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Home My WebLink About197-122 STATE OF ALASKA RECEIVED •SKA OIL AND GAS CONSERVATION COISSION REPORT OF SUNDRY WELL OPERATIONS FEB 2 6 201$ • 1. Operations Performed: 9:XOG CC ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver ® Other 13 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 197 - 122 3. Address: ® Development ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 7. Property Designation (Lease Number):, 8. Well Name and Number: ADL 025906 & 315848 MPG - 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): Milne Point Unit / Schrader Bluff 11. Present well condition summary: Total depth: measured 9845 feet Plugs:(measured) None feet true vertical 4508 feet Junk: (measured) 9579' feet Effective depth: measured 9739 feet Packer: (measured) 9180' & 9329' feet true vertical 4423 feet Packer: (true vertical) 3984' & 4100' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 9792' 7" 9822' 4490' 7240 5410 Liner SCANNED APE 19 2013 Perforation Depth: Measured Depth: 9256' - 9550' feet True Vertical Depth: 4043' - 4273' feet Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.4# 13Cr80 9115' 3933' Packers and SSSV (type, measured and true vertical depth): 7" Baker DB Packers 9180' & 9329' 3984' & 4100' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13 Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 110 53 308 220 240 Subsequent to operation: 80 52 347 220 185 14. Attachments: ❑ Copies of Logs and Surveys run 15. Well Class after work: t ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service ® Daily Report of Well Operations 16. Well Status after work: t ® 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: Sean McLaughlin, 564 -4387 N/A Email: Sean.McLaughlin @bp.com Printed N. - Joe ii ,u,v, a Title: Drilling Technologist Signature: i k ` _ q Phone: 564 -4091 Date: 2- /2-GM; - Form 10 -404 Re■ - -d 10/201 ' 7 201fff) )ELF Submit Original Only +P &L/3 /3 *' • Operation Summary Repo Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/26/2013 09:00 - 10:30 1.50 MOB P PRE PJSM, BRIDLE UP BLOCKS - FUNCTION RIG MOVING SYSTEM - WARM FRONT WHEEL WELL AREA WITH AIR HEATER - PREP FOR RIG MOVE 10:30 - 11:30 1.00 MOB P PRE PREP FLOOR TO LAY DERRICK OVER - PREP FOR RIG MOVE 11:30 - 12:00 0.50 MOB P PRE PJSM, REMOVE DERRICK PINS - LAY DERRICK OVER ON DERRICK STAND 12:00 - 14:00 2.00 MOB P PRE PJSM, WITH NEW CREW, SPCC WALK AROUND - CONT PREP RIG FOR RIG MOVE - BOTH THE RIG LOADER AND THE SPARE LOADER HAVING MECHANICAL DIFFICULTIES - CALL OUT FOR NEW LOADER TO BE TRANSPORTED TO RIG - MECHANIC MAINT, CLEAN INSIDE DRAW WORKS 14:00 - 15:30 1.50 MOB P PRE MOVE CREW TRAILER AND AIR HEATER - JACK UP RIG AND REMOVE SHIMS 15:30 - 18:00 2.50 MOB - P PRE MOVE RIG OFF OF MPL -12 - POSITION RIG IN CENTER OF PAD SECURE BOP ON CRADLE AND REMOVE FROM CELLAR - REMOVE RIG EQUIPMENT AND RIG MATS FROM AROUND CELLAR AND CLEAN AREA - 24 HOUR EMAIL NOTIFICATION GIVEN TO AOGCC OF IMPENDING BOP TEST 1/26/2013 16:37 HOURS 18:00 - 00:00 6.00 MOB P PRE MOVE RIG OFF OF MPL PAD - MOVE DOWN L -PAD ACCESS ROAD, TURN ON SPINE ROAD - MOVE DOWN SPINE ROAD AND MAKE TURN ONTO G -PAD ACCESS ROAD 1/27/2013 00:00 - 02:00 2.00 MOB P PRE PJSM, MAKE SPCC AND EQUIPMENT CHECKS - CONT MOVE RIG DOWN G -PAD ACCESS ROAD TO MPG -PAD - SPOT RIG ON PAD TO ALLOW FOR CELLAR WORK 02:00 - 03:30 1.50 MOB P PRE PJSM, RAISE DERRICK - POSITION HANDS TO WATCH LINES AND CABLES - RAISE DERRICK AND PIN IN PLACE - R/U RIG FLOOR EQUIPMENT 03:30 - 05:00 1.50 MOB P PRE BRIDLE DOWN - PLACE BOP IN CELLAR AND REMOVE FROM CRADLE - SPOT NEW MUD CROSS AND RELATED EQUIPMENT IN CELLAR 05:00 - 12:00 7.00 MOB P PRE PJSM ON RECONFIGURE OF BOP STACK - REMOVE DOUBLE GATE FROM STACK - REMOVE HCR'S AND MANUAL CHOKE AND KILL VALVES FROM OLD MUD CROSS - INSTALL NEW MUD CROSS ON STACK - M/U HCRAND MANUAL KILLAND CHOKE VALVES TO NEW MUD CROSS Printed 2/18/2013 3.00:14PM tr America - ALASKA BP `� Operation Summary Report Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 20:00 8.00 MOB P PRE PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CONT WORK ON BOP - CONFIGURATION TOP TO BOTTOM = ANNULAR, BLIND / SHEAR RAMS, MUD CROSS, 2 7/8 X 5 VBR'S - WILL COMPLETE TIGHTENING FLANGE BOLTS WHEN OVER THE WELL 20:00 - 22:30 2.50 MOB P PRE STAGE WELL EQUIPMENT AROUND WELL - POSITION MATS TO SPOT RIG OVER WELL - SPOT RIG OVER WELL MPG -15 22:30 - 00:00 1.50 MOB P PRE SHIM RIG, CLOSE AND CHINK CELLAR AREA - SPOT SLOP TANK, FUEL TRAILER AND CREW TRAILER 1/28/2013 00:00 - 03:00 3.00 WHSUR P DECOMP PJSM, MAKE SPCC AND EQUIPMENT CHECKS - R/U WELL KILL MANIFOLD AND CIRCULATING LINES TO TREE - TAKE ON 8.8 PPG, 100 DEGREE BRINE - BERM CELLAR AND RIG OUTER WALLS - RIG ACCEPTED AT 00:00 HOURS 03:00 - 06:00 3.00 WHSUR P DECOMP STEAM HARD LINE TO FLOW BACK TANK - BLOW AIR THROUGH ALL LINES TO VERIFY CLEAR OF ICE - TEST ALL CIRCULATING LINES WITH DIESEL TO 250 PSI, 3500 PSI, 5 MIN CHARTED - IAAT 200 PSI. 06:00 - 06:30 0.50 WHSUR P DECOMP RIG EVACUATION DRILL - DRILLER CALLED A GAS RELEASE TO THE CELLAR AREA. - RIG CREWAND CH2MHILL DRIVERS ON LOCATION RESPONDED APPROPRIATELY. AFTER ACTION REVIEW -ALL HANDS GRABBED ESCAPE PACKS AS THEY LEFT THE RIG. - CH2MHILL DRIVERS WALKED THE LONG WAY AROUND THE RIG TO AVOID GOING DOWNWIND. - SITE CONTROL WAS OFFSITE DOING CHANGOUT. - SITE CONTROL CALLED IN WITH NAMES FROM ROLLING ROSTER. 06:30 - 07:30 1.00 WHSUR P DECOMP RIG UP AND TEST LUBRICATOR TO PULL BACK PRESSURE VALVE. - PRE JOB SAFETY MEETING WITH RIG CREW AND MPU WELL SUPPORT - PICK UP AND RIG UP LUBRICATOR. - PRESSURE TEST LUBRICATOR TO 250 / 3500 PIS HIGH FOR 5 CHARTED MINUTES. 07:30 - 09:00 1.50 WHSUR P DECOMP PULL BACK PRESSURE VALVE AND LAY DOWN LUBRICATOR. - PULL BACK PRESSURE VALVE WITH HYDRAULIC LUBRICATOR. - LAY DOWN BACK PRESSURE VALVE AND LUBRICATOR. - RIG DOWN DRILL SITE MAINTENANCE EQUIPMENT TO MAKE ROOM FOR WELL KILL. Printed 2/18/2013 3:00:14PM F/4 ID North America AL ASKA . � % � % % Operation Summary Report ,, Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum. Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:00 - 12:00 3.00 KILLW P DECOMP PJSM, WELL KILL OPERATIONS - TOOLPUSHER AND WSL SIGN OFF ON • VALVE LINE -UP - INITIAL IA PRESSURE = 200 PSI Yit - BLEED GAS OFF OF IA - PUMP 55 BBLS ON 8.8 100 DEGREE BRINE DOWN TUBING, TAKING RETURNS THROUGH KILL MANIFOLD TO FLOW BACK TANK - 3 BPM = 500 PSI, 125 PSI ON IA CLOSE IA CHOKE AND BULL HEAD 30 BBLS DOWN TUBING TO FORMATION - 3 BPM = 750 - 900 PSI - OPEN IA CHOKE AND PUMP 248 BBLS DOWN TUBING, RETURNS TO FLOW BACK TANK - 5 BPM = 900-1500 PSI ON TUBING, HOLD 175 - 380 PSI ON IA -STOP PUMP, SHUT WELL IN 12:00 - 13:00 1.00 KILLW P DECOMP VAC OUT FLOW BACK TANK OF CRUDE RETURNS - 290 BBLS OF CRUDE IN FLOW BACK TANK - SEND TO RECYCLE FOR RECOVERY 13:00 - 14:30 1.50 KILLW P DECOMP CIRCULATE 410 BBLS OF 8.8 PPG 100 DEGREE BRINE - 4 BPM = 810 PSI ON TUBING, 75 PSI ON IA - PUMP UNTIL CLEAN FLUID RETURNS 14:30 - 15:00 0.50 KILLW P DECOMP MONITOR WELL FOR 30 MINUTES - TUBING = 0 PSI, IA= 0 PSI - BOTH SIDES ON A VACUUM - PUMPED TOTAL OF 597 BBLS 8.8 PPG BRINE, RETURNED 475 BBLS = 122 LOSS, MINUS 30 BBLS BULLHEADED = 92 BBLS LOSS DURING KILL 15:00 - 17:00 2.00 WHSUR P DECOMP BLOW DOWN AND RIG DOWN WELL KILL MANIFOLD AND CIRCULATING LINES - R/U SECONDARY KILL LINE TO FEED IA WITH BRINE - VAC OUT FLOW BACK TANK �G 6 17:00 - 19:00 2.00 WHSUR P DECOMP M/U WELL SUPPORT LUBRICATOR TO SET (/ V TWC - TEST LUBRICATOR TO 250 PSI, 3500 PSI, 5 MIN, CHARTED - INSTALL TWC - PERFORM ROLLING TEST BELOW TWC, 500 PSI, 10 MIN, CHARTED - TEST TWC FROM ABOVE, 250 PSI, 3500 PSI, 5 MIN, CHARTED 19:00 - 20:30 1.50 WHSUR P DECOMP FMC REP, BLEED TUBING VOID - N/D FMC TREE - CHECK THREADS, GOOD 2 7/8" EUE 8RD, 8.5 RH TURNS 20:30 - 00:00 3.50 BOPSUR P DECOMP PJSM, N /U BOPE - TORQUE ALL FLANGES ON MUD CROSS - CHANGE OUT TURNBUCKLES - MEASURE AND WELD EXTENSION ON RISER - MAINTAIN CONSTANT FILL TO IAAT 20 BPH - 24 HOUR FLUID LOSS = 143 BBLS 8.8 PPG BRINE Printed 2/18/2013 3:00:14PM North America ALA SKA BFP`�ri rf, Operation Summary Repo Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/29/2013 00:00 - 03:00 3.00 BOPSUR P DECOMP PJSM, SPCC AND EQUIPMENT CHECKS - N/U BOP, TORQUE ALL FLANGES - INSTALL RISER - M/U FLOOR VALVES AND TEST JOINTS 03:00 - 04:30 1.50 BOPSUR P -_ DECOMP INSTALL BLIND RAMS AND 2 7/8" X 5" VBR'S - FUNCTION TEST ALL RAMS 04:30 - 07:00 2.50 BOPSUR P DECOMP R/U TEST EQUIPMENT FILL BOP AND CHOKE MANIFOLD, BLEED ALLAIR OUT OF SYSTEM - PERFORM INITIAL BODY SHELL TEST - TWC NOT HOLDING PRESSURE FROM ABOVE. - SUCK OUT STACK AND WASH TOP OF TWC. - PRESSURE UP ON TWC TO SET POPPET. - TWC HOLDING PRESSURE. - REPEAT BODY SHELL TEST TO 3500 PSI. - GOOD TEST. - CALL BOB NOBLE OFAOGCCAND GIVE UPDATE. - BOB NOBLE GAVE PERMISSION TO BEGIN TESTING. - BOB NOBLE IS ON HIS WAY OUT TO WITNESS BOPE TEST. 07:00 - 14:00 7.00 BOPSUR P DECOMP PJSM, TEST BOPE - ALL TESTS, 250 PSI LOW, 3500 PSI HIGH 5 MINUTES, CHARTED - TEST ANNULAR WITH 2 7/8" TEST JOINT - TEST BLIND RAMS - TEST LOWER VARIABLE PIPE RAMS WITH 2 7/8" AND 4" TEST JOINTS - TEST ALL CHOKE MANIFOLD VALVES, HCR'S, FLOOR VALVES AND IBOP'S - BOB NOBLE OF AOG.QC WITNESSED BOPF TEST - MAINTAIN CONSTANT HOLE FILL INTO IA = 15BPH 14:00 - 16:30 2.50 BOPSUR P DECOMP HAVING PROBLEMS WITH TWC HOLDING PRESSURE - R/D TEST EQUIPMENT, DRAIN BOP STACK - VERIFY THAT FLUID IS INTERMITTENTLY PASSING TWC - WASH AND VAC OUT FLUID ABOVE TWC UNTIL CLEAN - R/U TEST EQUIPMENT - FILILAND BLEED AIR OUT OF SYSTEM 16:30 - 20:00 3.50 BOPSUR P DECOMP CONTINUE BOPE TESTAS INDICATED PREVIOUSLY - CONDUCTACCUMULATOR DRAW DOWN TEST 20:00 - 22:30 2.50 BOPSUR P DECOMP R/D BOP TEST EQUIPMENT - BLOW DOWN ALL CHOKE AND KILL LINES - L/D TEST JOINTS - PULL RISER AND SEND TO SHOP FOR REPAIR OF SMALL LEAK IN WELD - REINSTALL RISER Printed 2/18/2013 3:00:14PM North America - ALASKA BP rr' ? ,f� ; -, ' Operation Summary Report, Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67- E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:30 - 00:00 1.50 WHSUR P DECOMP P/U OFF -SET LUBRICATOR AND M/U TO HANGER - M/U WELL SUPPORT LUBRICATOR TO OFF SET LUB - TEST TO 250 PSI, 3500 PSI, 5 MIN CHARTED - 24 HOUR FLUID LOSS = 202 BBLS 1/30/2013 00:00 - 01:30 1.50 WHSUR P DECOMP PJSM, TEST WELL SUPPORT LUBRICATOR -250 PSI, 3500 PSI, 5 MIN, CHARTED - PULL TWC, WELL IN ON A VAC - R/D W/S LUBRICATOR, L/D OFF -SET LUBRICATOR - R/D TEST EQUIP, BLOW DOWN LINES 01:30 - 02:00 0.50 WHSUR P DECOMP M/U LANDING rJOINT TO HANGER - MOBILIZE CENTRILIFT EQUIPMENT TO RIG FLOOR 02:00 - 03:00 1.00 WHSUR P DECOMP PJSM TO PULL HANGER TO RIG FLOOR - WSL VERIFY NO PRESSURE BELOW HANGER, IA'ISONAVACUUM - FMC REP BACK OUT LOCK DOWN SCREWS -PULL HANGER TO RIG FLOOR W - PUT = 83K, SOWT = 73K - REMOVE ESP CABLE FROM HANGER CUT ESP CABLE AND HEAT TRACE AT BOTTOM OF FIRST FULL JOINT - RUN IN HOLE AND PLACE SLICK PIPE ACROSS BOP STACK - CLOSE ANNULAR AND LINE UP THROUGH CHOKE AND GAS BUSTER 03:00 - 06:00 3.00 CASING P ' DECOMP CIRCULATE DEEP CLEAN SWEEP SURFACE TO SURFACE - 3 BPM = 520 PSI - HEAVY OIL RETURNS AT BEGINNING OF CIRCULATION, FIRST -20 BBLS - OBSERVE PARTIAL SOAP PILL RETURNS FROM CALCULATED DEPTH OF AROUND — 2000' - OBTAIN SPR'S, 20 SPM = 160 PSI, 30 SPM = 350 PSI - WSL / DRILLER VERIFY NO TRAPPED PRESSURE & OPEN ANNULAR. - TBG & IA ON VERY SLIGHT VACUUM. - L/D TBG HANGER IN GOOD CONDITION. - R/U ESP SHEAVE AND POWER TONGS - 10 BPH LOSS RATE WITH CONTINUOUS HOLE FILL, 8.8 PPG BRINE. 06:00 - 11:30 5.50 PULL P DECOMP PJSM, PULL ESP / HEAT TRACE COMPLETION ASSEMBLY. - POH W/ 2 -7/8" 6.5# L -80 EUE TBG - L/D 1X1 TO PIPE SHED - AND SPOOL ESP / HEAT TRACE CABLE. - SNAKE OVER DOUBLE SHEAVE IN DERRICK TO SPOOLING UNIT. - F/ SURFACE T/ 7946' MD. PUW /75K, SOW /60K. (INCLUDES 40K TOP DRIVE WT.) - —12 BPH LOSS RATE. Printed 2/18/2013 3:00:14PM North America - ALASKA B �� s Operation Summary Report Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:00 0.50 PULL P DECOMP HELD KICK WHILE TRIPPING DRILL. AAR: - DISCUSSED CUTTING BOTH ESP & HEAT TRACE CABLES. REQUIRES TWO ROPES TO SECURE TO DERRICK. - SAFETY -VALE- JOINT WAS READY AND ACCESSIBLE WHEN PICKED UP FROM PIPE SHED. - A SECOND FOSV (4" TIW VALVE) WTH A CROSS -OVER TO 8RD EUE, WAS READY ON SUB RACK. CLEAN AND CLEAR RIG FLOOR - REMOVE SS BANDS AND FLAT GUARDS. - CLEAN OILY WORKAREA. 12:00 - 12:30 0.50 PULL P DECOMP PERFORM PRETOUR CHECKS. -PJSM ON PULL ESP/ HEAT TRACE COMPLETION. 12:30 - 20:30 8.00 PULL P DECOMP PJSM, POOH AND UD 2 7/8" ESP / HEAT TRACE COMPLETION 1X1 - PULL F/ 9112' T/ 4292' - HEAT TRACE ENDED AT 3285' 20:30 - 22:00 1.50 PULL P DECOMP CONTINUE POOH WITH 2 7/8" ESP COMPLETION AND STAND BACK IN DERRICK - PULL FROM 4292' TO 2168' - OBSERVE CORROSION ON OUTSIDE OF PIPE, L/D CORRODED PIPE - DISCUSSED OPTIONS WITH TOWN ENGINEER, DECIDE TO LAY DOWN REMAINING 2 7/8" TUBING 22:00 - 23:00 1.00 PULL P DECOMP CONTINUE TO PULL AND UD 2 7/8" ESP COMPLETION 1X1 - PULL FROM 2168' TO 1572' - PUWT = 50K, SOWT = 50K 23:00 - 00:00 1.00 PULL P DECOMP C/O ESP REEL IN CENTRILIFT SPOOLING UNIT - CLEAN DRIP PAN ON SPOOL CAGE - CLEAN RIG FLOOR OF EXCESS OIL AND ABSORB - 24 HOUR FLUID LOSS = 254 BBLS 1/31/2013 00:00 - 01:00 1.00 PULL P DECOMP PJSM, SPCC, C-O-MATIC AND EQUIPMENT CHECKS - CONTINUE TO C/O CENTRILIFT REEL IN SPOOLING UNIT 01:00 - 03:30 2.50 PULL P DECOMP CONTINUE TO PULL AND UD 2 7/8" ESP COMPLETION 1X1 - PULL FROM 1572' TO ESP PUMP AND MOTOR ASSY 03:30 - 04:30 1.00 PULL P DECOMP UD ESP PUMP AND MOTOR ASSY -FEED ESP CABLE THRU SHEAVE AND SPOOL UP ON REEL IN SPOOLING UNIT - MONITOR WELL, OBTAIN STATIC LOSS RATE = 12 BPH - MAINTAIN CONTINUOUS HOLE FILL WITH 8.8 PPG BRINE - PUMP FAILURE, PLUGGED AND LOCKED -UP - 286 JTS LAYED DOWN - RECOVERED ALL CLAMPS AND BANDS - 1 SS BAND LOST TO HOLE Printed 2/18/2013 3:00:14PM Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 06:30 2.00 PULL P DECOMP R/D CENTRILIFT EQUIPMENT - R/D SHEAVE AND TRUNK - CLEAN OIL FROM RIG FLOOR AND PIPE SHED - R/D SPOOLING UNIT 06:30 - 07:00 0.50 WHSUR P DECOMP M/U - WEAR 9" RING RUNNING TOOL ■ INSTALL ID WEAR RING. - L/D RUNNING TOOL. 07:00 - 08:00 1.00 PULL P DECOMP REMOVE ESP REELS FROM SPOOLING UNIT MOVE SPOOLING UNIT OFF LOCATION TO ALLOW WIRELINE - CLEAN RIG FLOOR. 08:00 11:00 3.00 EVAL P DECOMP MOVE IN AND SPOT SWS SLICK LINE UNIT - INSTALL DUTCH RISER PJSM, R/U SLICK LINE TOOLS AND EQUIP - M/US PDS LOGGING TOOL 11:00 - 13:00 2.00 EVAL P DECOMP RIH WITH CALIPEG TOO LS - LOG UP FROM PDS 2500' TO R S GING SMALLESTID AT PATCH AT 2122' IS 5.94207", A MECHANICAL DRIFT WILL NOT BE RUN 13:00 13:30 0.50 EVAL P DECOMP R/D/ WIRELINE TOOLS AND EQUIPMENT - R/D DUTCH RISER 13:30 - 14:00 0.50 CASING P ■ DECOMP PERFORM RIG SERVICE INSPECTAND GREASE TOP DRIVE, DRAWWORKS, AND IRON ROUGHNECK 14:00 - 15:00 1.00 CASING P DECOMP HOLD SAFETY MEETING WITH ALL CREW MEMBERS - BP WELLS TEAM LEADER, RWO , , DRILLI SUPERINTENDENTNG SUPERINT DOYON PRESENT TPAND 15:00 16:00 1.00 CASING P DECOMP PJSM, MOBILIZE HALLIBURTON PACKER TO RIG FLOOR - M/U 7" RTTt PACKER 16:00 - 18:00 2.00 CASING P DECOMP RIH WITH PACKER ON 2 7/8" EUE 8RD TUBING FROM DERRICK - RIH FROM SURFACE TO 2700' 18:00 - 00:00 6.00 CASING P DECOMP C/O ELEVATORS TO 4 1 DP - RIH WITH RTTS ON 4" DP 1X1 FROM PIPE SHED - RIH F/ 2700' T/ 7474' - 24 HOUR FLUID LOSS = 221 BBLS \ \ k _ ( 2/1/2013 00:00 02:00 2.00 CASING P DECOMP PJSM, RIH ITH RTTS PACKER ( � ■ - RIH F/ 7474' W T/ 9151' MD ? PUWT = 108K, SOWT = 72 G 02:00 - 02:30 0.50 CASING P DECOMP SET RTTS AT 9144' MD CENTER OF ELEMENT -SET WITH 15K DOWN WEIGHT 02:30 - 04:00 1.50 CASING P DECOMP R/U TO TEST CASING Q q CLOSE NLAAT A TO � 1 2000 PSI, AN 30 MIN U RC HARTED ND TES =GOOD C SING TEST A (t na 1 - CALL WTL FOR AUTHORIZATION TO PROCEED = GRANTED - NUOUS HWN DRILL PIPE MAINTAIN AND CONTI TUBING DURING TEST FILL DO TO KEEP HOLE FULL BELOW RTTS BLEED OFF PRESSURE, WSL ENSURE NO PRESSURE BELOWANNULAR Printed 2/18/2013 3:00:14PM Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time 6/12/2000 12:00:00AM Rig Release. Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 CASING P DECOMP R/D DP / TUBING FILL LINE, M/U TOP DRIVE - PICK UP AND OPEN BY -PASS ABOVE RTTS - PICK UP AND RELEASE RTTS PACKER PER HALLIBURTON REP - LET PACKER RELAX AND MONITOR WELL FOR 15 MINUTES - STATIC LOSS RATE = 12 BPH R/D ALL TEST EQUIPMENT, BLOW DOWN ALL LINES 05:00 - 14:00 9.00 CASING P DECOMP PJSM, LDDP 1X1 - MAINTAIN CONTINUOUS HOLE FILL - MONITOR HOLE FILL CLOSELY, NOTIFY WSL OF ANY CHANGES - L/D 4" DRILL PIPE F/ 9144' MD TO 2723' MD L/D 2 7/8" TUBING WORKSTRING F/ 2723' TO 7" RTTS - NO DRAG NOTED PULLING THRU THE PATCH @ -2122` MD. - MAINTAIN CONTINUOUS HOLE FILLAT -9 -11 BPH LOSS RATE W/ 8.8 PPG BRINE. 14:00 - 14:30 0.50 CASING P DECOMP PJSM, UD RTTS - L/D 7" RTTS PER HES REP. TEST ELEMENTS WERE SCUFFED FROM TOP TO BOTTOM, 1/2" WIDE ONCE. 14:30 - 15:00 0.50 WHSUR P DECOMP M/U WEAR RINGING TOOL - PULL WEAR RING AND UD RUNNING TOOL - CLEAN / CLEAR RIG FLOOR 15:00 - 19:00 4.00 RUNCOM P RUNCMP PJSM, LOAD AND STRAP 290 JOINTS OF 2 7/8" VAM TOP CR13 TUBING - M/U FLOOR SAFETY VALVE AND CROSS -OVERS - R/U STABBING BOARD 19:00 - 20:00 1.00 RUNCOM P RUNCMP PERFORM WELL KILL DRILL WITH PIPE OUT OF HOLE AND HANDS AWAY FROM THE FLOOR - THE FLOAT PADDLE WAS RAISED CAUSING THE HIGH FLOWALARM TO SOUND - THE HOLE FILL PUMP WAS SHUT OFF, THE DRILLER CHECKED FOR PIT GAIN AS WELL AS FLOW - THE BLIND RAMS WERE SHUT IN, THE CHOKE HCR WAS OPENED TO A CLOSED CHOKE - THE DRILLER ANNOUNCED A WELL KILL • DRILL TO THE HANDS - ALL HANDS RESPONDED VERY QUICKLY TO THEIR ASSIGNED STATIONS AND NOTIFIED THE DRILLER - ALL CLEAR WAS GIVEN, WSL VERIFIED NO PRESSURE UNDER THE BLINDS, THE BLINDS WERE THEN OPENED AND CONSTANT HOLE FILL WAS RESUMED - AN "AAR" WAS HELD WITH ALL HANDS, TOUR PUSHER, WSLAND BP ASSESSMENT TEAM - HANDS DID A VERY GOOD JOB DESCRIBING HOW THEY RESPONDED TO THE DRILL, AND WHAT THEIR INDIVIDUAL RESPONSIBILITIES WERE Printed 2/18/2013 3:00:14PM North America - ALASKA r / 47. /, , 4 / r Operation Summary Repo Common Wet Name: MPG -15 AFE No Event Type: WORKOVER ONO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 23:00 3.00 RUNCOM P RUNCMP CONTINUE TO LOAD AND STRAP ATOTAL OF 290 JOINTS OF 2 7/8" VAM TOP CR13 TUBING - C/O TO LONG BALES - HANG DOUBLE ESP SHEAVE IN DERRICK - R/U POWER TONGS WITH COMPENSATOR 23:00 - 00:00 1.00 RUNCOM P RUNCMP SPOT CENTRILIFT SPOOLING UNIT - LOAD ESP CABLE AND HEAT TRACE SPOOLS INTO SPOOLING UNIT - MOBILIZE CENTRILIFT TOOLS TO RIG FLOOR - 24 HOUR FLUID LOSS = 243 BBLS 8.8 PPG BRINE 2/2/2013 00:00 - 02:00 2.00 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND CRITICAL EQUIPMENT CHECKS - CONTINUE R/U ESP EQUIPMENT - PULL ESP CABLE TO RIG FLOOR - COMPLETE TORQUE TURN EQUIPMENT R/U 02:00 - 06:00 4.00 RUNCOM P RUNCMP PJSM, P/U ESP PUMP AND MOTOR ASSY - LOAD OIL AND SERVICE MOTOR - TIE IN ESP CABLE AND CHECK FOR CONDUCTIVITY 06:00 - 12:00 6.00 RUNCOM P RUNCMP RUN 2 -7/8" 6.4#, CR13 VAMTOP TUBING 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' AT 1/2 BPM / 650 PSI. @ 14:00 HRS. - RIH F/ SURFACE T/ 1852' MD 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM, SERVICE RIG - SERVICE DRAW WORKS AND TOP DRIVE - MAKE SPCC AND EQUIPMENT CHECKS 12:30 - 23:00 10.50 RUNCOM P RUNCMP CONTINUE TO RUN 2 -7/8" 6.4#, CR13 VAMTOP TUBING ESP COMPLETION - P/U TUBING 1X1 FROM PIPE SHED - RIH F/ 1852' T/ 5688' - INSTALL 2' CANNON CLAMPS EVERY OTHER COLLAR - CHECK CONDUCTIVITY EVERY 2000' AND PUMP 5 BBLS DOWN PIPE = 980 PSI (AT 4000') - PUWT = 65K, SOWT = 60K 23:00 - 00:00 1.00 RUNCOM P RUNCMP MAKE ESP CABLE SPLICE - STRING HEAT TRACE CABLE FROM SPOOLING UNIT, OVER SHEAVE TO RIG FLOOR - MOBILIZE DOUBLE CHANNEL CANNON CLAMPS TO RIG FLOOR - 24 HOUR FLUID LOSS = 190 BBLS 8.8 PPG BRINE Printed 2/18/2013 3:00:14PM North America - ALASKA - BP Operation Summary Report Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ _ (ft) 2/3/2013 00:00 - 03:30 3.50 RUNCOM P RUNCMP PJSM, PERFORM SPCC AND EQUIPMENT CHECKS - CONTINUE TO MAKE ESP CABLE SPLICE 03:30 - 12:00 8.50 RUNCOM P RUNCMP CONTINUE TO RUN 2 -7 /8" 6.4#, CR13 VAMTOP TUBING ESP COMPLETION PU TUBING 1X1 FROM PIPE SHED - RIH F/ 5678' T/ 6969' MD. - STRING HEAT TRACE CABLE FROM SPOOLING UNIT, OVER SHEAVE TO RIG FLOOR - INSTALL HEAT TRACE AT BOTTOM OF JOINT #179 - INSTALL 6 DOUBLE CHANNEL CANNON CLAMPS ON EACH JOINT - INSTALL 1 SINGLE CHANNEL CANNON CLAMP ON EACH COLLAR CHECK HEAT TRACE EVERY 1000' - CHECK CONDUCTIVITY OF ESP CABLE EVERY 2000' AND FLUSH PUMP W/5 BBLS / 1 BPM. - @6969' PUW/ 70K, SOW / 65K. 12:00 - 12:30 0.50 RUNCOM P RUNCMP PJSM, RUN ESP / HEAT TRACE. - SERVICE RIG PERFORM PRE -TOUR CHECKS. 12:30 - 00:00 11.50 RUNCOM P RUNCMP CONTINUE TO RUN 2 -7/8" 6.4 #, CR13 VAMTOP TUBING WITH ESP/ HEAT TRACE COMPLETION. - P/U TUBING 1X1 FROM PIPE SHED - RIH F/ 6969' T/ 8709' MD - CONTINUE ESP CONDUCTIVITYAND HEAT TRACE CHECKS EVERY 1000' AND 2000' - PUMP 5 BBLS AT.5 BPM = 1820 PSI (AT 8000') - PUVVT = 79K, SOWT =65K - 24 HOUR FLUID LOSS = 167 BBLS 8.8 PPG BRINE - BOILER POP -OFF MALFUNCTION, #IR- 4345666 2/4/2013 00:00 - 03:30 3.50 RUNCOM P RUNCMP PJSM, SPCC AND EQUIPMENT CHECKS - CONTINUE TO RUN 2 -7/8" 6.4 #, CR13 VAMTOP TUBING WITH ESP / HEAT TRACE COMPLETION. - P/U TUBING 1X1 FROM PIPE SHED - RIH F/ 8709' T/ 9089' MD - INSTALL 6 DOUBLE CHANNEL CANNON CLAMPS ON EACH JOINT - INSTALL 1 SINGLE CHANNEL CANNON CLAMP ON EACH COLLAR - CHECK HEAT TRACE EVERY 1000' - CHECK CONDUCTIVITY OF ESP CABLE EVERY 2000' AND FLUSH PUMP W/5 BBLS / 1 BPM. - CLAMPS INSTALLED - CANNON CLAMPS = 93 - 5' CANNON CLAMPS = 510 - 2' CANNON CLAMPS = 108 - EQUIPMENT SS CLAMPS = 5 - FLAT BAR CLAMPS = 3 Printed 2/18/2013 3:00:14PM Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date /me: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 08:00 4.50 RUNCOM P RUNCMP M/U HANGER WITH TWC INSTALLED - M/U 2 7/8" EUE LANDING JOINT WITH FOSV TO HANGER - INSTALL PENETRATORS IN HANGER - TERMINATE ESP CABLE AND HEAT TRACE LINE TO PENETRATORS IN HANGER 08:00 - 08:30 0.50 RUNCOM P RUNCMP PJSM, LANDING TBG HANGER. FMC REP, WSL, CENTRALIFT REP IN ATTENDANCE.' - LAND HANGER PER FMC REP. PU WT= 83K INCLUDING 40K BLK WT. SO WT =69K. - RILDS PER FMC REP. LD LANDING JOINT. 08:30 10:00 1.50 WHSUR P RUNCMP PERFORM ROLLING TEST FROM BELOW TWC FOR 10 MIN. 3.7 BPM = 650 PSI, 75 BBLS PUMPED AWAY - TEST FROM ABOVE TWC, 250 / 3500 PSI, 5 MIN, CHARTED 10:00 - 11:30 1.50 BOPSUR P RUNCMP PJSM N/D 13 5/8" BOPE - REMOVE FLOW NIPPLE AND TURNBUCKLES. - LOTO KOOMYAND REMOVE HOSES. - SET BACK BOP STACK 11:30 - 14:00 2.50 WHSUR P RUNCMP PJSM, N/D BOPE N/U FMC GEN VI, 11 X 2- 9/16" 5M, ADAPTER, 2 9/16" CAMERON TREE - CENTRILIFT REP TAKE FINAL ESP / HEAT TRACE READINGS. 14:00 15:30 1.50 WHSUR_ P RUNCMP FMC REP PRESSURE TEST ADAPTER VOID - 250 PSI FOR 5 CHARTED MINUTES, PASSED. - 5000 PSI FOR 30 CHARTED MINUTES. PASSED. - PRESSURE TEST PRODUCTION TREE - 250 / 5000 PSI, BOTH 5 MINUTES CHARTED. PASSED. 15:30 - 18:30 3.00 WHSUR N WSEQ RUNCMP WAIT ON WELL SUPPORT VALVE CREW - CREW WAS WORKING ON AN EMERGENCY JOB - PREP RIG FLOOR, CELLAR AND PIPE SHED AREAS FOR RIG MOVE - HOLD "CONSTANT IMPROVEMENT' MEETING - TOPICS DISCUSSED INCLUDE; SAFETY ACTION ITEMS, SUMMER MAINTENANCE, NEW BRIDGE CRANES, NEW IRON ROUGHNECK, WORK ON PITS, NEW SHAKERS, AND GRAVEL EXTENSIONS AT PAD ACCESS ROADS - RWO SUPERINTENDENT, BP SAFETY SUPERVISOR, BOTH WSL'S, AND SCS'S - BOTH DOYON TOOLPUSHERS, DRILLING SUPERINTENDENT, AND DOYON SAFETY SUPERVISOR WERE PRESENT 18:30 22:00 3.50 WHSUR P RUNCMP PJSM, R/U AND TEST DSM LUBRICATOR - TEST 250 / 3500 PSI, 5 MIN, CHARTED, PULL TWC. - TEST LUBRICATOR, INSTALL BPV - L/D LUBRICATOR. - PERFORM ROLLING TEST FROM BELOW BPV, 500 PSI, 10 MIN, 3.5 BPM, 62 BBLS PUMPED, 7 BBLS BLED BACK Printed 2/18/2013 3:00:14PM • North America - ALA F a O peration Summary R epo Common Well Name: MPG -15 AFE No Event Type: WORKOVER (WO) Start Date: 1/26/2013 End Date: 2/5/2013 X4- 00X67 - E:DRILL (2,050,000.00 ) Project: Milne Point Site: M Pt G Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/12/2000 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active datum: Kelly Bushing / Rotary Table @60.6ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 WHSUR P RUNCMP CLEAN REMAINING FLUID FROM PITS AND CUTTINGS TANK - SPOT LITTLE RED SERVICES - R/U TO BULLHEAD FREEZE PROTECT - 24 HOUR FLUID LOSS = 175 BBLS 2/5/2013 00:00 - 01:30 1.50 WHSUR P RUNCMP PJSM, SPCC AND EQUIPMENT CHECKS - LRS FREEZE PROTECT IAAND TUBING - BULLHEAD 70 BBLS DEAD CRUDE TO IA, 2 BPM = 2000 PSI - BULLHEAD 15 BBLS DEAD CRUDE TO TUBING, 1 BPM = 2000 PSI - R/D LRS 01:30 - 02:00 0.50 WHSUR P RUNCMP COMPLETE PIT CLEANING - REMOVE CUTTINGS TANK FROM RIG TO ALLOW ROADS AND PADS TO PREP NEXT WELL - PREP RIG FOR MOVE - RELEASE RIG AT 02:00 HOURS Printed 2/18/2013 3:00:14PM Tree: 2- 9/16" - 5M FMC • MPU G-15 a. RT Elev. = 58.8' (N22E) Wellhead: 11 "x12" Monobore 5M FMC . Orig. GL Elev. = 29.8' Gen 6 w/11" x 2 -7/8" FMC Tubing P RT to Tbg Spool = 30.5' (N22E) f Hanger, 2 -7/8" 8rd. top & bottom, 2.5" CIW BPV profile Camco 2 -7/8" x 1" 20" 91.1 ppf, H-40 112' o, KBMM -2 GLM 143' I 0 p 2122' Heat Trace 3436' I $ ES cementer was found to be leaking /; during attempted completion (2- 27 -98) Howco internal casing patch installed KOP @ 300' to 500' (5/17/98) and pressure tested to 3000 Max Hole Angle = 82 deg. psig - Do not exceed this test psi!!! Hole angle through perfs. = 38 deg. Patch ID = 5.875" (drift = 5.75 ") Heat Traced to 3420' Camco 2 -7/8" x 1" k. KBMM -2 GLM 2599' y 2 -7/8" xn nipple 2.205" ID 9020' Note: Caution should be used when running ESP BHA through casing patch at 2122' lit O Discharge Head Model FPHVDIS 2 -7/8" 6.4 ppf., Cr13 Vam Top Tbg. Pump Model - 140 -P10 SXD 9064' (drift ID = 2.347 ", Cap. = .00579 bpf) E 7" 26 # /ft., L -80, BTRC, production git csg., (drift ID = 6.151 ", cap. = 0.0383 bpf) Std. Bolt On Intake 9082' Model - FRSTX FERH6 AR o � Intake (TVD) 3900' �� Tandem Seal Section Stimulation Summary d 9086' Model - FST3DBHLUT PFS SB /SB N Sand: - Not Stimulated. FST3DBHLLT PFS SB /SB OA sand - 33.5M# 12 -20 Prop -Lok resin ilIWIL coated Ottowa sand behind pipe. ME Motor, 54 HP, 880 volt, 9099 OB sand - 66.2M# 12 -20 Prop -Lok resin 39 amp, Model SP1 coated Ottowa sand behind pipe. PumpMate w/6 fin 9108' W Centralizer Perforation Summary Ref. Log 07/25/97 DGR Size SPF Interval ° Baker 7" DB Pkr 9180' (TVD) - "N" Sand .. :.:•:•:•:•:•: E 2.812" "XN" Nipple 9298' 4.5" 5 9256` -9272' (3984` - 3996') E" 2.75" No -Go 4.5" 5 9228 - 9294' (4009'- 4014`) Baker 7" DB Pkr 9329' "O A" Sand 4.5" 4 9436-9455' (4120`4140') C ; 5 Two 7" marker jts. at 9127' to 9167' MD 4.5" 4 9456-9480' (4146- 4160') !J "OB" Sand 4.5" 4 9530' -9550' (4199`- 4215') "Jet Charges @ 0/180 deg. phasing" 7" landing collar (PBTD)I 9739' I e I *Note: Fish below bottom perf @ 9579'. < 7" float collar I 9779' (ESP Tandem Seal Sectons, Motor and �� 7" float shoe I Pumpmate w/6 Fin Centralizer) �� 9822' DATE REV. BY COMMENTS MILNE POINT UNIT 3/18/01 GMH RWO Nabors 4ES WELL G -15 7/12/06 MOR RWO Nabors 3S API NO. 50- 029 -22784 2/06/13 B. Bixby Doyon 16 ESP & Tbg Changeout BP EXPLORATION (AK) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 rt December 30, 2011 E 2 4 tM Mr. Tom Maunder (T7_ Alaska Oil and Gas Conservation Commission Wip 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPG -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPG -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) MPG -Pad 10110/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPG-01 1890290 50029219270000 Tanko conductor NA NA NA NA NA MPG -02 1890280 50029219260000 Tanko conductor NA NA NA NA NA MPG -03A 2042190 50029219420100 Tanko conductor NA NA NA NA NA MPG-04 1890450 50029219410000 Tanko conductor NA NA NA NA NA MPG-05 1910230 50029221380000 1.1 NA 1.1 NA 5.1 8/14/2011 MPG-07 1910250 50029221400000 0.1 NA 0.1 NA 3.4 9/4/2011 MPG -08A 1930480 50029221410100 0.2 NA 0.2 NA 2.6 10/10/2011 MPG-09 1971170 50029227790000 1.3 NA 1.3 NA 15.3 10/30/2009 MPG -10 1971180 50029227800000 2.1 NA 2.1 NA 20.4 10/30/2009 MPG -11 1971190 50029227810000 0.8 NA 0.8 NA 5.1 8/14/2011 MPG-12 1971420 50029227920000 1.3 NA 1.3 NA 8.5 8/14/2011 MPG -13 1971200 50029227820000 1.2 NA 1.2 NA 10.2 10/30/2009 MPG -14 2011330 50029230310000 0.8 NA 0.8 NA 4.3 9/4/2011 --- MPG-15 1971220 50029227840000 2.9 NA 2.9 NA 34.0 10/30/2009 MPG -16 2032100 50029231890000 1.8 NA 1.8 NA 17.0 8/15/2011 MPG -17 2040130 50029231920000 1.6 NA 1.6 NA 14.5 8/15/2011 MPG -18 2040200 50029231940000 1.6 NA 1.6 NA 13.6 8/15/2011 MPG-19 2041920 50029232280000 1.6 NA 1.6 _ NA 13.6 8/15/2011 '" STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPS Test Report Submit to: Contractor: Nabors Rig No.: 3S Rig Rep.: J. Fritts / J.Greco Rig Phone: 659-4487 Operator: BP Op. Phone: 659- 4485 Rep.: W.Hoffman/B.Burson Field/Unit & Well No.: MPG-15 PTD # 197122Q ~ DATE: 3/14/2008 Rig Fax: 659- 4486 Op. Fax: 659-4628 Operation: Drlg: Workover: X Explor.: Test: Initial: Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: Valves: TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.: P Wetl Sim P Housekeeping: P Drl. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 Pipe Rams 1 Lower Pipe Rams Blind Rams 1 BI'md P Choke Ln. Valves 1 HCR Valves 2 Kill Line Valves 1 Check Valve 0 MUD SYSTEM: Visuat Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly Lower Kelly Bab Type Inside BOP CHOKE MANIFOLD: Quantity Test Result No. Valves Manual Chokes Hydraulic Chokes ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure Pressure After Closure 200 psi Attained Futl Pressure Attained Blind Switch Covers: All stations Nitgn. Bottles (avg}: H2S Gas Detector P P Test Results Number of Failures: Test Time: Hours Comaonents tested ALL Repair or replacement of equipment wtll be made witl~n days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Blind Rams closed on 2 7/8 tubing chanoed out blind rams and test Cci2 250/3500 contacted Chuck Sheve Cal time of incident 3-13-08 Cdt 17:30 hrs. 24 HOUR NOTICE GIVEN YES NO _ Date Time Test start 3:00 Finish BOP Test (for rigs) ~, BFL 11/14/07 ~~~~~ SUN ~~`-~ Q 2~~8 BY Witness J. Fntts/ B.Burson Nabors 3S Blind Ram Test MP G-15 3-14-08.x1s STATE OF ALASKA AL~ OIL AND GAS CONSERVATION COM~ION RECEIVEQ APR 1 7 2008 REPORT OF SUNDRY WELL OPERATION~~a Oil & Gas Cons. Commission 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 197-122 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22784-00-00 7. KB Elevation (ft): ~ 58 80 9. Well Name and Number: MPG-15 . 8. Property Designation: 10. Field /Pool(s): ADL 315848 ' Milne Point Unit / Schrader Bluff ' 11. Present well condition summary Total depth: measured 9845 feet true vertical 4508 ' feet Plugs (measured) N/A Effective depth: measured 9739 feet Junk (measured) 9579' true vertical 4423 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 9792' 7" 9822' 4490' 7240 5410 Liner ~~~ MAY ~ ~ 200 Perforation Depth MD (ft): 9256' - 9550' Perforation Depth TVD (ft): 4043' - 4273' 2-7/8", 6.5# L-80 9114' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" Baker'DB' Packers 9180' & 9329' 12. Stimulation or cement squeeze summary: Intervals treated (measured): _. ~ ~~ , SAY 1DD8 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 0 220 226 Subsequent to operation: 138 ~ 68 402 560 0 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 fhat the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mackie Derrick, 564-5891 N/A Printed Name Sondra Stewman Title Technical Assistant Prepared By Name/Number: Si Phone 564-4750 Date ~,%® ondra Stewman, 564-4750 Form 10-404 Revised 04/2006 ~ Submit Original Only ~L r Tree: 2-9/16" - 5M FMC Wellhead: 11"x12" Monobore M FMC Gen 6 w/11" x 2-7/8" FMC Tubing Hanger, 2-7/8" 8rd. top & bottom, 2.5" CIW BPV profile MPU G-15 RT Elev. = 58.8` (N22E) Orig. GL Elev. = 29.8' RT to Tbg Spool = 30.5' (N22E) 20" 91.1 ppf, H-40 112` KOP @ 300` to 500` Max Hole Angle = 82 deg. Hole angle through perfs. = 38 deg. Heat Traced to 3420' Note: Caution should be used when running ESP BHA through casing patch at 2122` 2-7/8" 6.5 ppf., L-80, 8rd. EUE tbg. (drift ID = 2.347", Cap. _ .00579 bpf) 7" 26#/ft., L-80, BTRC, production csg., (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary N Sand: -Not Stimulated. OA sand - 33.5M# 12-20 Prop-Lok resin coated Ottowa sand behind pipe. OB sand - 66.2M# 12-20 Prop-Lok resin coated Ottowa sand behind pipe. Size SPF Interval TVD 4.5" 5 "N" Sand 9256`-9272' (3984`-3996') 4.5" 5 9228 - 9294' "O A" Sand (4009'-4014`) 4.5" 4 9430'-9455' (4120`-4140') 4.5" 4 9455`-9480' (4140`-4160') "OB" Sand 4.5" 4 9530`-9550' (4199`-4215') "Jet Charges @ 0/180 deg. phasing" 'Note: Fish below bottom pert @ 9579'. (ESP Tandem Seal Sectons, Motor and Pumpmate w/6 Fin Centralizer) DATE I REV. BY COMMENTS 13/18/01 I GMH I RWO Nabors 4ES 1 7/12/06 MOR RWO Nabors 3S 03/19/08 BDB RWO Nabors 3S BP EXPLORATION OAK) Camco 2-7/8" x 1" KBMM GLM 144' 2122' ES cementer was found to be leaking during attempted completion (2-27-98) Howco internal casing patch installed (5/17/98) and pressure testedto 3000 psig - Do not exceed this test psi!!! Patch ID = 5.875" (drift = 5.75") Camco 2-7/8" x 1" KBMM GLM 2609` 2-7/8" xn nipple 2.205" ID 9012` Pump, 400P10, ` Model - SXD 9053 Std. Bolt-On Intake 8073` Model - FRSXT Intake (TVD) 3900' Tandem Seal Section 8078' Model - FST3DBHLUT Motor, 93 HP, 1760 volt, g105' 35 amp, Model FMMHG Phoenix Sensor 9107` Baker 7" DB Pkr 9180` 2.812" "XN" Nipple 9298 2.75" No-Go Baker 7" DB Pkr 9329' T~nro 7" marker jts. at 9127` to 9167' M Model - XTO w/6 centralizer, Zinc Anode 7" landing collar (PBTD) 9739' 7" float collar 9779` 7" float shoe 8822' MILNE POINT UNIT WELL G-15 API NO. 50-029-22784 ~. • BP EXPLORATION Page 1 of 5 Operations Summary Report Legal Well Name: MPG-15 Common Well Name: MPG-15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 3/9/2008 End: 3/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/16/2008 Rig Name: NABOBS 3S Rig Number: Date From - To I Hours Task ,Code NPT Phase Description of Operations -- - 3/8/2008 15:00 - 00:00 9.00 RIGD C PRE PJSM Change out transmission on # 1 rig motor, remove and set in place, roof panel and transission with MPU crane. Discussed blind pick with MPU Safety and given OK to proceed with job as long as safe work plan in place with proper communication. 3/9/2008 00:00 - 06:00 6.00 RIGD P PRE Mechanics for the installation of the transmission to return at 06:00 hrs. RD for move to MPG-15. Perform minor maintenance projects throughout the night. 06:00 - 18:00 12.00 RIGD C PRE Resume installation of transmission on #1 motor. Prepare the Pipe Shed, Pits and Carrier for Rig Move. Notified AOGCC - John Crisp; for 24 hr notice regarding upcoming BOPE test. 18:00 - 21:30 3.50 RIGD P PRE Scope down and cower Derrick @ 19:30 hrs. Held PJSM with truck crew. Move rig off Well with WSL and Pad operator present. 21:30 - 00:00 2.50 MOB P PRE Stage Rig units in position to move, notify MP security and move off MPH Pad C~3 22:30 hrs, arrive on MPG Pad ~ 23:00, Position BOP in place behind Well. 3/10/2008 00:00 - 01:30 1.50 RIGU P PRE Lay rig mats and hurculite, back Carrier over Well with WSL and Pad operator present. 01:30 - 06:00 4.50 RIGU P PRE Lay mats and herculite, position Pits, Pipe Shed and Rig components. Scope up and raise Derrick. The Rig was acce ted at 06:00 hrs on 3/10/2008. 06:00 - 13:30 7.50 KILL P DECOMP RU to the Tree to kill the well. RU double valve on the IA. Discuss well kill with Anchorage Engineering and decision made to kil! the well with Little Red assisting to increase the pump rate down the Tubing due to the high angle of the well. Call out Little Red Services from Prudhoe Bay due to Milne Point truck being worked on. Call out Hardline Trailer from Milne Point and RU hardline from the Rig to the Tiger Tank. Pressure test all surface lines to a closed choke to 3,500 psi. Pressure test the hardline to the Tiger Tank to 500 psi. Little Red arrives on location at 13:00 hrs. 13:30 - 15:00 1.50 WHSUR P DECOMP RU Lubricator and pressure test to 500 psi with diesel. Pull 2-1/2" Type "H" BPV with Well Support Techs. he pressures on the well are: Tbg = 100 psi , IA = 550 psi. 15:00 - 15:30 0.50 KILL P DECOMP Well kill safety meeting with WSL, Toolpusher, Rig Crew and Little Red Hot Oil reps. 15:30 - 16:00 0.50 KILL P DECOMP RU Little Red to the Tree with their Pump-In Sub on the Tree. Pressure test their lines - OK. 16:00 - 17:00 1.00 KILL P DECOMP Bleed the Tubing from 30 psi to 0 psi to the Tiger Tank (all gas). Shut in and observe air bubbles on the high pressure hose connected to the Tiger Tank. Blow down line and swap out prior to continuing with the well kill. Pressure test the line to 500 psi - OK. Open the well to a closed choke: Tubing = 0 psi , IA = 530 psi. Bleed the gas from the IA to the Tiger Tank. 17:00 - 18:00 1.00 KILL N RREP DECOMP Break circulation down the Tubing with the Rig Pump and had to shut down. The Super Choke panel would not function the choke open or closed. Had to re-adjust the air regulator and got it operational prior to proceeding. 18:00 - 18:30 0.50 KILL P DECOMP Well Kill safety meeting with WSL, Toolpusher, Rig Crew and Little Red Hot Oil reps. Preform pre tour checks and blow through line prior to pumping. 18:30 - 19:00 0.50 KILL P DECOMP Perform pre tour checks and blow through lines prior to Printed: 3/27/2008 1:53:52 PM BP EXPLORATION Operations Summary Report Page 2 of 5 Legal Well Name: MPG-15 Common Well Name: MPG-15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 3/9/2008 End: 3/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/16/2008 Rig Name: NABOBS 3S Rig Number: Date From - To ~ Hours Task Code NPT Phase ~ Description of Operations 3/10/2008 18:30 - 19:00 0.50 KILL P DECOMP pumping. 19:00 - 22:30 3.50 KILL P DECOMP Pumped 60 bbls of 140 deg F seawater down the Tubing, taking returns through the choke to the Tiger Tank at a rate of 2 BPM / 1,000 psi. Recovered -32 bbls. Close the Choke and bullhead 55 bbls seawater down the Tubing at 2 BPM / 1,270 psi. Shut in and observe SITP = 30 psi. Blow through line to keep from freezing. The SITP bled off to 0 psi in approximately 10 mins. Open the Choke and pump 427 bbls of heated seawater down the Tubing at a rate of 6 BPM / 2,450 psi with both Little Red and Rig Pump, taking returns to Tiger Tank. Recovered - 310 bbls. 22:30 - 23:00 0.50 KILL P DECOMP Shut down Little Red and Rig Pump and monitor shut in pressures on the well for 30 mins. Both the Tubing and 23:00 - 23:30 0.50 KILL P DECOMP Blow down and R/D Kill lines. 23:30 - 00:00 0.50 WHSUR P DECOMP Wait on seawater and the FMC rep to set TWC. 3/11/2008 00:00 - 01:30 1.50 WHSUR P DECOMP Wait on seawater and FMC rep to set TWC. 01:30 - 03:00 1.50 WHSUR P DECOMP Set TWC with FMC rep. Test from above to 3,500 psi for 30 charted min. nd tested from below b bullheadin down the Annulus at 1 BPM ~ 150 si for 30 charted min. 03:00 - 06:00 3.00 WHSUR P DECOMP RD high pressure lines. ND Tree and Adapter Flange with FMC rep. Check the Hanger threads - OK. 7-1/4 Turns on the Hanger. Utilize 30 bbl /hour fill rate down the Annulus while 06:00 - 06:30 0.50 BOPSU P DECOMP Pre-tour checks and service the Rig. 06:30 - 10:30 4.00 BOPSU P DECOMP PU the 13-5/8" 5M BOPE off the Cradle and NU to the wellhead. AOGCC inspector Chuck Scheve waived the state's right to witness the BOPE test at 07:30 hrs on 3/11/2008. 10:30 - 17:00 6.50 BOPSU P DECOMP Pressure test the BOPE per BP / AOGCC Regulations to 250 psi low and 3,500 psi high. Test the Annular to 3,500 psi. All tests passed. 17:00 - 18:00 1.00 BOPSU P DECOMP Break out and L/D test assembly. Blow down lines. Choke line froze. 18:00 - 21:00 3.00 BOPSU N DECOMP R/U steam lines and thaw choke line and kill line. Hook up air lines and blow choke and kill lines down. 21:00 - 22:30 1.50 PULL P DECOMP R/U Opso Lopso and screw into hanger, M/U polish rod extension and lubricator. Test lubricator to 500 psi with diesel. Pull 2-1/2" CIW TWC. Both tubing and IA on vacuum. R/D 22:30 - 23:00 0.50 PULL P DECOMP M/U 2-7/8" landing joint with TIW valve and screw into hanger. Made up with 11 turns. 23:00 - 00:00 1.00 PULL P DECOMP FMC wellhead tech backed out lock down screws. Pull hanger, hanger came off seat at 65,000#. Up weight 60,000#. 3/12/2008 00:00 - 01:30 1.50 PULL N DECOMP R/U and attempt to circulate well. High pressure mud line was froze in the cellar. R/U steam lines and thaw mud line. 01:30 - 02:30 1.00 PULL P DECOMP Pump 144 bbls of hot seawater down tubing taking returns out IA to the pits until clean returns at shakers. Circulate at 3 bpm with 500 psi. Lost 42 bbls of seawater while circulatin . 02:30 - 03:00 0.50 PULL P DECOMP R/D circulating assembly and blow down hose and mud line. 03:00 - 04:00 1.00 PULL P DECOMP Disconnect ESP cable from hanger, disconnect heat trace cable from hanger. Lay down hanger. 04:00 - 18:00 14.00 PULL P DECOMP POOH with ESP and heat trace completion. standing back 2-7/8" Tubing in the Derrick and spooling up the ESP and Heat Printed: 3/27/2008 1:53:52 PM BP EXPLORATION Page 3 of 5 Operations Summary Report Legal Well Name: MPG-15 Common Well Name: MPG-15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 3/9/2008 End: 3/16/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 3/16/2008 Rig Name: NABOBS 3S Rig Number: Date 'From - To Hours ' Task Code NPT Phase ~ Description of Operations 3/12/2008 04:00 - 18:00 14.00 PULL P DECOMP Trace Cables. Maintain continuous hole fill while POOH. Averaging 12-13 bbl /hour loss rate while POOH. 10 stands (20 Jts) out of the hole at 09:00 hrs. Stop and circulate the long way at 3 bpm with 600 psi to aid cleaning up some crude. 28 stands out of the hole at 12:00 hrs. Swapped out the bottom Joint of stand #51 out of the hole and the upper Joint of stand #52 out of the hole due to damage with the tongs. Finished with heat trace after stand #54. Clear and clean rig floor. 18:00 - 23:30 5.50 PULL P DECOMP POOH with ESP completion, standing back 2-7/8" tubing in the derrick and spooling up ESP cable. Maintain continuous hole fill while POOH. Averaging 12-13 bph fluid loss. Pulled total of 286 joints of 2-7/8" tubing. Recovered 545- 6' flat guards, 30 - 4' flat guards, 10 - 3' flat guards, 94 Lasalle clamps, 5 protectorlizers, 3 armster guards and 1,850 heat trace flat bands. 23:30 - 00:00 0.50 PULL P DECOMP R/D tubing handling equipment, R/U to lay down ESP. 3/13/2008 00:00 - 03:00 3.00 PULL P DECOMP UD ESP. Pump was mostly packed off with scale. There was severe corrosion on one side of ESP motor. 03:00 - 04:00 1.00 PULL P DECOMP Clear and clean rig floor. Run end of ESP cable over sheave to spooling unit. 04:00 - 07:30 3.50 CLEAN P CLEAN M/U 7" Casing Scraper and RIH on 2-7/8" Tubing out of 7:30 - 08:00 .50 LEAN P LEAN Derrick. In with 33 stands of Tubing which puts the bottom of the Scraper C~ 2074'. Work the stand up and down a few times. MU Headpin and circulate down the Tubing taking returns up the IA. Pumoed a total of 63 bbls of heated seawater at a rate of 3 bpm / 200 psi with crude returns observed on surface. ~. 08:00 - 09:00 1.00 CLEAN P CLEAN TOH with 7" Scraper Assembly standing back 2-7/8" Tubing in the Derrick. Maintaining continuous hole fill. 09:00 - 10:00 1.00 CLEAN P CLEAN On surface with Scraper Assembly. Lay down the Assembly and PU 7" RTTS with Halliburton rep. 10:00 - 11:30 1.50 EVAL P INTERN TIH with 7" RTTS on 2-7/8" Tubing from the Derrick. Maintaining continuous hole fill with seawater. 11:30 - 13:00 1.50 EVAL P INTERN In with 32 stands of Tubing and RIH 45' on stand #33 which puts the center of the element at 2,052'. PUW = 23K ,SOW = 23K. MU TIW on the Tubing. Set the RTTS with Halliburton rep and slack off all the weight above it (approximately 10K). Close the Annular and attempt to pressure test the 7" Casing to surface - no Joy. It appears there is not enough weight to get the seal on the RTTS. Release and re-set several times with same results. Confer with Anchorage Engineering and decision made to POOH and hang some more weight below the RTTS. 13:00 - 14:00 1.00 EVAL P INTERN TOH with the 7" RTTS standing back the 2-7/8" Tubing in the Derrick maintaining continuous hole fill. 14:00 - 15:00 1.00 EVAL P INTERN PU 2-7/8" Muleshoe and 17 stands (34 Jts) of 2-7/8" Tubing tom the Derrick. MU the 7" RTTS. 15:00 - 16:30 1.50 EVAL P INTERN TIH with the RTTS on 2-7/8" Tubing from the Derrick. 16:30 - 17:00 0.50 EVAL P INTERN In with stand #49 from the Derrick and RIH 41' on stand #50 putting the center of element at 2,050'. Set RTTS as per HES Rep. PUW = 23K ,SOW = 23K. MU TIW valve on the Tubing. 17:00 - 17:30 0.50 EVAL N INTERN Had incident on the Rig -- inadvertantly closed the Blind Rams Printed: 3/27/2008 1:53:52 PM • BP EXPLORATION Operations Summary Report Legal Well Name: MPG-15 Common Well Name: MPG-15 Event Name: WORKOVER Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 3S Date From..- To ;Hours Task Code ~ NPT Start: 3/9/2008 Rig Release: 3/16/2008 Rig Number: Page 4 of 5 Spud Date: 6/12/2000 End: 3/16/2008 Phase Description of Operations 3/13/2008 17:00 - 17:30 0.50 EVAL N INTERN on the 2-7/8" Tubing instead of the Annular. POOH to inspect the Joint of Tubing. Lay down the damaged Joint and PU a new one out of the Pipe Shed. Drilling HSE Advisor on the Slope, Workover Engineer and AOGCC Rep Chuck Scheve all notified immediately. 17:30 - 18:30 1.00 EVAL P INTERN Set 7" HES RTTS. R/U and pressure test 7" casing to 2,050'. 18:30 - 23:30 ~ 5.00 ~ EVAL ~ N 23:30 - 00:00 0.50 ~ EVAL P 3/14/2008 100:00 - 03:00 I 3.00 I EVAL I P 03:00 - 04:00 I 1.00 04:00 - 06:00 I 2.001 RU 06:00 - 08:30 2.50 RU 08:30 - 11:00 2.50 RU 11:00 - 18:00 ~ 7.00 ~ RU 18:00 - 19:00 ~ 1.00 ~ RUN 19:00 - 00:00 I 5.00 3/15/2008 100:00 - 04:30 I 4.50 04:30 - 09:00 I 4.50 N INTERN Open Blind rams and inspect. One ram rubber was cut. Replace blind rams. Had tested RTTS and lower set of ~ I NTERN Release 7" HES RTTS, 1/2 right hand turn and P/U to 24K. Lost 26 bbls of seawater. I NTERN POOH with 7" HES RTTS. Stand back 33 stands of 2-7/8 tubing in derrick. Break out and UD RTTS. POOH and Stand back 17 stands of 2-7/8" tubing in derrick. UD muleshoe. Maintain continuous hole fill, losing 12/13 bph seawater. I NTERN Install test plug and test blind rams to 250 psi low and 3,500 psi hig pressure. o eac tes or minutes on c art. pod Test. Pull and UD test plug. RUNCMP R/U floor to P/U ESP completion. Unhook and UD Containment trunk from dual ESP /Heat Trace sheave. RUNCMP PU and MU new ESP Assembly with Centrilift reps. SFAL R UNCMP The Generator on the ESP Spooling Unit went down. Milne Point mechanics diagnose and fix the Generator. They re-filled the oil reservoir which had lost all its oil through a loose dipstick. RUNCMP RIH with new ESP Assembly on 2-7/8", 6.5#, L-80, EUE 8rd Tubing from the Derrick. Utilizing Best-O-Life 2000 Pipe Dope on all connections with an optimum make up torque = 2,300 ft-Ibs. Maintaining continuous hole fill while RIH with the Completion. Stop every 2,000 ft to check the conductivity of the ESP Cable. Flush the pump with 10 bbls of seawater at a rate of 0.5 bpm / 850 psi. 25 stands in at 13:30 hrs. 40 stands in at 15:00 hrs. 90 stands in at 18:00 hrs. RUNCMP Run Heat Trace cable over dual ESP sheave. Bring flat guards and bands to rig floor. Clamp Heat Trace to stand #91 and check conductivity. RUNCMP RIH with new ESP completion with Heat Trace on 2-7/8", 6.5#, L-80. EUE 8rd Tubing from the derrick. Use Best-O-Life 2000 Pipe Dope on all connections with optimum make up torque of 2,300 ft/Ibs. Maintain continuous hole fill while RIH with completion. Stop every 2,000' to check conductivity of the ESP and Heat Trace cables. Flush the pump with 10 bbls of seawater at 0.5 bpm with 850 psi. RUNCMP RIH with new ESP completion with Heat Trace on 2-7/8", 6.5#, L-80. EUE 8rd Tubing from the derrick. Use Best-O-Life 2000 Pipe Dope on all connections with optimum make up torque of 2,300 fUlbs. Maintain continuous hole fill while RIH with completion. Stop every 2,000' to check conductivity of the ESP and Heat Trace cables. Flush the pump with 10 bbls of seawater at 0.5 bpm with 850 psi. 121 stds in hole at 04:30 hrs. RUNCMP Change out the reels in the Spooling Unit. Make splice in ESP cable with Centrilift rep. Printed: 3/27/2008 1:53:52 PM BP EXPLORATION Operations Summary Report Page 5 of 5 Legal Well Name: MPG-15 Common Well Name: MPG-15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 3/9/2008 End: 3/16/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/16/2008 Rig Name: NABORS 3S Rig Number: r Date ;From - To ,Hours Task Code ~ NPT Phase Description of Operations 3/15/2008 ~ 09:00 - 11:00 ~ 2.00 ~ RU 11:00 - 12:00 I 1.001 RU 12:00 - 17:00 I 5.001 RU 17:00 - 18:00 ~ 1.00 ~ RU 18:00 - 19:30 ~ 1.50 ~ RU 19:30 - 21:00 I 1.501 RUN 21:00 - 22:30 I 1.501 RU 22:30 - 23:00 I 0.501 RU 23:00 - 23:30 I 0.501 WHSUR I P 23:30 - 00:00 0.50 WHSUR P 3/16/2008 00:00 - 01:30 1.50 WHSUR P 01:30 - 04:00 ~ 2.50 ~ BOPSUF~ P 04:00 - 07:00 ~ 3.00 WHSUR ~ P 07:00 - 08:00 ~ 1.00 ~ W HSUR ~ P 08:00 - 10:00 I 2.001 WHSUR ~ P RUNCMP Resume RIH with ESP Completion and heat trace on 2-7/8" Tubing from the Derrick. RUNCMP The Gen Set on the Spooling Unit blew oil through the dipstick again. Milne Point mechanics arrive on location and troubleshoot. The cause is believed to be the breather tube might be freezing up and causing pressure to build and releasing by popping the dipstick. Thaw out the tube and re-fill the reservoir with new oil. RUNCMP Continue RIH with ESP Completion and heat trace on 2-7/8" Tubing from the Derrick. Hole loss averaging 12-13 bbls / hour. 140 stands in at 16:00 hrs. RUNCMP Ran a total of 286 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing. MU Headpin and flush the ESP pump a final time with 10 bbls of seawater at a rate of 0.5 bpm / 800 psi. Ran total of 95 LaSalle clamps, 555 - 6' Flat guards, 14 - 4' Flat guards, 9 - 3' Flat guards, 3 Armster guards, 5 Protectolizers and 1,709 bands. RUNCMP M/U hanger and orient. Install penetrators in hanger. Measure and cut ESP and Heat Trace cables and run ends back over dual ESP sheave. RUNCMP Splice end onto Heat Trace cable and check conductivity. Connect to penetrator. RUNCMP Splice end onto ESP cable and check conductivity. Connect to penetrator. RUNCMP Land tubing hanger. Up weight 52K, Down weight 32K. Run in lock down screws. WHDTRE Install 2-1/2" CIW TWC. TWC was installed by FMC wellhead tech. WHDTRE R/U to test TWC. WHDTRE Test TWC from above to 1,000 psi for 30 minutes on the chart, Test from below by injecting at 1 bpm with 210 psi for 30 minutes on chart. WHDTRE Blow down lines, drain BOP stack, unhook turnbuckles, pull riser, unhook koomey lines and N/D BOPE and place stack in cradle. WHDTRE Clean and prep Tubing Spool. Install new Adapter Flange and Tree. Pre-tour checks with day crew. Centrilift perform final ESP and Heat Trace checks: Pressure at intake = 1,683 psi ; Temperature at intake = 77.5 degF ;Temperature at motor = 76.6 degF ;ESP phase to phase = 4.2 ohms ;ESP phase to ground = 1.52 Gigaohms ;Heat Trace phase to phase = 3.8 ohms ;Heat Trace phase to ground = 11 Gigaohms. WHDTRE Pressure test the Hanger void with FMC rep to 5,000 psi for 30 mins -good. Fill the Tree with diesel and test to 5,000 psi - good. Drain the Tree. WHDTRE PU and MU the Lubricator with Well Support Techs. Pressure test to 500 psi with diesel -good. Pull the TWC. The Tubing is on a vacuum. Seta 2-1/2" Type "H" BPV. RD the Lubricator. Secure the Tree and Cellar area. Check the IA and it is on a vacuum as well. The Rig was released at 10:00 hrs on 3/16/2008. Printed: 3/27/2008 1:53:52 PM STATE OF ALASKA 11114107 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nabors Rig No.: 3S Rig Rep.: J. Fritts / E. Potter Rig Phone: 659-4487 Operator: BP Op. Phone: 659- 4485 Rep.: W.Hoffman/B.Burson Field/Unit & Well No.: MPG-15 PTD # 1971220 Operation: Drlg: Workover: X Test: Initial: X Weekly: Test Pressure: Rams: 250/3500 Annular. 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test ResuR Location Gen.: P Well Sign P Housekeeping: P Dr1. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK : Quantity Size Test Result Annular Preventer 1 13 5/8 5000 P Pipe Rams 1 2 7/8 x 5 P Lower Pipe Rams Blind Rams 1 Blind P Choke Ln. VaNes 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 1? Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Usual Test Alarm Test Trip Tank P P Pit Level Indicators P P Flow Indicator P P Meth Gas Detector P P H2S Gas Detector P P Test Results DATE: 3/11/2008 Rig Fax: 659- 4486 Op. Fax: 659-4628 Explor.: Bi-Weekly Valves: 250/3500 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 NT Lower Kelly 1 NT Ball Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quantity Test Result No. Valves 13 P Manual Chokes 1 P Hydraulic Chokes _ 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 3000 P Pressure After Closure 1550 P 200 psi Attained 26sec P Full Pressure Attained 2 min 5 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 ~ 1925 Number of Failures: 0 Test Time: 6 Hours Components tested ALL Repair or replacement of equipment w~ be made wittfin days. Notify the Norih Slope Inspector 659-3607, follow with written confirmation to Superviser at: Remarks: Tested with a 2 7/8" test joint f Greased #12 choke valve Greased manual choke valve 24 HOUR NOTICE GIVEN YES X NO Waived By Chuck Scheve Date 03/09/08 Time 1630hrs start 1030 hrs Finish BOP Test (for rigs) BFL 11/14/07 ~~~ MAR ~ ~ 2108 W"rtness J. Fritts! W. Hoffman Nabors 3S BOP Test MP G-15 3-11-08.x1s Page 1 of 1 Maunder, Thomas E (DOA) From: Stewman, Sondra D [Sondra.Stewman@bp.comj Sent: Tuesday, October 16, 2007 11:22 AM To: Maunder, Thomas E (DOA) Subject: RE: MPG -15 (197 -122) Attachments: MPG -15, RWO, 03- 2001.pdf Tom, Attached is the documentation you requested for MPG -15, 197 -122. Please advise if I can be of assistance. Thank you, Sondra Stewman ADW Drilling TA _ MAR 1 Z s Oil , Diversity & Inclusion Resource D &I Info: http / /alaska.bpweb.bp.com /di Be real, be present and most of all be POSITIVE! From: Maunder, Thomas E (DOA) [mailto:tom.maunder @alaska.gov] Sent: Tuesday, October 16, 2007 9:46 AM To: Stewman, Sondra D Subject: MPG -15 (197 -122) Sondra, I am reviewing the latest 404 for a pump acid job on this well and was checking the file. There is a 404 in the file received -April 19 reporting work apparently done in 1Q 2001. The work summary attached is for work done in June 2000. The 404 for that work was received August 4, 2000. Could you please send the correct summary for the 1Q 2001 work? Email is fine. Tom Maunder, PE AOGCC 10 /1 6/2007 • • BP EXPLORATION Page 1 of 1 Operations Summary Report Legal Well Name: MPG -15 Common Well Name: MPG -15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 3/10 /2001 End: 3/18/2001 Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 3/17/2001 Rig Name: NABORS 4ES Rig Number: 4ES Date From - To Hours Task Code NPT Phase Description of Operations 3/14/2001 01:00 - 02:30 1.50 RIGD POST Scope and Lower Derrick on MPE -30 02:30 - 03:30 1.00 RIGD POST Prep rig to move from MPE-30 to MPG -15 03:30 - 06:30 3.00 MOB PRE Move rig from MPE -30 to MPG -15 06:30 - 09:00 2.50 RIGU PRE Spot and Berm Rig 09:00 - 11:00 2.00 RIGU PRE Raise and Scope derrick. Rig accepted at 11:00 Hrs 03 -14 -01 11:00 - 13:30 2.50 RIGU PRE Rig up tiger tank and take on 9.8 ppg brine, hook up lines to tree. heat brine to 9.8 ppg 13:30 - 14 :30 1.00 RIGU PRE Rig up Lubricator and Pull BPV. &00 psi on tubing. 14:30 - 17:00 2.50 RIGU PRE Continue to heat 9.8 brine to 140 deg. , Rig up double sheave and elephant trunk. 17:00 - 21:00 4.00 KILL DECOMP Test lines to 3,000 psi. Open up to well with 600 psi on tubing and 850 psi on annulus. Began well kill at 3.5 bbl. /min rate at 1050 psi. Bullhead influx 20 bbls at 3 bpm . Final 3.5 bpm Q 800 psi. Circulated 275 bbls of oil and trace of water to tiger tank. 21:00 - 21:30 0.50 KILL DECOMP Monitor well . Well static 21:30 - 22:00 0.50 PULL DECOMP Set TWC and test to 3,500 psi. 22:00 - 23:00 1.00 PULL DECOMP Bleed Hanger Void and ND Tree 23:00 - 00:00 1.00 PULL DECOMP Nipple Up Test spool and NU BOPE 3/15/2001 00:00 - 02:00 2.00 PULL DECOMP Nipple Up Test spool and NU BOPE & Change Rams 02:00 - 05:00 3.00 PULL DECOMP Test BOPE to 25013500 psi annular 250/2,500 psi 05:00 - 05:30 0.50 PULL DECOMP PU LUB & Pull TWC ID LUB 05:30 - 07:00 1.50 PULL DECOMP PU Landing JT/ BOLDS pull Hanger to the floor. PU Wt. 54 K SO Wt. 35 K . Test ESP and HT Cable. LD Hanger and LD Jt 07:00 - 16:30 9.50 PULL DECOMP Pull Heat trace ESP Completion and SLM to 3,500' 16:30 - 18:00 1.50 PULL DECOMP Clear rig floor of HT equipment Clean rig floor 18:00 - 21:00 300 PULL DECOMP Continue to POH with ESP completion 21:00 - 22:00 1.00 PULL DECOMP Change out spool in spooling unit 22:00 - 23:00 1.00 PULL DECOMP Continue to POH with ESP completion 23:00 - 00:00 1.00 PULL DECOMP Laydown pump and motor. lost 1 2' flat guard and 2 bands. 3/16/2001 00:00 - 01:00 1.00 PULL DECOMP Laydown pump and motor. lost 1 2' fiat guard and 2 bands. 01:00 - 02:00 1.00 PULL DECOMP Clear rig floor rig up to PU Pump /Motor 02:00 - 04:30 2.50 PULL DECOMP PU Pump/Motor & service. Test motor and cable 04:30 - 10:00 5.50 PULL DECOMP RIH with 2 7/8" ESP assembly 10:00 -11:30 1.50 PULL DECOMP Rig up to run heat trace 11:30 - 21:00 9.50 PULL DECOMP Continue to RIH with 2 7/8" ESP Completion and HT 21:00 - 23:00 2.00 PULL DECOMP Make ESP cable Reel to Reel splice 23:00 - 00:00 1.00 PULL DECOMP Continue to RIH with 2 7/8" ESP Completion and HT at 8,100' 3/17/2001 00:00 - 03:30 3.50 RUNCOM COMP Continue to RIH with 2 7/8" ESP Completion and HT 03 :30 - 04:00 0.50 RUNCOM COMP Pick Up landing joint - Make up Hanger and penetrators 04:00 - 09:30 5.50 RUNCOM COMP Make Heat Trace and ESP EFT Splice 09:30 - 10:00 0.50 RUNCOM COMP Land Hanger , RILDS Pick up wt= 54 K and SO WT = 29 K Back out landing joint 10:00 - 10:30 0.50 WHSUR COMP Install TWCV and test to 3500 psi. 10:30 - 13:00 2.50 WHSUR COMP Nipple Down BOPE 13:00 - 14:00 1.00 WHSUR COMP Nipple up tree 14:00 - 14:30 0.50 WHSUR COMP Test tree to 5,000 psi 14:30 - 16:30 2.00 WHSUR COMP Pull TWC and install BPV, Secure well and Clear floor area, final check ESP and Heat trace. 16:30 - 17:00 0.50 WHSUR COMP Rig down double sheave. Rig released at 17:00 hrs 03 -17 -01 Printed: 10/18/2007 10:52:52 AM STATE OF ALASKA ~~`~~''~~ ALASKA OIL AND G,AS CONSERVATION COM~ION REPORT OF SUIVDRY WELL OPERATIONS ~S 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Q ACID TREATMENT Performed: Alter Casing ~ Pull Tubing ~ P~~rforate New Pool ~ Waiver ~ Time Extension Change Approved Program ~ Operat. Shutdown Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 197-1220 3. Address: P.O. Box 196612 Stratigraphic Service ' 6. API Number: Anchorage, AK 99519-6612 50-029-227$A-00-00 ' 7. KB Elevation (ft): 9. Well Name and Number. 58.8 KB ~ MPG-15 - 8. Property Designation: 10. Field/Pool(s): ADLO-315848 ~ MILNE POINT Field/ SCHRADER BLFF OIL Pooi 11. Present Well Condition Summary: Total Depth measured 9845 feet Plugs (measured) None true vertical 4507.88 feet Junk (measured) None Effective Depth measured 9739 feet true vertical 4423 feet -- Casing Length Size MD TVD Burst Collapse Conductor 80' 20" Surface - 112' Surface - 112' 1490 470 Production 9792' 7" 26# L-80 Surface - 9822' Surface - 4490' 7240 5410 Perforation depth: Measured depth: 9256 - 9272 9288 - 9294 9430 - 9455 9455 - 9480 9530 - 9550 True Vertical depth: 4042.99 - 4055.48 4067.98 - 4072.66 4179.06 - 4198.68 4198.68 - 4218.33 4258 - 4273 Tubing: (size, grade, and measured depth) 2-718" 6.5# L-80 SURFACE - 9109' Packers and SSSV (type and measured depth) 0 0 o ~~;~~C~~ N01~ ~ ~U~f~ o 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Shut in 0 0 0 0 Subsequent to operation: Shut in 123 178 0 258 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory Development ~ Service Daily Report of Well Operations X 16. Well Status after proposed work: 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 N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Pr Title Data Management Engineer Signatur Phone 564-4944 Date 10/8/2007 Form 10-404 Revised 04/2006 (~ ~ ~ ~ ~ {~ ~ ~ ~ 7-~"'~~~, ~ d,-LG (~~ Submit Original Only MPG-15 • DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 9/28/2007 T/1=350/420. (Acid treatment). Spear into tbg w/ 5 bbls crude for infectivity ;test. Pump 6 bbls 7.5% DAD acid followed by 43 bbls crude down tbg to spot -;acid on ESP. Turn well over to DSO. FWHP=500/500. 10/4/2007 ASRC Unit 1 flow and test MPG-15 10/6/2007;ASRC Unit 1 Flow and test MPG-15 *Job complete' FLUIDS PUMPED BBLS 48 CRUDE 6 7.5% DAD ACID 3 60/40 METH 57 TOTAL _ STATE OF ALASKA . ALAWA OIL AND GAS CONSERVATION COM SION REPORT OF SUNDRY WELL OPERATIONS RECEIVED JUL 1 9 2006 Ii I",,, I, rL: 1. Operations Performed: "~ ..... \JI lJélS (;Ons. Commiss' o Abandon 181 Repair Well o Plug Perforations o Stimulate o Re-EnteAaQbP.d Well o Alter Casing 181 Pull Tubing o Perforate New Pool o Waiver 181 Other o Change Approved Program o Operation Shutdown 181 Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 197-122 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22784-00-00 7. KB Elevation (ft): 58.80 9. Well Name and Number: MPG-15 8. Property Designation: 10. Field / Pool(s): ADL 315848 Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9845 feet true vertical 4508 feet Plugs (measured) Effective depth: measured 9739 feet Junk (measured) true vertical 4423 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' 1490 470 Surface Intermediate Production 9792' 7" 9822' 4490' 7240 5410 Liner ,¡''') , ..'- r\ '1:1;,,, ,,_,,~ ¿~., Perforation Depth MD (ft): 9256' - 9550' Perforation Depth TVD (ft): 4043' - 4273' 2-7/8",6.5# L-80 9109' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Fl ,¡UL 2 0 2D06 Treatment description including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubina Pressure Prior to well operation: 0 0 0 320 0 Subsequent to operation: 0 0 0 400 0 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Service 181 Daily Report of Well Operations o Exploratory 181 Development 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ OWINJ o WDSPL 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 Bryan McLellan, 564-5516 Printed Name Sondra Stewman/ Title Technical Assistant ~nature ~ ~iÎ/..rÌ'\ ') ~ Prepared By Name/Number: Phone 564-4750 DateOì-l ~~()(P Sandra Stewman, 564-4750 - . ' Form 10-404 Revised 04/2006 on ORIGINAL Submit Onglnal Only ~ 2-9/16" - 5M FMC . Wellhead' 11"x12" Monobo~ FMC Gen 6 w/11" x 2-7/8" FMC Tubing Hanger, 2-7/8" 8rd. top & bottom, 2.5" CIW BPV profile 20" 91.1 ppf, H-40 ~ KOP @ 300' to 500' Max Hole Angle = 82 deg. Hole angle through perfs. = 38 deg. Heat Traced to 3420' Note: Caution should be used when running ESP BHA through casing patch at 2122' 2-7/8" 6.5 ppf., L-80, 8rd. EUE tbg. (drift ID = 2.347", Cap. = .00579 bpf) T' 26#/ft., L-80, BTRC, production csg., (drift ID = 6.151", cap. = 0.0383 bpf) Stimulation Summary N Sand: - Not Stimulated. OA sand - 33.5M# 12-20 Prop-Lok resin coated Ottowa sand behind pipe. OB sand - 66.2M# 12-20 Prop-Lok resin coated Ottowa sand behind pipe. Perforation Summary Ref Log 07/25/97 DGR Size SPF Interval TVD "N" Sand 4.5" 5 9256'-9480' (4043'-4218') "0 A" Sand 4.5" 4 9430'-9455' (4180'-4197') "OB" Sand 4.5" 4 9530'-9550' (4258'-4274') "Jet Charges @ 0/180 deg. phasing" MPU G-15 .. RT Elev. : 58.8: (N22E) ~. GL Elev. - 29.8 RT to Tbg Spool = 30.5' (N22E) Camco 2-7/8" x 1" KBMM GLM 143' DATE REV. BY COMMENTS 3/18/01 GMH RWO Nabors 4ES 7/12/06 MOR RWO Nabors 3S 2122' I Camco 2-7/8" x 1" KBMM GLM 2609' 2-7/8" xn nipple 2.205" ID I 9012' Pump, 214 stg. FC925, I Model - FPMT AR 1: 1 . 9053' Std. Bolt-On Intake 9073' Model - FRSXTBAR Intake (TVD) Tandem Seal Section Model - FSB3UTFER 3900' 9077' Motor, 72 HP, 1130 volt, 9105' 41 amp, Model FME PumpMate w/6 fin 9107' Centralizer Two T' marker jts. at 9127' to 9167' MD 7" landing collar (PBTD)I 7" float collar I I 9739' 9779' 7" float shoe 9822' MILNE POINT UNIT WELL G-15 API NO. 50-029-22784 BP EXPLORA TIONJAK) e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: N3S Spud Date: 6/12/2000 End: 6/21/2006 00:00 - 06:00 06:00 - 12:00 12:00 - 17:00 17:00 - 21 :30 21 :30 - 00:00 6/22/2006 00:00 - 09:00 09:00 - 11 :00 11 :00 - 12:00 12:00 - 14:00 14:00 - 16:30 16:30 - 17:30 17:30 - 21 :00 21 :00 - 23:00 23:00 - 00:00 6.00 6.00 POST PRE 5.00 PRE 4.50 PRE 2.50 PRE 9.00 RIGU PRE 2.00 RIGU PRE 1.00 RIGU PRE 2.00 KILL DECOMP 2.50 KILL DECOMP 1.00 KILL DECOMP 3.50 KILL 2.00 KILL DECOMP DECOMP 1.00 KILL DECOMP Prepare rig for move. Lower Derrick and disconnect modules. Rig maintenance as waiting for location preparations on MPG-15. Needle gun pins and Derrick legs, Blocks and Bales w/ Tuboscope inspection. Site assessment for temporary buildings done in w/ MPU OTL, DSO, Well Ops Supv. Veco haul flow back tank and various loads of rig support equpment to location, including bunks of 3 1/2" DP for workstring. Notified AOGCC of upcoming BOPE test. Camp on location. Do pre-rig inspection w/ DSO. Continue to move miscellaneous support equipment, and rig modules. One Peak Sow to move Camp and Rig. Carrier and pits on location. Sow to roundtrip to F-pad for pipe shed. Spot rig and lay herculite containment, and Berms. MIRU Nabors 3S. Spot Rig over the well. Spot Pits and Pipe Shed. Raise Derrick. Continue to rig up and hook up auxilliary equipment. Contact state for 24 hr notice of BOPE testing. Accept rig @ 09:00. Pull BPV. WHP's T/IA - 350/200 psi. LRS on location for pumping. Rig up choke and HCR to double valve on annulus. Test hardline to tubing to 3000 psi, ok. Test choke line to closed choke to 1500 psi, ok. Wait on Veco Vac trucks to bring 8.7 #/gal brine for kill. Trucks caught behind rig move on Spine Rd from Prudhoe. PJSM Discuss well kill pump schedule. Pump 8.7 #/gal Brine @ 120 deg F w/ LRS down tubing taking returns through choke to Tiger tank. Pump 60 bbls @ 2.5 BPM 900 psi down tubing, 450 psi on annulus. Close choke and bullhead 40 bbls (2 times RH volume) into formation @ 2 BPM 950 psi. Open choke and increase rate to 2 1/2 BPM 650 psi Tbg and 450 psi trapped on annulus Circulate 8.7 #/gal Brine down Tubing trapping pressure on Annulus per kill sheet. Pump 400 Bbls until 8.7 #/gal Brine in and out. Shut in for flow check. SITP and SICP of 50 psi. Observe for 30 minutes. Circulate additional 40 Bbls 8.7 #/gal Brine down tubing with 8.7#/gal returns. Total volume circulated - 440 Bbls, 37 Bbls lost to formation during circulation. (surface to surface=320 Bbls) SITP and SICP of 40 psi. Calculate kill wt fluid required with 40 psi and 85 psi trip margin to be 9.3 #/gal. 135 bbls 8.7#/galleft in Vac truck. Send Vac truck w/135 Bbls of 8.7 #/gal Brine to D pad to take on 155 Bbls of 9.8 #/gal from storage tank. Call Prudhoe for another truck to bring 100 Bbls 140 deg F water to add to 150 bbls of 9.8 #/gal Brine from storage to make 9.3 #/gal. Wait on Brine. Brine trucks on location. PJSM discuss 2nd circulation kill. Pump 9.3 #/gal @ 3 BPM 800 psi Tbg, trap 80 psi annulus. Pump 60 Bbls, reduce rate to 2 BPM, close choke and bullhead 40 Bbls into formation @ 500 psi. Open choke and continue to circulate 9.3 #/gal brine taking returns and trapping 40 to 60 psi on annulus. 240 Bbls circulated, losses of 19 Bbls. Circulate 9.3 #/gal Brine @ 3 BPM, 750 psi Tbg, 40 psi annulus. Hole volume of 320 Bbls, 360 Bbls circulated Weigh returns @ 9.3 #/gal. Losses to formation during 2nd circulation Printed: 7/10/2006 7:21:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: N3S Spud Date: 6/12/2000 End: 6/22/2006 23:00 - 00:00 1.00 KILL DECOMP of 17 Bbls. Shut down and monitor well for 30 minutes. 0 psi on Tbg and Ann. Tbg and Annulus on slight vacuum. Set TWC and test to 1000 psi from above. 6/23/2006 00:00 - 06:00 6.00 KILL DECOMP NO Tree. NU BOPE. State witness of testing waived by Chuck Scheve. 06:00 - 10:00 4.00 KILL DECOMP Continue to NU BOPE. 10:00 - 16:00 6.00 BOPSU DECOMP Fill stack and HCRlChoke with water checking for leaks. Start BOPE test wI 2 7/8" test joint for initial testing of VBR. Test all components to 250 psi low 13500 psi high. Test annular to 3500 psi. Test VBR with 3 1/2" test joint. Test Accumulator System. 16:00 - 20:00 4.00 PULL DECOMP Pump out stack. Hook up gauge to annulus, 0 psi. PUMU Opso-Lopso into Tbg Hgr. Waiting on "elephant trunk" from Kuparuk to rig up off of shieve for ESPIHeat Trace cable. MU Lubricator and pull TWC. Tbg pressure-O psi, slight vacuum. Break out Opso-Lopso. leave bottom xo in hanger. 20:00 - 21 :30 1.50 PULL DECOMP Elephant trunk on location. Rig up to shieve. Call for XO from Tool Svc. Load joint of 31/2" DP, Change out eleveators. MU XO to bottom of 31/2" landing joint and torque appropriately. 21 :30 - 22:30 1.00 PULL DECOMP Pull tbg hgr to rig floor, 65K to break, 62K to pull, no pressure. LD tbg hgr and fill hole with 15 bbls brine. 22:30 - 00:00 1.50 PULL DECOMP Run ESP cable and Heat Trace through elephant trunk to dbl spooler. POOH I completion, strapping tbg as standing back in derrick. 6/24/2006 00:00 - 03:00 3.00 PULL DECOMP POOH wI completion, spooling ESP and Heat Trace cables on dbl spooler. Strap Tbg as standing back in Derrick. 03:00 - 04:00 1.00 PULL DECOMP CO ESP spool, clean up floor. 04:00 - 10:00 6.00 PULL DECOMP POH wI ESP and Heat Trace, standing back and strapping 2 7/8" Tbg in Derrick. Heat Trace on 109 jts, 2 GLMs (3458'). 10:00 - 15:00 5.00 PULL DECOMP Clear and Clean floor of flatbands. Continue POH wI ESP, standing back and strapping Tbg in Derrick. Pull ESP through patch @ 2122' with no indications or problems. 15:00 - 17:00 2.00 PULL DECOMP 120 Stds of 2 7/8" Tbg OOH. 17:00 - 17:30 0.50 PULL DECOMP POH 143 stands Tbg. 62 Bbls of 9.3 #Igal Brine lost to formation as POH. Last 15 joints of tubing (above ESP) severely scaled up. Areas of corrosionlpitting which could be through Tubing. Perforations in bottom 1/3 of 2nd full joint above ESP. 1st full joint and pup joint above ESP packed off with scale. No sign of 0&0 Holefinder cup. As cut band on last clamp (on flat cable) cable came OOH and up toward shieve. Appears as though cable pulled out of pothead connector. Pull remnants of ESP to surface. 17:30 - 18:00 0.50 PULL DECOMP ESP missing from below pump intake (at the flange). ESP left in hole = 11.17' I 4.00" 00 tandem seal section and 10.68' I 4.50" 00 motor section. OAL-23.75'. Bolts missing from flange between pump intake and seal section. 18:00 - 19:00 1.00 PULL DECOMP Clean rig floor. Lay down 12 stands of scaled up tubing from Derrick. (3 joints layed down above ESP), for total of 15 joints discarded. Discuss options with MPU operations and RWO engineer. 19:00 - 22:00 3.00 PULL DECOMP Finish preperation of rig floor. PU XO's and 4.75" 00 mule shoe. RIH and set wear ring. Fill hole with 5 bbls brine. 22:00 - 00:00 2.00 CLEAN DECOMP RIH 125 jts 2-7/8" tubing from pipe shed. RIH with tubing from Printed: 7/10/2006 7:21:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 35 Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: N3S Spud Date: 6/12/2000 End: 6/24/2006 22:00 - 00:00 2.00 CLEAN DECOMP derrick. 6/25/2006 00:00 - 01 :30 1.50 CLEAN DECOMP RIH with tbg-DP to tag fish. Stopped at 2085' MD checked PU/SO, (20K 120K). No trips or bobbles working through patch @ 2122'. Starting pit volume 221 bbls. 01 :30 - 04:30 3.00 CLEAN DECOMP Continue to RIH with tbg/DP to tag fish. Stopped at 8957' checked PU/SO, (40K I 18K). RIH with rest of tubing to 9334' without tagging fish. 04:30 - 06:00 1 .50 CLEAN DECOMP Rigging up floor for running 3.5" DP. Continue RIH with DP to tag seal section and motor. Lost 38 bbls 9.3 ppg brine from midnight to 0600. Tag top of fish @ 9579'. 06:00 - 10:30 4.50 CLEAN DECOMP Jet and Reverse on fish short tripping @ 4 Bpm I 450 psi csg pressure, stacking 15 K #'s, unable to make any hole. PU off of fish, reduce rate to 2.5 Bpm I 330 psi csg pressure, losses @ 3/4 Bpm. Mix and pump 30 Bbl Duo-Vis sweep. Reverse circulate viscous pill from surface to surface. 4 Cu yds of sand and scale in the returns. Displace wI 400 Bbls. Lost 52 Bbls to formation during reverse circulaton. 10:30 - 12:00 1.50 CLEAN DECOMP POH and laydown 10 jts of 31/2" DP. Muleshoe @ 9334'. Flowcheck well for 30 minutes. losses of 1.8 Bbls in 30 minutes (3.5 BbI/Hr). 12:00 - 15:00 3.00 CLEAN DECOMP POH standing back 2 7/8" Tubing in the Derrick. 15:00 - 17:30 2.50 CLEAN DECOMP 80 Stds in Derrick, Pit Volume of 124 Bbls, 24 Bbls hole fill. (12 Bbls lost to formation). 17:30 - 18:00 0.50 CLEAN DECOMP 149 Stds OOH. Break out and lay down Muleshoe. 18:00 - 22:00 4.00 CLEAN DECOMP Clean floor, RU for running Dummy packer drift. 5.69" OD I 4.45' length. RIH with drift onTbg. RI to 2050' checked PU/SO, (20K I 19K). No hitches running through patch @ 2122', and to 2328'. POH through patch, smoothlno weight indication. Continue POOH 22:00 - 00:00 2.00 PERF DECOMP Ready floor for SLB. PUMU TCP BHA on 2-7/8" tbg from derrick, RIH as per tally. 6/26/2006 00:00 - 01 :00 1.00 PERF DECOMP Finish PUMU TCP BHA, RIH on tbg as per tally. SLB assy 4.5" PJOmega 4505 @ 5 spf. 47' of loaded guns, 184 ft of blanks, total BHA OAL - 239.82'. Firing head for 1/2" ball, 518" ball to disconnect. Guns loaded to perforate intervals 9256'-9272', 9288'-9294', 9455'-9480'. 2 ea 10' pup joints and 1 ea 2 7/8" RA tag run 1 stand above guns. 01 :00 - 05:30 4.50 PERF DECOMP RIH with TCP. Leave 2.5' stump in slips. Lost 36 bbls since 00:00. PJSM discussing rig up procedures and risks associated with SLB e-line to rig floor. Discussed handling of the tools. 05:30 - 09:00 3.50 PERF DECOMP RU SLB for e-line logging. PUMU 1-11/16" GR-CCL wI SL rollerstem. RIH to 1000'. POOH and secure well. Rig down SLB, MU head pin and pump line to Tbg. Problems with remote panel for BOPE. Panel in doghouse not working. 09:00 - 14:30 5.50 RREP DECOMP Standby waiting for Nabors mechanics to repair hydraulic valve for remote panel of Koomey Unit and BOPE. 14:30 - 15:00 0.50 DECOMP Rig up SLB pump in sub, line wiper, flow tubes and GR-CCL logging tools. RIH to tie in TCP assy. 15:00 - 17:00 2.00 DECOMP RIH to 3248', unable to get any deeper. Work pump rate from 2 BPM - 4 BPM I 60 psi Tbg pressure. Check manifold and valves. Re-align and attempt to pump e-line tools in hole again. Clean pill pit and call for EP mud lube. Check manifold Printed: 7/10/2006 7:21:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: N3S Spud Date: 6/12/2000 End: and kill line open. RBIH wI logging tools pumping 2 bpm, 330 psi Tbg pressure. Work thru several "humps" in well bore and RIH to 9192' and log up to 8400'. Tie in to RA tag wI 10' marker pup jts of 2 7/8" Tbg. Correlate to Sperry Sun MWD dated 12 September 1997. Guns are on depth. -29' correction log to MD. This puts fish @ 9550' (depth of bottom "OB" sand perforations) 19:30 - 20:30 1.00 PRFAD N DECOMP POH wI SLB e-line. 20:30 - 00:00 3.50 PRFAD N DECOMP RU SLB and drop 5/8" ball. Pressure up to 2800 psilfire guns. Check pressure 10 psi at tbg. Weight up to 9.8 ppg to kill well, includes 80 psi trip margin. Take volume in pits down for weight up. Hose failure. Lost 3 gal. fluid (9.3 ppg brine) outside berm, 2 gal. inside containment from failed hose. Cleaned up, spill notified proper authorities, continued with well kill operations. Lost 113 bbls 9.3 ppg brine last 24 hours 6/27/2006 00:00 - 03:30 3.50 KILL P DECOMP Take pits down to make room for weight up. Mix NaCI for a 9,8 ppg brine. Bring 290 bbls 9.8 ppg brine from D pad. Line up 2 empty vacs for fluid disposal. 03:30 - 06:00 2.50 KILL P DECOMP Start 9.8 ppg NaCI kill fluid down hole. Start 60 csg, 40 tbg. Pump fluid around, shut down with 9.8+ ppg coming back at 370 bbls pumped away. Bleed lines, open bag with 0/0 on csg/tbg. Fill hole with 3 bbls, shut down and monitor. 06:00 - 07:00 1.00 KILL P DECOMP Flowcheck well. 1.6 Bbls to fill. Losses of 3.2 BPH. POH 5 stands to position guns above top perforation and flow check well prior to POH. PU wt off bottom of 51 K. Fill hole w/3 Bbls (2 bbls loss to formation). 07:00 - 13:00 6.00 P DECOMP POH and SIB 120-stds of 2-7/8" tubing in Derrick. UD Std #81, which had a bad pin end on the bottom joint. 13:00 - 14:00 1.00 P DECOMP POH and UD 32-jts of 217/8" tubing through Pipe Shed. 14:00 - 15:00 1.00 P DECOMP POH and SIB 14-stands of 2-7/8" in Derrick. 15:00 - 15:30 0.50 P DECOMP Hold PJSM to breakout and UD TCP guns. 15:30 - 18:00 2.50 P DECOMP Break out and UD Schlumberger TCP guns. All shots fired successfully. 18:00 - 18:30 0.50 CLEAN P DECOMP Clear and clean rig floor. Prep to PUMU Weatherford/Reeves Under-Reammer BHA. 18:30 - 20:00 1 .50 CLEAN P DECOMP PUMU WeatherfordlReeves Under-Reamer, 2-7/8" PDM, Circ. Sub, 2-718" MHA, 5.70" Gauge Sub, 3-1/2" Pump-Out Sub. 20:00 - 00:00 4.00 CLEAN P DECOMP RIH w/Weatherford BHA on 3-1/2" DP 1 x 1 from pipe shed. 6/28/2006 00:00 - 12:00 12.00 CLEAN P DECOMP RIH w/Weatherford/Reeves Under-Reamer BHA 1x1 on 3-1/2" DP from pipe shed. 120 jts. RIH @ 0140-hrs. 180 jts. RIH @ 0445-hrs. #270 @ 0930-hrs. Saw no tight spots while RIH. 12:00 - 15:00 3.00 CLEAN P DECOMP Establish parameters with stand #148 buried: P/U wt 94K, SIO wt 40K, initial pump rate 45-SPM (1.07-BPM), then increase slowly to 105-SPM (2.5-BPM). Pull and ream with stand #148 at 8-ftImin and see pressure increase from 1150-psi to 1350-psi; ream down full stand, then ream back up, and back down. See no indication of increasing pressure or change in P/U or SIO weights. Break off circulating head and POH and SIB stand #148. Perform same Yo-Yo routine with stands 147, 146, and 145. Did not see anything other than 10 to 20-psi pump pressure change that would indicate any tight spots from 9141' to 9394'. 15:00 - 15:30 0.50 CLEAN P DECOMP RIH wI DP stands 145, 146, 147, and 148 and drop dart to Printed: 7/10/2006 7:21:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: N3S Spud Date: 6/12/2000 End: 6/28/2006 15:00 - 15:30 0.50 CLEAN P DECOMP open Pump Out sub to reverse circulate. 15:30 - 18:00 2.50 CLEAN P DECOMP Mix and pump 30-Bbl Hi-Vis sweep and see some crude oil with the 9.8-ppg brine come across shaker. Redirect fluids to cuttings tank when the sweep comes over shaker. Find about 1-gallon of fine metal shavings on the magnets in the Possum Belly. Metal shavings indicate we should have a good surface for packer setting at +1- 9349', corrected for E-Line MD. 18:00 - 00:00 6.00 CLEAN P DECOMP POH laying down 15.5# DP in pipe shed 1 x1. POH standing back 13.3# DP in derrick. UD Weatherford UR BHA. Fluid losses = 3-4 bbls.hr. 80 jts. POH @ 2245-hrs. 6/29/2006 00:00 - 01 :00 1.00 CLEAN P DECOMP 35 Stands of 13.3# DP POH and standing in derrick. Fluid losses @ 3-4 bbls./hr. 01 :00 - 03:00 2.00 CLEAN P DECOMP POH wlWeatherford UR BHA. 03:00 - 04:00 1.00 CLEAN P DECOMP UD UR BHA. All cutter knives intact. Retrieved dart. Laid BHA down in one piece per Weatherford recommendation. Clear and clean rig floor. 04:00 - 04: 15 0.25 RUNCMP PJSM -- PUMU BOT lower retainer packer BHA. 04:15 - 10:00 5.75 RUNCMP PUMU BOT lower retainer packer BHA. RIH on 100-stands of 3-1/2" DP from Derrick. 10:00 - 14:30 RUNCMP Continue RIH Baker Packer on Drill Pipe from Pipe Shed. P/U joint #295 and get paramaters: P/U wt 90K, SIO wt 46K. Bury #295, drop 1-118" ball, M/U Head Pin and circulating line to #295, P/U 18.5 feet to park packer @ 9,349', tailpipe wI WLEG @ 9,359'. Both depths from Nabors 3S RKB of 23.70'. 14:30 - 15:30 RUNCMP Start pump and bring up to 1-1/2 BPM, 150-psi. See pressure increase to 550-psi after 1490-strokes (35-Bbls), and let pressure build to 2000-psi, SID pump. P/U on DP to 90K, then slowly pull to 18K over and setting tool shears and pressure immediately drops to O-psi. Packer is set. 15:30 - 20:00 4.50 RUNCMP POH and UD 95-joints of DP in Pipe Shed. POH stand back 2 stands 13.3# DP in derrick. 20:00 - 00:00 4.00 BOPSU RUNCMP Crew change - days to nights. PJSM/HACL. PUMU 7" Halco RTTS packer with storm valve. Set packer at -40' below rotary table. prr packer to 1000 psi from above. Prep to test BOPE. 6/30/2006 00:00 - 04:00 4.00 BOPSU P RUNCMP Perform weekly BOPE test per AOGCC/BP requirements - 250 psi 10/3500 psi hi. Tested 2·7/8" x 5-1/2" VB rams with both 2-7/8" and 3-1/2" test jts. per requirements. AOGCC - Lou Grimaldi waived withness test. 04:00 - 09:00 5.00 RUNCMP Cut and slip drilling line. 09:00 - 10:00 1.00 RUNCMP RIH and engage Storm Packer, release it, POH, break it out and lay it down. Check Hole Fill and have 4-Bblloss during the BOP test and Slip and Cutting Drill Line = -0.45-BPH. 10:00 - 16:00 RUNCMP POH and SIB Drill Pipe In Derrick. Fluid loss while POH 2-1/2 BPH. 16:00 - 17:00 1.00 RUNCMP Clear and Clean Rig Floor and change out tubulars handling equipment for M/U Bottom Packer Assembly. 17:00 - 19:00 2.00 RUNCMP P/U Snap Latch Seal Assy and M/U to two x 40' (+1-) sections of Baker Excluder Screen and RIH. P/U Pup Jt Assy and M/U to Screens. P/U Packer Assy and MIU to pup joints and RIH. Losses = -2-3 BPH. 19:00 - 19:30 0.50 RUNCMP Clear & clean rig floor. 19:30 - 21 :30 2.00 RUNCMP RIH wltop packerlscreen/snap latch BHA on 3-1/2" DP from derrick. 31 stds, RIH to casing patch. Ease packer assembly Printed: 7/10/2006 7:21:41 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: Rig Release: Rig Number: 6/21/2006 7/6/2006 N3S Spud Date: 6/12/2000 End: through patch. No resistance met with packer going through patch. Continue RIH. 21 :30 - 00:00 2.50 RUNCMP RIH wltop packerlscreenlsnap latch BHA on 3-1/2" DP from derrick, 7/1/2006 00:00 - 03:30 3.50 RUNCMP RIH wltop packerlscreenlsnap latch BHA on 3-1/2" DP 1x1 from pipe shed. 37 jts. RIH @ 0100-hrs. Tag top of lower packer 9320'. PU wt. = 95K# SO wt. = 40K#. Latch into top of lower packer seal bore. Pull snap latch out of seal assembly w/15K# overpull. Drop 1-7/16" setting ball. 03:30 - 04:00 RUNCMP LD one jt. PUMU 10' DP pup jt. MU headpin into jt. DP. PU 1 jt. DP. RIH and latch back into lower packer. Pull back out of seal assembly w/15K# overpull. Rig up kelly hose to top of headpin. Pump ball to setting tool seat @ 1.5 BPM, ball on seat. Latch back into lower packer. PU DP to SO wt. Pressure up against ball and seat to 1500 psi. Set packer. Bleed off pressure. Pull 40K# over PU wt. (130K#). Slack off to stack out DP. repeat 40K# over PU wt. and slack off to stack out DP two additional times to ensure packer top and bottom slips set. 04:00 - 05:00 RUNCMP PU DP to SO wt. - 40K#. Set DP in rotary slips and rig up rotary tongs to hold torque in DP. Turn DP 15 turns to right. Hold torque in DP with rotary tongs. Work pipe to transmit torque to packer setting tool. Release setting tool from packer. 05:00 - 06:00 1.00 RUNCMP Rig up floor to POH LODP. 06:00 - 17:00 11.00 RUNCMP POH and UD DP. #30 @ 0800-hrs. #200@ 1400-hours. #235 @ 1515-hours. #270 @ 1615-hours. #290 @ 1700-hours. 17:00 - 18:00 1.00 RUNCMP Break off and UD the Baker Packer Running Tool; Clear and clean Rig Floor. 18:00 - 00:00 6.00 RUNCMP Waiting on arrival of Centrilift ESP eqpt., Centrilift service technician and ESP cable spooler per MPU management decision. Filling hole every 2 hrs. w/4 bbls. and every 6 hrs. topping off hole wlbrine to reduce oil returns to pits. 7/2/2006 00:00 - 14:30 RUNCMP Waiting on arrival of Centrilift ESP eqpt., Centrilift service technician and ESP cable spooler. Filling hole every 2 hrs. w/4 bbls. and every 6 hrs. topping off hole wlbrine to reduce oil returns to pits. Fluid losses = -2 BPH. 200 bbls. in pits. @ 0400-hrs. Fluid loss from 0400-hrs to 1600-hrs = 28-Bbls or -2.3 BPH. 14:30 - 18:30 RUNCMP Position Spooler and RIU double sheave. Layout Herculite between Spooler and Rig. Establish electrical umbilical from Rig to Spooler. Wait on Centrilift ESP Assembly. 18:30 - 20:00 RUNCMP Centrilift ESP assembly on well pad @ 1830-hrs. Load eqpt. into pipe shed and assemble ESP service tools on rig floor. Load ESP cable spooler with ESP cable spool. 20:00 - 23:00 RUNCMP PJSM. PUMU ESP assembly. Prep to RIH. 23:00 - 00:00 RUNCMP RIH wlESP completion eqpt. 7/3/2006 00:00 - 16:00 RUNCMP RIH wlESP completion. 60 jts. RIH @ 0150-hrs., 130 jts. RIH @ 0400-hrs. Gain 1 bbl. fluid w/130 jts. RIH. 177 jts. RIH. Begin running heat trace cable at 0600-hrs. Stand #107 Ot #214) @ 1130-hrs. At 1400-hours viscous, black crude oil came to the surface while filling the tubing from the charge pump. Average fluid losses to the formation = -3 to 4 BPH. 16:00 - 20:00 4.00 RUNCO RUNCMP Make Reel-to-Reel ESP cable splice. Tour loss for Daylight Printed: 7/10/2006 7:21:41 AM · ' e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPG-15 MPG-15 WORKOVER NABORS ALASKA DRILLING I NABORS 3S Start: 6/21/2006 Rig Release: 7/6/2006 Rig Number: N3S Spud Date: 6/12/2000 End: Tour is 41-Bbls or 3.4-BPH. Resume RIH wlESP completion and tubing from derrick. Running heat trace cable. Start RIH wltubing 1x1 from pipe shed at 2330-hrs. Fluid losses -2 BPH. 7/4/2006 00:00 - 04:30 4.50 RUNCMP Continue RIH w/ESP completion picking up tubing from pipe shed 1 x1. Fluid losses -2 BPH. 04:30 - 11 :00 6.50 RUNCMP Rig up lines and pump 10 bbls. brine through ESP @ 1/2 BPM @ 650 psi. PUMU headpin and tubing hanger to landing joint; P/U wt 53K, SIO wt 27K. Space out ESP cable and heat trace cables to connect to hanger penetrators. Centrilift service tech check electrical continuity. Good test. Splicing ESP cable and heat trace cables to penetrators; good tests on both. Insert penetrators into Hanger and test--good tests. 11 :00 - 12:00 1.00 RUNCO RUNCMP Land Hanger and RILDS 12:00 - 16:30 4.50 RUNCO RUNCMP P/U and install TWC and test to 2500-psi. Good test. 30-minutes later, gas bubbles were coming to the surface of the fluid in the bottom of the BOP stack. Call for Lopso-Opso lubricator extension and lubricator to pull TWC. Replace with 2nd TWC and still have gas bubbling through the TWC. Decide to circulate well bore with 250-Bbls of clean 9.8-ppg brine. 16:30 - 21:00 4.50 RUNCO RUNCMP Wait on 9.8-ppg brine. 21 :00 - 00:00 3.00 RUNCO RUNCMP Circulate 95 Bbls of 9.8 ppg brine taking returns to the Tiger Tank. Obtain 52 Bbls of returns. Circulate 205 Bbls of 9.8 ppg brine taking returns to the pits. Returns are clean. Obtain 171 Bbls of returns. Shut in and monitor well. TII = 10/10 psi. 715/2006 00:00 - 11 :00 11.00 RUNCO RUNCMP Circulate 95 Bbls of 9.8 ppg brine taking returns to the Tiger Tank. Obtain 52 Bbls of returns. Circulate 205 Bbls of 9.8 ppg brine taking returns to the pits. Returns are clean. Obtain 171 Bbls of returns. Shut in and monitor well. T/I = 10/10 psi. Discuss with Engineering and decide to Bullhead -1-1/2 wellbore volumes of 9.9-ppg heavy. Annulus pressure @ 1100-hrs = 35-psi. 11 :00 - 15:00 WAIT RUNCMP Wait on 9.9-ppg heavy brine. 15:00 - 17:30 DPRB RUNCMP Annulus pressure 35-psi at start. Bullhead 50-Bbls 9.9-ppg heavy brine down tubing, @ .75-BPM and 1850-psi. Realign valves and bullhead 280-Bbls 9.9-ppg heavy brine down annulus @ 3-BPM and 680-psi. 17:30 - 20:15 2.75 RUNCMP Shut down and monitor well. SI Tubing at 50 psi and falling. SI Casing at 70 psi and falling. Tubing and Casing at 0 psi. 20:15 - 20:30 0.25 RUNCO RUNCMP Set BPV 20:30 - 00:00 3.50 BOPSU RUNCMP N/D BOPE 7/6/2006 00:00 - 02:30 2.50 BOPSU P RUNCMP N/D BOPE 02:30 - 05:00 2.50 WHSUR P RUNCMP N/U Tree 05:00 - 07:30 2.50 BOPSU P RUNCMP Pull BPV. Set TWC. Pressure test Tree to 5000 psi. 07:30 - 09:00 1.50 BOPSU P RUNCMP RIU lubricator and pull TWC; P/U BPV and install. Secure Tree and Cellar and prepare to RDMO to MPF-29. Release rig at 0900-hours, 6 July, 2006. Printed: 7/10/2006 7:21:41 AM ___ STATE OF ALASKA _. ALASK, .L AND GAS CONSERVATION COM REPORT OF SUNDRY WELL OPERATIONS' SION ii Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other FCC - Perf-Tubing Puncher 2. Name of Operator [5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 59' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service i4. Location of well at surface 8. Well Number 2074' NSL, 3455' WEL, SEC. 27, T13N, R10E, UM MPG-15 9. Permit Number/ Approval No. At top of productive interval 197-122 3582' NSL, 1083' WEL, SEC. 21, T13N, R10E, UM 10. APl Number At effective depth 50-029-22784 3756' NSL, 1161' WEL, SEC. 21, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 3815' NSL, 1187' WEL, SEC. 21, T13N, R10E, UM 12. Present well condition summary Total depth: measured 9845 feet Plugs (measured) true vertical 4508 feet Effective depth: measured 9739 feet Junk (measured) true vertical 4423 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface Intermediate Production 9792' 7" 1713 sx PF 'E', 155 sx Class 'G' 9822' 4490' Liner Perforation depth: measured 9430'- 9455', 9530'- 9550' !;~ ;-- ¢~' !i,~ i \/' ill ~'~ true vertical 4179' - 4199', 4258' - 4273' ~ : ;, , i' ") ...... Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 9117' ,." i* ~.~-.~.....:..~. 0it ::~ , Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Michael Wiliiams~------~'~_.~,~ ~ ~~ Title Technical Assistant Date : .: ~'~ ~" ~ ' : ":" : : PreparedByName/Number: De~ayne ,¢chnorr564-5174 Submit In Duplicate Form 10-404 Rev. 06/15/88 ,,,AL 02/01/2001 MPG-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FCO.: RUN TUBING PUNCH ON CT. SUMMARY ROAD CTU #3 FROM DEADHORSE TO MILNE POINT. STAND-BY FOR THIRD PARTY SERVICES. RIG UP THIRD PARTY EQUIPMENT. RIG UP CTU. SHUT DOWN FOR DAY...UNABLE TO GET PRESSURE TESTED DUE TO THIRD PARTY EQUIPMENT. CHANGE OUT THIRD PARTY EQUIPMENT. VECO CHANGED OUT VALVES ON PUMP IN SUB. RESUME OPERATIONS. PRESSURE TEST BOP AND LINES. PERFORM WEEKLY BOP FUNCTION TEST. RUN IN HOLE WITH NOZZLE AND CLEAN OUT DOWN TO TOP OF ESP. ATTEMPT TO START PUMP. NO LUCK. SPOT ACID. ATTEMEMPT TO START PUMP. NO LUCK. DISPLACE SPENT ACID TO TANK. START POOH AND PREP FOR TUBING PUNCH OPERATIONS. FINISH PULLING OUT OF HOLE WITH NOZZLE. FREEZE PROTECT FLOWLINE. PICK UP LUBRICATOR. INSTALL BAKER COIL TUBING CONNECTOR AND TOOL STRING. PICK-UP SCHLUMBERGER 1.56" TUBING PUNCH GUN. PUNCH TUBING 9035-9037 CTMD. (9 SHOTS TOTAL). POH. ALL SHOTS FIRED. RDMO Fluids Pumped BBLS. Description 19O 1% KCL 150 MEOH 11 12% DAD ACID 351 Total ADD PERFS 02/01/2001 SUMMARY The following interval was perforated using one SWS 1-11/16" tubing puncher gun, 4 SPF, 0° phasing (9 shots total). 9035- 9O37 MD STATE OF ALASKA - ALASKA ._ .,_ AND GAS CONSERVATION COMM. REPORT OF SUNDRY WELL OPERATIONS .,ION 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 59' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2074' NSL, 3455' WEL, SEC. 27, T13N, R10E, UM MPG-15 At top of productive interval 9. Permit Number / Approval No. 197-122 3582' NSL, 1083' WEL, SEC. 21, T13N, R10E, UM 10. APl Number At effective depth 50-029-22784 3756' NSL, 1161' WEL, SEC. 21, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 3815' NSL, 1187' WEL, SEC. 21, T13N, R10E, UM 12. Present well condition summary Total depth: measured 9845 feet Plugs (measured) true vertical 4508 feet Effective depth: measured 9739 feet Junk (measured) true vertical 4423 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arcticset I (Approx.) 112' 112' Surface Intermediate 9792' 7" 1713 sx PF 'E', 155 sx Class 'G' 9822' 4490' Production Liner Perforation depth: measured 9430' - 9455', 9530' - 9550' i~,.? !.'il ' true vertical 4179' - 4199', 4258' - 4273' ,.. Tubing (size, grade, and measured depth) 2-7/8", 9.6#, L-80, 8rd EUE to 9115' ,"~].~ska (')il & ,,: :: ,' Packers and SSSV (type and measured depth) N/A "'' ":' :" 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. - Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mci Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify t_hat the foregoing is true and correct to the best of my knowledge Sigr(ed ~j.e~_~l~~-7~:,,.~...~,__ Title Technical Assistant Date Prepared By Name/Numbec Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Duplicate Wellhead: 11"x12" Monobore 5M FMC Orig. GL Bev. = ,_.~.8' Gan 6 w/11" x 2-7/8" FMC Tubing ~i RT to Tbg Spool = 30.5' (N22E) Hanger, 2-7/8" 8rd. top & bottom, 2.5" ~' ClW BPV profile ' KOP ~ 300' to 500' ~ - .~ Max Hole Angle = 82 deg. ~ ' ~-~ ~)~ ~ I Hole angle through pars. = 38 deg. ~ ~ 2122' ~ ~ ES cementer was found to be leaking ~ -' dudng attempted ~mpletion (2-27-98) ~ ~ Howco internal casing patch installed ~ _~-S (5/17/98) and pressure tested to 3000 ~ r~'~ psig - DO not exceed this test psilll ~ ~-- Patch ID = 5.875" (drift = 5.75') ~ ' '~._:-~ ' KBMM Camco 2-7/8" x 1" ] GLM 2594' Note: Caution should be used when ~ running ESP BHA through casing patch ~ ~ at 2122' ~L Pump, 204 stg. FC650, 2-7/8" ~.5 ppf., k-80, 8rd. ~E tbs. .... ~ (dri~ ID = 2.347", Cap. = .0057~ bp~ ~a ~-~ ~ump, 8 st~. FC~PSH, I I Std. Bolt-On Intako ~ ,~: Model- FPINTAR 9090' ~ Modol- FIS3DBHk~FS Motor, 54 H~, ~ 020 volt, ~ ~ 02' Stimulation Summa~ 34 amp, Modol FMH N Sand: Did not peR. ~) I CA sand - 33.5M¢ 12-20 Prop-Lok resin PumpMate w/6 fin 9112' coated O~owa sand behind pipe.__ ' Centralizer OB sand - 66.2M¢ 12-20 Prop-Lok resin coated O~owa sand behind pipe. Two 7" marker jts. at 9127' to 9167' MD .... .... Perforation Summa~ ; ] ;; Ref. Loo 07/25/97 DGR -: :: ..... .... Size SPFi Inte~al (~D) .... "CA" Sand .... 4.5" 4 9430'-9455' (4180'-4197') - - :: .... .... 4.5" 4 9530'-9550' (4258'-4274') :: ;;, 7" landing collar (PBTD)l 9739,I 7" float collar I 9779' I 7" float shoe "Jet Charges e 0/180 deg. phasing" ..... ~ I I DATE REM BY COMMENTS MILNE POINT UNIT 3/18/01 GMH RWO Nabors 4ES WELL 6-1 5 APl NO. 50-029-22784 BP EXPLO TION - .. ~~- . , ~ ~ Mod ' -~ Mod :' Std. )0 .-7'i Mod :'-i Intal ~ Tan( ~ Mod Mot{ 34 a . Can Tw, -- -- - -- -- -Z ZZ .... .... .... __ 7') _ _ ~ ~ v) -- -- 7" 7~ ~ ~ 7" operati°ns SUmmary Report Legal Well Name: MPG-15 Common Well Name: MPG-15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 6/12/2000 End: 6/15/2000 Contractor Name: NABORS Rig Release: Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES ~!Date ~rom-To ~ours ~Task ~u,b !phase ~: Description of Operations 6/12/2000 23:59-10:00 10.02 MOB DECOMP istandby 10:00 - 11:00 1.00 MOB DECOMP Fill pits with seawater 11:00 - 13:30 2.50 MOB DECOMP Circulate 8.4 seatater 13:30 - 16:30 3.00 MOB DECOMP Shut in well 160 psi on tubing. Weight up to 9.5ppg 16:30 - 19:30 3.00 MOB DECOMP Circulate 9.5 ppg around 19:30 - 20:30 1.00 MOB DECOMP Set TWC and test from below 200 psi by bullheading annulus 20:30 - 0.00 MOB DECOMP ND tree NU BOP 6/13/2000 00:00- 02:00 2.00 PULL DECOMP nu bop 02:00 - 05:30 3.50 PULL DECOMP test BOP AOGCC John Spalding waived test 05:30 - 07:00 1.50 PULL DECOMP RU and pull TWC 07:00 - 07:30 0.50 PULL DECOMP Stab landing jt. and pull Tubing Hanger 07:30 - 08:30 1.00 PULL DECOMP Fill hole and observe wel for flow 08:30 - 14:30 6.00 PULL DECOMP Pull completion and Heat Trace 14:30 - 20:30 6.00 PULL DECOMP Continue pull 2 7/8" tubing and ESP 20:30 - 22:30 2.00 PULL DECOMP Service and LD ESP, clear floor 22:30 - 00:00 1.50 PULL DECOMP Change out ESP spool and sheave 6/14/2000 00:00 - 00:30 0.50 RUNCOI~I COMP Change out ESP spool and sheave 00:30 - 01:30 1.00 RUNCOI¥~ COMP PU/MU Kelly 01:30 - 05:00 3.50 RUNCOI~ DECOMP RU to run 2 7/8" completion. PU & Service ESP 05:00 - 09:30 4.50 RUNCOI~ COMP TIH w/ESP completion 09:30 - 11:00 1.50 RUNCOI~ COMP RU Centrilift Heat Trace Sheave and Spool 11:00 - 13:00 2.00 RUNCOI~I COMP TIH wi2 7/8" ESP completion and Heat Trace 13:00 - 15:30 2.50 RUNCOI~I COMP Set in new reel and splice ESP cable 15:30 - 00:00 8.50 RUNCOI~I COMP TIH wi2 7/8" ESP completion and Heat Trace 6/15/2000 00:00 - 03:00 3.00 RUNCOI~I COMP TIH wi2 7/8" ESP completion qnd Heat Trace 03:00 - 03:30 0.50 RUNCOI~I COMP PU Tubing Hanger, MU landing jr. 03:30 - 06:00 2.50 RUNCOI~I COMP Trouble shoot seals on Centrilift penetrator. Install penetrators, splice ESP and Heat Trace. 06:00 - 10:00 4.00 RUNCOI~ COMP Splice ESP and Heat Trace cables to Penetrators 10:00 - 11:30 1.50 RUNCOit COMP Land Tubing Hanger, install and test TWC ~11:30 - 14:30 3.00 BOPSUR COMP ND BOP, NU X-mas tree 14:30 - 15:30 1.00 WHSUR COMP Test Hanger and X-mas tree to 5000 psi 15:30 - 16:00 0.50 WHSUR COMP Pull TWC, Install BPV. Release rig at 22:00 hrs. Printed: 411212001 9:33:26 AM TIlE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03, 2001, M p i A T E E IA L U N U W T H IS M ARK E R C:LOKBMF]LM.DOC STATE OF ALASKA ALASK/ L AND GAS CONSERVATION COM! REPORT OF SUNDRY WELL OPERATIONS 310N 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) [] Development KBE -- 59' BP Exploration (Alaska) Inc. [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 8. Well Number 4. Location of well at surface MPG-15 2074' NSL, 3455' WEL, SEC. 27, T13N, R10E, UM 9. Permit Number / Approval No. At top of productive interval 197-122 3582' NSL, 1083' WEL, SEC. 21, T13N, R10E, UM INAL 10. APl Number At effective depth ORIG 50- 029-22784 3756' NSL, 1161' WEL, SEC. 21, T13N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Schrader Bluff 3815' NSL, 1187' WEL, SEC. 21, T13N, R10E, UM 12. Present well condition summary Total depth: measured 9845 feet Plugs (measured) true vertical 4508 feet Effective depth: measured 9739 feet Junk (measured) true vertical 4423 feet Casing Length Size Cemented MD TVD Structural 20" Conductor 80' 250 sx Arcticset I (Approx.) 112' 112' Surface 7" 9822' 4490' Intermediate 9792' 1713 sx PF 'E', 155 sx Class 'G' Production Liner Perforation depth: measured 9430'-9455', 9530' - 9550' !i._.'.i?!:.~ .~. ':i"i. . true vertical 4179' - 4199', 4258' - 4273' .~; '"' ~'"~ ..'!. i--'-, :.-'. Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80, 8rd EUE to 9117' ':-".i;.:;:~i:~;:-: ~..~: ,'~ ..:';~.: Packers and SSSV (type and measured depth) N/A 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble '~~.~ ~ Title Technical Assistant Date ' Prepared By Name/Number: Terrie Hubble, 564-4628 ...... Submit In Duplicate~ Form 10-404 Rev. 06/15/88 Legal Well Name: MP G-15 Common Well Name: MP G-15 Spud Date: 6/12/2000 Event Name: WORKOVER Start: 6/12/2000 End: 6/15/2000 Contractor Name: NABORS Rig Release: 6/15/2000 Group: RIG Rig Name: NABORS 4ES Rig Number: 4ES '- ~ate'-:-'.i 'Fr0m A~tiV~=c~e::Phasei-i.~:I : Description of Operations 6/12/2000 23:59- 10:00 10.02 MOB DECOMP standby 10:00 - 11:00 1.00 MOB DECOMP Fill pits with seawater 11:00 - 13:30 2.50 MOB DECOMP Circulate 8.4 seatater 13:30 - 16:30 3.00 MOB DECOMP Shut in well 160 psi on tubing. Weight up to 9.5ppg 16:30 - 19:30 3.00 MOB DECOMP Circulate 9.5 ppg around 19:30 - 20:30 1.00 MOB DECOMP Set TWC and test from below 200 psi by bullheading annulus 20:30 - MOB DECOMP ND tree NU BOP 6/13/2000 00:00-02:00 2.00 PULL DECOMP nubop 02:00 - 05:30 3.50 PULL DECOMP test BOP AOGCC John Spalding waived test 05:30 - 07:00 1.50 PULL DECOMP RU and pull TWC 07:00 - 07:30 0.50 PULL DECOMP Stab landing jt. and pull Tubing Hanger 07:30 - 08:30 1.00 PULL DECOMP Fill hole and observe wel for flow 08:30 - 14:30 6.00 PULL DECOMP Pull completion and Heat Trace 14:30 - 20:30 6.00 PULL DECOMP Continue pull 2 7/8" tubing and ESP 20:30 - 22:30 2.00 PULL DECOMP Service and LD ESP, clear floor 22:30 - 00:00 1.50 PULL DECOMP Change out ESP spool and sheave 6/14/2000 00:00 - 00:30 0.50 RUNCOI~I COMP Change out ESP spool and sheave 00:30 - 01:30 1.00 RUNCOI~I COMP PU/MU Kelly 01:30 - 05:00 3.50 RUNCOI~ DECOMP RU to run 2 7/8" completion. PU & Service ESP 05:00 - 09:30 4.50 RUNCOI~I COMP TIH w/ESP completion 09:30 - 11:00 1.50 RUNCOI~I COMP RU Centriliff Heat Trace Sheave and Spool 11:00 - 13:00 2.00 RUNCOI~I COMP TIH w/2 7/8" ESP completion and Heat Trace 13:00 - 15:30 2.50 RUNCOI~I COMP Set in new reel and splice ESP cable 15:30 - 00:00 8.50 RUNCOI~I COMP TIH w/2 7/8" ESP completion and Heat Trace 6/15/2000 00:00 - 03:00 3.00 RUNCOI~I COMP TIH w/2 7/8" ESP completion qnd Heat Trace 03:00 - 03:30 0.50 RUNCOI~I COMP PU Tubing Hanger, MU landing jr. 03:30 - 06:00 2.50 RUNCOI~I COMP Trouble shoot seals on Centrilift penetrator. Install penetrators, splice ESP and Heat Trace. 06:00 - 10:00 4.00 RUNCOI~ COMP Splice ESP and Heat Trace cables to Penetrators 10:00 - 11:30 1.50 RUNCOI~ COMP Land Tubing Hanger, install and test TWC 11:30 - 14:30 3.00 BOPSUF COMP ND BOP, NU X-mas tree 14:30 - 15:30 1.00 WHSUR COMP Test Hanger and X-mas tree to 5000 psi 15:30 - 16:00 0.50 WHSUR COMP Pull TWC, Install BPV. Release rig at 22:00 hrs. r, ,,.", ......... ' · i Printed: 7/20/2000 10:23:15AM Well Compliance Report File on Left side of folder i~2'i'2'~20 ~ .................................... M~E-P~~'"~ SB ....... ~i5 .......... 50~ 029-22784-00 MD 09845 ~ TVD 04508-- ~,Ommpletion Date: 5f~8/98 Completed Status: 1-OIL Current: T Name Interval Sent Received D 8i"i"5 .......... ~SPERRY MPTi~WR4 .......... OH 9/i7/97 9/17/97 L DGR/EWR4-MD IMSINAL 7398-9845 OH 9/17/97 9/17/97 L DGR/EWR4-TVD ~II~AL 3176-4508 OH 9/17/97 9/17/97 L GR/PERF ffrINAL 9404-9598. P'~- CH 5 5/30/'98 6/2/98 L GR/PERF L,F, tNAL 9235~9430 ~',~ ~/!~ ~ CH 5 5/30/98 6/2/98 R MWD SRVY .~S~"'--RRY 0-0845. OH 6/30/98 7/1/98 Daily Well Ops -7/a~- -t0/g¢ A D DitchSamplesRequired? yes ~____~ndReceive 9d2--0'e~n/r--- Was the ~vell cored? yes ~(~.~ Analysis Description Received?~.e.~.--~------~ample Comments: T/C/D Monday, May 01, 2000 Page 1 of 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CUMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2074' NSL, 3455' WEL, SEC. 27, T13N, R10E, UM At top of productive interval 3582' NSL, 1095' WEL, SEC. 21, T13N, R10E, UM At effective depth 3757' NSL, 1174' WEL, SEC 21, T13N, R10E, UM At total depth 3815' NSL, 1201' WEL, SEC. 21, T13N, R10E, UM 5, Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) RTE = 59' 7. Unit or Property Name Milne Point Unit 8. Well Number MPG-15 9. Permit Number / Approval No. 97-122 10. APl Number 50- 029-22784 11. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured 9845 feet true vertical 4508 feet Effective depth: measured 9739 feet true vertical 4423 feet Casing Length Structural Conductor Surface Intermediate Production Liner Size 80' 20" 9792' 7" Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx.) 1713 sx PF 'E', 155 sx Class 'G' Perforation depth: measured true vertical 9430' - 9455', 9530'- 9550' (Subsea)4120' - 4140', 4199' - 4215' Tubing (size, grade, and measured depth) 2 7/8" 6.5*, L-80 set at 9075' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure MD TVD 112' 112' 9822' 4461' 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run ,~,Daily Report of Well Operations 16. Status of well classifications as: [] Oil F-I Gas I--I Suspended Service 17. I hereby certify that the foregoing is true and. correct to the best of my knowledge Prepared By Name/Number: Jeanne Haas, 564-5225 Facility M Pt G Pad Progress Report Well MPG-15 Page 1 Rig Nabors 5S Date 08 September 98 Date/Time 10 Aug 98 11 Aug 98 12 Aug 98 13 Aug 98 14 Aug 98 06:00-09:30 09:30-10:00 10:00-11:00 11:00-15:00 15:00-15:30 15:30-16:00 16:00-18:00 18:00-20:30 20:30-21:00 21:00-21:30 21:30-23:30 23:30-06:00 06:00-10:00 10:00-12:00 12:00-15:00 15:00-18:00 18:00-22:00 22:00-04:30 04:30-06:00 06:00-10:30 10:30-11:00 11:00-13:00 13:00-15:30 15:30-16:00 16:00-18:00 18:00-20:00 20:00-01:00 01:00-03:30 03:30-06:00 06:00-08:30 08:30-14:30 14:30-16:30 16:30-21:00 21:00-04:00 04:00-06:00 06:00-07:30 07:30-08:00 08:00-08:30 08:30-10:00 10:00-10:30 10:30-11:00 11:00-12:30 12:30-14:00 14:00-06:00 Duration 3-1/2 hr 1/2 hr lhr 4hr 1/2 hr 1/2hr 2hr 2-1/2 hr 1/2 hr 1/2hr 2hr 6-1/2 hr 4hr 2hr 3hr 3hr 4hr 6-1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 2hr 2-1/2 hr 1/2 hr 2hr 2hr 5hr 2-1/2 hr 2-1/2 hr 2-1/2 hr 6hr 2hr 4-1/2 hr 7hr 2hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1-1/2 hr 16hr Activity Rigged up Draw works Removed Hanger plug Circulated at 0.0 ft Circulated at 9005.0 ft Installed Hanger plug Rigged down Xmas tree Installed BOP stack Tested All rams Retrieved Hanger plug Removed Tubing hanger Pulled Tubing in stands to 0.0 ft Pulled Tubing in stands to 2520.0 ft Pulled Tubing in stands to 9092.0 ft Laid down 0.0 ft of Tubing Functioned downhole tools at 1000.0 ft Ran Tubing in stands to 6000.0 ft Ran Tubing in stands to 9100.0 ft Ran Tubing to 9715.0 ft (2-7/8in OD) Laid down 960.0 ft of Tubing Pulled Tubing in stands to 0.0 ft Rigged up Completion string handling equipment Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 2122.0 ft Ran Tubing in stands to 2122.0 ft Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - Electrical submersible pumps Rigged up sub-surface equipment - ESP Ran Tubing in stands to 1600.0 ft Pulled Tubing in stands to 100.0 ft Pulled Tubing in stands to 0.0 ft Ran Tubing in stands to 6465.0 ft Ran Tubing to 6522.0 ft (2-7/8in OD) Ran Tubing in stands to 6522.0 ft Ran Tubing in stands to 9075.0 ft Rigged up Tubing hanger Installed Tubing hanger Rigged up Tubing hanger Rigged up Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Removed Hanger plug Freeze protect well - 2.000 bbl of Diesel Rig moved 50.00 % STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Pull Tubing [] Operation Shutdown [] Stimulate [] Plugging 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Perforate 4. Location of well at surface 2074' NSL, 3455' WEL, SEC. 27, T13N, R10E, UM At top of productive interval 3582' NSL, 1095' WEL, SEC. 21, T13N, R10E, UM At effective depth 3757' NSL, 1174' WEL, SEC 21, T13N, R10E, UM At total depth 3815' NSL, 1201' WEL, SEC. 21, T13N, R10E, UM []Alter Casing [] Repair Well []Other 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service ESP Changeout 6. Datum Elevation (DF or KB) RTE = 59' 7. Unit or Property Name Milne Point Unit 8. Well Number MPG-15 9. Permit Number / Approval No. 97-122 10. APl Number 50- 029-22784 1. Field and Pool Milne Point Unit / Schrader Bluff 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Structural Conductor 80' Sudace Intermediate 9792' Production Liner 9845 feet 4508 feet 9739 feet 4423 feet Size 20" 1, Plugs (measured) Junk (measured) Cemented 250 sx Arcticset 1 (Approx.) 1713 sx PF 'E', 155 sx Class 'G' MD TVD 112' 112' 9822' 4461' Perforation depth: measured true vertical 9430' - 9455', 9530' - 9550' (Subsea)4120'- 4140', 4199' - 4215' Tubing (size, grade, and measured depth) 2 7/8" 6.5*, L-80 set at 9100' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure ORIGINAL 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments []Copies of Logs and Surveys run ,,J~aily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 7. I hereby certify that the foregoing is true amd correct to the best of my knowledge J ~ Title Staff TechnicalAssistant Prepared By Name/Number: Jeanne H~as, 5~4-5225 Facility M Pt G Pad Progress Report I I I I I I I I I I I I I ~ I I I I I I I Well MPG-15 Page 1 Rig (null) Date 08 September 98 Date/rime 25 Aug 98 26 Aug 98 27 Aug 98 28 Aug 98 29 Aug 98 07:30-21:30 21:30-02:30 02:30-04:30 04:30-06:00 06:00-06:30 06:30-09:30 09:30-11:30 11:30-12:00 12:00-13:30 13:30-14:30 14:30-15:00 15:00-16:00 16:00-18:00 18:00-19:00 19:00-06:00 06:00-06:30 06:30-10:30 10:30-15:-30 15:30-21:30 21:30-22:00 22:00-22:30 22:30-01:00 01:00-02:00 02:00-04:30 04:30-05:30 05:30-06:00 06:00-10:30 10:30-12:00 12:00-12:30 12:30-15:30 15:30-22:30 22:30-22:45 22:45-06:00 06:00-06:30 06:30-08:00 08:00-10:30 10:30-15:00 15:00-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-20:30 20:30-21:30 21:30-23:00 Duration 14hr 5hr 2hr 1-1/2 hr 1/2 hr 3hr 2hr 1/2 hr 1-1/2 hr lhr 1/2 hr lhr 2hr lhr llhr 1/2 hr 4hr 5hr 6hr 1/2 hr 1/2hr 2-1/2 hr lhr 2-1/2 hr lhr 1/2 hr 4-1/2 hr 1-1/2 hr 1/2 hr 3hr 7hr 1/4 hr 7-1/4 hr 1/2hr 1-1/2 hr 2-1/2 hr 4-1/2 hr 1-1/2 hr 1-1/2 hr 1/2 hr 1/2hr 1-1/2 hr lhr 1-1/2 hr Activity Rig moved 100.00 % Circulated at 2640.0 ft Removed Xmas tree Worked on BOP - BOP stack Held safety meeting Worked on BOP - BOP stack Circulated at 2640.0 ft Held safety meeting Removed Tubing hanger Pulled Tubing in stands to 9000.0 ft Held safety meeting Circulated at 9000.0 ft Pulled Tubing in stands to 7776.0 ft Held safety meeting Pulled Tubing in stands to 250.0 ft Held safety meeting Retrieved ESP Conducted slickline operations on Slickline equipment - Tool run Installed ESP Repaired Additional services Tested ESP - Via string Ran Tubing in stands to 6486.0 ft Functioned downhole tools at 6486.0 ft Retrieved ESP Repaired Tubing handling equipment Retrieved ESP Retrieved ESP Tested ESP - Via string Held safety meeting Installed ESP Ran Tubing in stands to 6849.0 ft Held safety meeting Ran Tubing in stands to 7700.0 ft Held safety meeting Ran Tubing in stands to 8000.0 ft Functioned Electric cable Ran Tubing in stands to 9100.0 ft_~/~~ Installed Hanger assembly Functioned Electric cable Held safety meeting Functioned Electric cable Installed Tubing hanger Removed BOP stack Installed Xmas tree STATE OF ALASKA :": "~ ~,:,','ir, ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ....... 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 97-122 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22784 4. Location of well at surface i ':..;~!--i ?~-i..;"; ! ~-.,¢.~:~ 9. Unit or Lease Name 2074' NSL, 3455' WEL, SE C. 27, T13N, R10E, UM ': ~i'.~. ~ i'~ M line Poi nt Unit .. At top of productive interval -- i 10. Well Number 3582' NSL, 1095' WEL, SEC. 21 T13N, R10E, UM .! "~";;~':~"::':I:~ MPG-15 At total depth ' ~: ' ~ ..... .~,-~,- ........... '; ,- :. . _ ~ 11. Field and Pool 3815' NSL, 1201' WEL, SEC. 21 T13N R10E, UM ' ' Milne Point Unit / Schrader Bluff 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 59'I ADL 315848 12. Date Spudded7/20/97 I 13' Date I'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if OffshOre 116' NO' Of'c°mpletiOns7/25/97 5/28/98 N/A MSLI One 17. Total Depth (MD+TVD)9845 4508 FT,I18' Plug Back Depth (MD+TVD)I19' Directi°nal SurveY 120' Depth where SSSV set 121' Thickness °f Permafr°st9739 4423 FT} [] Yes [] No N/A MD . 1800' (Approx.) 22. Type Electric or Other Logs Run ; ~., i ~', i. ~, , MWD, LWD, GR/CCL 23. CASING~ LINER AND CEMENTING RECORD CASING SE~rlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 7" 26# L-80 30' 9822' 8-1/2" 1713 sx PF 'E', 155 sx Class 'G' ....... ...... 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) 4-1/2" Gun Diameter, 4 spf 2-7/8", 6.5#, L-80 9092' MD TVD MD TVD 9430'-9455' 4179'-4199' 9530'-9550' 4258'-4273' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect with 80 bbls diesel Proplok frac, 9530'-9550' 66200# 12/20 Natural Sand behind pipe Proplok frac, 9430'-9455' 33500# 12/20 Natural Sand behind pipe 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 5, 1998 I Electric Submersible Pump ......... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAWTY-API (CORR) Press. 24-HOUR RATE ...... 28. CORE DATA ,,, Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. TSBD 9426' 4176' TSBC 9480' 4218' TSBB 9526' 4254' 31. List of Attachments Summary of Daily Drilling Reports, Surveys certF,/~..g:~,~e foregoing,,i~rue/an_~co... . / . ~ 7 . 32. I hereby rrect to~ best of my knowledge Signed.~ 'itle Drilling Engineering Supervisor Date / ~PG-15 ' ' ~" - ~ -97-122 Prepared By Name/Number: Kathy Campoamor, 564-5122 Well Number Permit No. / Approval No. iNSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on ail 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 Facility M Pt G Pad Progress Report Well MPG-15 Rig Nabors Page Date 1 17 June 98 Date/Time 20 Jul 97 21 Jul 97 22 Jul 97 23 Jul 97 24 Jul 97 25 Jul 97 03:00-06:00 06:00-07:00 07:00-07:30 07:30-08:30 08:30-10:00 10:00-10:30 10:30-11:00 11:00-01:00 01:00-02:00 02:00-03:30 03:30-04:30 04:30-05:15 05:15-06:00 06:00-11:30 11:30-12:30 12:30-15:30 15:30-18:00 18:00-19:00 19:00-01:00 01:00-02:30 02:30-03:30 03:30-04:30 04:30-06:00 06:00-10:00 10:00-11:00 11:00-13:00 13:00-13:30 13:30-14:00 14:00-15:30 15:30-22:00 22:00-22:30 22:30-01:00 01:00-02:00 02:00-06:00 06:00-09:00 09:00-10:00 10:00-17:30 17:30-19:00 19:00-20:30 20:30-21:30 21:30-22:30 22:30-00:00 00:00-02:30 02:30-03:30 03:30-06:00 06:00-11:00 11:00-12:00 12:00-14:00 14:00-14:30 14:30-15:30 15:30-06:00 06:00-06:30 06:30-08:00 08:00-14:00 Duration 3hr lhr 1/2 hr lhr 1-1/2 hr 1/2 hr 1/2 hr 14hr lhr 1-1/2 hr lhr 3/4 hr 3/4 hr 5-1/2 hr lhr 3hr 2-1/2 hr lhr 6hr 1-1/2 hr lhr lhr 1-1/2 hr 4hr lhr 2hr 1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 1/2 hr 2-1/2 hr lhr 4hr 3hr lhr 7-1/2 hr 1-1/2 hr 1-1/2 hr lhr lhr 1-1/2 hr 2-1/2 hr lhr 2-1/2 hr 5hr lhr 2hr 1/2 hr lhr 14-1/2 hr 1/2 hr 1-1/2 hr 6hr Activity Installed Divertor Installed Bell nipple Made up BHA no. 1 Serviced Top drive Made up BHA no. 1 Tested Divertor Circulated at 112.0 ft Drilled to 2075.0 ft Circulated at 2075.0 ft Drilled to 2300.0 ft Circulated at 2300.0 ft Pulled out of hole to 700.0 ft R.I.H. to 2300.0 ft Drilled to 3317.0 ft Circulated at 3317.0 ft Pulled out of hole to 1930.0 ft R.I.H. to 3317.0 ft Serviced Rotary table Drilled to 4346.0 ft Circulated at 4346.0 ft Pulled out of hole to 3317.0 ft R.I.H. to 4346.0 ft Drilled to 4538.0 ft Drilled to 5397.0 ft Circulated at 5397.0 ft Pulled out of hole to 3975.0 ft Serviced Top drive R.I.H. to 4824.0 ft Reamed to 5397.0 ft Drilled to 6442.0 ft Circulated at 6442.0 ft Pulled out of hole to 4824.0 ft R.I.H. to 6442.0 ft Drilled to 6925.0 ft Drilled to 7401.0 ft Circulated at 7401.0 ft Pulled out of hole to 731.0 ft Pulled BHA Made up BHA no. 2 Serviced Top drive Serviced Block line Singled in drill pipe to 2132.0 ft R.I.H. to 6495.0 ft Reamed to 7401.0 ft Drilled to 7731.0 ft Drilled to 8306.0 ft (cont...) Circulated at 8306.0 ft Pulled out of hole to 6870.0 ft R.I.H. to 7535.0 ft Reamed to 8306.0 ft Drilled to 9828.0 ft Drilled to 9845.0 ft (cont...) Circulated at 9845.0 ft Pulled out of hole to 90.0 ft Progress Report Facility M Pt G Pad Well MPG- 15 Rig Nabors ~ ;2fi,.& Page 2 Date 17 June 98 Date/Time 26 Jul 97 27 Jul 97 28 Jul 97 14:00-15:00 15:00-16:00 16:00-21:30 21:30-01:00 01:00-05:00 05:00-06:00 06:00-08:00 08:00-09:30 09:30-09:45 09:45-16:00 16:00-18:30 18:30-20:30 20:30-06:00 06:00-11:30 11:30-11:45 11:45-15:30 15:30-16:30 16:30-17:45 17:45-18:00 18:00-20:00 20:00-21:15 21:15-22:00 22:00-23:15 23:15-00:00 00:00-01:30 01:30-02:30 02:30-03:30 03:30-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-09:15 09:15-09:30 09:30-11:00 Duration lhr lhr 5-1/2 hr 3-1/2 hr 4hr lhr 2hr 1-1/2 hr 1/4 hr 6-1/4 hr 2-1/2 hr 2hr 9-1/2 hr 5-1/2 hr 1/4 hr 3-3/4 hr lhr 1-1/4 hr 1/4 hr 2hr 1-1/4 hr 3/4 hr 1-1/4 hr 3/4 hr 1-1/2 hr lhr lhr 1-1/2 hr lhr 1/2 hr 1-1/2 hr 1-1/4 hr 1/4 hr 1-1/2 hr Activity Downloaded MWD tool Serviced Top drive R.I.H. to 9845.0 ft Circulated at 9845.0 ft Pulled out of hole to 737.0 ft Pulled BHA Pulled BHA (cont...) Rigged up Casing handling equipment Held safety meeting Ran Casing to 5266.0 ft (7in OD) Washed to 6200.0 ft Circulated at 6200.0 ft Ran Casing to 7in (8100.0 ft OD) Ran Casing to 9822.0 ft (7in OD) (cont...) Rigged up Cement head Circulated at 9822.0 ft Mixed and pumped slurry - 269.000 bbl Displaced slurry - 372.000 bbl Functioned DV collar Circulated at 2122.0 ft Mixed and pumped slurry - 450.000 bbl Displaced slurry - 81.000 bbl Cleared Header box Rigged down Casing handling equipment Removed Divertor Installed Casing head Installed Adapter spool Tested Adapter spool Removed Adapter spool Removed Adapter spool (cont...) Installed Adapter spool Installed Xmas tree integral components Installed Hanger plug Laid out 5in drill pipe from derrick Facility M Pt G Pad Progress Report Well MPG-15 Page 1 Rig Nabors 4ES Date 17 June 98 Date/Time 23 Feb 98 24 Feb 98 25 Feb 98 26 Feb 98 08:00-14:00 14:00-17:30 17:30-20:30 20:30-23:00 23:00-00:00 00:00-03:00 03:00-04:00 04:00-05:00 05:00-06:00 06:00-07:00 07:00-09:00 09:00-09:30 09:30-10:00 10:00-13:00 13:00-14:00 14:00-15:30 15:30-19:00 19:00-02:00 02:00-04:00 04:00-04:30 04:30-06:00 11:00-13:00 13:00-15:00 15:00-19:30 19:30-03:00 03:00-06:00 06:00-09:00 09:00-10:00 10:00-11:00 11:00-11:30 11:30-14:00 Duration 6hr 3-1/2 hr 3hr 2-1/2 hr lhr 3hr lhr lhr liar lhr 2hr 1/2 hr 1/2 hr 3hr lhr 1-1/2 hr 3-1/2 hr 7hr 2hr 1/2 hr 1-1/2 hr 2hr 2hr 4-1/2 hr 7-1/2 hr 3hr 3hr lhr lhr 1/2 hr 2-1/2 hr Activity Rig moved 100.00 % Retrieved Xmas tree on Tubing Rigged up BOP stack Tested BOP stack Made up BHA no. 1 R.I.H. to 2110.0 ft Drilled installed equipment - DV collar R.I.H. to 2314.0 ft Circulated at 2314.0 ft Serviced Block line Singled in drill pipe to 5506.0 ft Circulated at 5506.0 ft Singled in drill pipe to 5906.0 ft Drilled cement to 6243.0 ft Singled in drill pipe to 6864.0 ft Drilled cement to 6957.0 ft Singled in drill pipe to 9704.0 ft Reverse circulated at 9704.0 ft Circulated at 9704.0 ft Tested Other sub-surface equipment - Via annulus and string Pulled out of hole to 6500.0 ft R.I.H. to 2050.0 ft Pulled out of hole to 0.0 ft R.I.H. to 9500.0 ft Laid down 9500.0 ft of 3-1/2in OD drill pipe Ran Tubing to 500.0 ft (2-7/8in OD) Ran Tubing to 2625.0 ft (2-7/8in OD) Removed BOP stack Installed Xmas tree Tested Xmas tree Freeze protect well - 85.000 bbl of Diesel Facility Date/Time 15 May 98 16 May 98 17 May 98 18 May 98 19 May 98 20 May 98 21 May 98 22 May 98 Progress Report M Pt G Pad Well MPG-15 Page 1 Rig Nabors 4ES Date 17 June 98 10:00-22:00 22:00-23:30 23:30-02:00 02:00-04:30 04:30-06:00 06:00-06:30 06:30-08:30 08:30-10:30 10:30-21:30 21:30-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-06:30 06:30-09:30 09:30-11:00 11:00-18:30 18:30-19:30 19:30-21:00 21:00-06:00 06:00-08:00 08:00-09:00 09:00-10:30 10:30-12:30 12:30-13:30 13:30-20:00 20:00-22:30 22:30-23:30 23:30-04:30 04:30-06:00 06:00-06:30 06:30-20:00 20:00-22:00 22:00-23:00 23:00-00:00 00:00-01:30 01:30-06:00 06:00-10:30 10:30-11:30 11:30-22:00 22:00-23:00 23:00-06:00 06:00-09:30 09:30-10:00 10:00-14:30 14:30-15:30 15:30-18:30 18:30-19:30 19:30-03:00 03:00-06:00 06:00-09:00 09:00-14:00 14:00-14:30 14:30-15:30 Duration 12hr 1-1/2 hr 2-1/2 hr 2-1/2 hr 1-1/2 hr 1/2 hr 2hr 2hr llhr 4-1/2 hr lhr lhr 2hr 1/2 hr 3hr 1-1/2 hr 7-1/2 hr lhr 1-1/2 hr 9hr 2hr lhr 1-1/2 hr 2hr lhr 6-1/2 hr 2-1/2 hr lhr 5hr 1-1/2 hr 1/2 hr 13-1/2 hr 2hr lhr lhr 1-1/2 hr 4-1/2 hr 4-1/2 hr lhr 10-1/2 hr lhr 7hr 3-1/2 hr 1/2 hr 4-1/2 hr lhr 3hr lhr 7-1/2 hr 3hr 3hr 5hr 1/2 hr lhr Activity Rig moved 100.00 % Circulated at 2100.0 ft Installed BOP stack Tested BOP stack Laid down 350.0 ft of Tubing Held safety meeting Pulled Tubing in stands to 0.0 ft Made up BHA no. 1 Singled in drill pipe to 9704.0 ft Reverse circulated at 9704.0 ft Laid down 2800.0 ft of 3-1/2in OD drill pipe Serviced Block line Pulled out of hole to 2500.0 ft Held safety meeting Ran Drillpipe in stands to 2130.0 ft Pulled out of hole to 0.0 ft Installed Internal casing patch~ se.{ ~ z/co:£~/~ Pulled Drillpipe in stands to 0.0 ft R.I.H. to 2189.0 ft Circulated at 2189.0 ft Circulated at 2189.0 ft Tested Internal casing patch - Via annulus and string ~o ~oo0 fc_L Pulled out of hole to 0.0 ft Ran Drillpipe in stands to 2150.0 ft Worked on BOP - Lubricator Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Perforated from 9530.0 ft to 9550.0 ft Rigged down sub-surface equipment - Perforating tools Rigged down sub-surface equipment - Perforating tools Ran Tubing to 9001.0 ft (3-1/2in OD) Rigged up High pressure lines Tested Testing equipment Tested Production equipment Monitor wellbore pressures Circulated at 9001.0 ft Bullhead well FRAC job - 300.000 bbl injected at 4800.0 psi Reverse circulated at 5393.0 ft Reverse circulated at 5393.0 ft Ran Tubing to 9409.0 ft (3-1/2in OD) Reverse circulated at 9470.0 ft Injectivity test- 3.000 bbl injected at 1100.0 psi Pulled Tubing in stands to 0.0 ft Worked on BOP - Lubricator Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Ran Drillpipe in stands to 6000.0 ft Ran Drillpipe in stands to 9458.0 ft Reverse circulated at 9458.0 ft Pulled out of hole to 8896.0 ft Serviced Block line Facility M Pt G Pad Progress Report Well MPG-15 Page 2 Rig Nabors 4ES Date 17 June 98 Date/Time 23 May 98 24 May 98 25 May 98 26 May 98 27 May 98 28 May 98 15:30-19:00 19:00-20:00 20:00-22:00 22:00-04:30 04:30-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-11:30 11:30-12:00 12:00-13:00 13:00-15:00 15:00-16:00 16:00-21:00 21:00-06:00 06:00-06:30 06:30-19:00 19:00-22:30 22:30-06:00 06:00-06:30 06:30-14:00 14:00-19:00 19:00-01:00 01:00-06:00 06:00-06:30 06:30-08:00 08:00-08:15 08:15-08:30 08:30-09:15 09:15-09:30 09:30-12:00 12:00-15:30 15:30-19:00 19:00-20:00 20:00-21:00 21:00-23:00 23:00-06:00 06:00-06:15 06:15-06:30 06:30-08:00 08:00-09:45 09:45-10:00 10:00-18:00 18:00-18:15 18:15-20:00 20:00-21:30 21:30-22:15 22:15-22:30 22:30-23:30 23:30-00:30 00:30-01:00 01:00-02:00 02:00-03:00 03:00-04:00 Duration 3-1/2 hr lhr 2hr 6-1/2 hr lhr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr lhr 2hr lhr 5hr 9hr 1/2 hr 12-1/2 hr 3-1/2 hr 7-1/2 hr 1/2 hr 7-1/2 hr 5hr 6hr 5hr 1/2hr 1-1/2 hr 1/4 hr 1/4 hr 3/4 hr 1/4 hr 2-1/2 hr 3-1/2 hr 3-1/2 hr lhr lhr 2hr 7hr 1/4 hr 1/4 hr 1-1/2 hr 1-3/4 hr 1/4 hr 8hr 1/4 hr 1-3/4 hr 1-1/2 hr 3/4 hr 1/4 hr lhr lhr 1/2 hr lhr lhr lhr Activity Pulled Drillpipe in stands to 0.0 ft Worked on BOP - Lubricator Held safety meeting Perforated from 9430.0 ft to 9455.0 ft Worked on BOP - Bell nipple Ran Tubing in stands to 500.0 ft Held safety meeting Ran Tubing in stands to 8873.0 ft Rigged up High pressure lines Tested Testing equipment Injectivity test - 191.000 bbl injected at 6155.0 psi FRAC job - 291.000 bbl injected at 6736.0 psi FRAC job - 328.000 bbl injected at 5300.0 psi Monitor wellbore pressures Pulled Tubing in stands to 5000.0 ft Held safety meeting Laid down 9080.0 ft of Tubing Pulled Drillpipe in stands to 9214.0 ft Singled in drill pipe to 9464.0 ft Held safety meeting Singled in drill pipe to 9704.0 ft Reverse circulated at 9704.0 ft Circulated at 9704.0 ft Laid down 3500.0 ft of 3-1/2in OD drill pipe Serviced Drillfloor / Derrick Laid down 6175.0 ft of 3-1/2in OD drill pipe Removed Wear bushing Installed BOP test plug assembly Tested Bottom ram Removed BOP test plug assembly Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing in stands to 2110.0 ft Pulled Tubing in stands to 2110.0 ft Ran Tubing in stands to 2250.0 ft Pulled Tubing in stands to 2250.0 ft Rigged up sub-surface equipment - Electrical submersible pumps Ran Tubing to 4700.0 ft (2-7/8in OD) Held safety meeting Serviced Drillfloor / Derrick Ran Tubing to 6800.0 ft (2-7/8in OD) Rigged up sub-surface equipment - Other sub-surface equipment Held safety meeting Ran Tubing in stands to 9050.0 ft Held safety meeting Installed Tubing hanger Installed Electric cable Ran Tubing on landing string to 9092.0 ft Installed Hanger plug Removed BOP stack Installed Xmas tree Tested Xmas tree Installed Hanger plug Freeze protect well - 80.000 bbl of Diesel Removed High pressure lines Milne Point Unit, Alaska TO: Hendrix FROM: H. Thackeray Well Name: MPG-15 Main Category: DRLG COMP Sub Category: ELINE PERF Operation Date: 5/18,19/98 Date: 15-19-98 Objective: Eline convey perforate the Schrader Bluff "OB" sands. Sequence of Events: 5/18/98 1400 1600 1615 1745 1900 2230 23OO 2345 MI RU Atlas E-line unit. MU perf gun and toolstring on rollers. PJSM. PT Lubricator. Start in hole Slowed and stopped at 3500'. Having to work tools down thru 79-80 degree hole Really struggling at 6470' Unable to get over 81 degree hump at .-.6500'. POOH for tractor Start back in hole with gun and tool string with tractor Tools not reading at 1800'. POOH Check tools. Found shorted out from o-ring failure Start back in hole with tractor tools 5/19/98 0000 O345 0355 O4OO Quit rolling at 3170' Tractor form 3170-8500' at ,--25 fpm Correlate depth to Sperry Sun MWD log 7/25/97 Perforate "OB" sand from 9530-9550' with 4 ~" gun with 4 'Big Hole' spf at 0-180 degree phasing POOH RD Atlas Eline Results: Perforated "OB" sand from 9530-9550' (20') with 4 spf Big Hole charges at 0-180 degree phasing utilizing Atlas tractor tool to get down 81 degree hole angle. NOTE: Slickline crew came out and installed Petredat tool in 3 1,~,, GLM for frac job. Tie in log/date: Sperry Sun MWD log 7/25/97 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation 9530 9550 4 ~ 4 Phasing 0-180 BP EXPLORATION (ALASKA)INC. Milne Point Unit TO: J. Spearman/J. Hendrix FROM: J. Fox DATE: 05 / 19 - 20 / 98 RE: MPU G-15 'OB' SAND DATA FRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY Approximately 66.2 M # of 12-20 PropLok resin coated natural sand was placed behind pipe. Design (50 M#) plus 50% excess was pumped and displaced with 46 bbl. (of 86 total displacement vol.) before the wellbore screened out. 175 bbl. of 8 ppg (final prop. stage concentration) made it into the perfs. Achieved approx. 240 psi of net pressure build before screen out. There was a sharp pressure build of 200 psi just as 8 ppg slurry reached the perfs that stabilized before starting a more gradual and constant pressure build until sudden screen out. The first 6 M# of proppant was coated with Halliburton PropLok resin at a concentration of 3/16 gal/100# and then increased to 3/8 gal. / 100# ( at the start of the 5 ppg stage) for the remainder of the proppant. Because of recent problems getting adequate resin coverage the following changes were made from past practices: · Decreased gel pH to 5.5 to 6.5 · Doubled concentration of resin plasticizer concentration. · No color dyes were used. · heated gel to approx. 95 deg. · 12/20 natural sand was used for the first time. The 12 - 20 sand was initially proposed based on better coating by the resin. It also has the added benefits of better retention in the formation due to more angularity of the sand grains as well as potential cost savings (relative to Carbolite). During the 100 bbl. injectivity test max. rate was not achievable due to limitations with maximum pressure that the surface equipment had been pressure tested to. Based on past experience it was not anticipated that the pressures would be so high however the Hydril tubing used for the frac string had a 2.75" ID rather 2.992" used in the past. This restriction compounded by cold fluids (high viscosity) caused considerably higher friction pressures. For the data frac the surface treating lines were re-pressure tested to 8150 psig and the trips were set for 7500 psig. which ended up being more than adequate. There were still problems getting adequate suction pressure at the pumps due to fluid viscosity and possibly the 6" (rather than 8") Halliburton flowmeter. Note: · It was intended to run a Petredat gauge in a GLM at the end of the tubing however the GLM O.D. was too large to fit through the casing patch. The casing patch was only tested to 2000 psig so that was the determining factor on maximum inner annular pressure during the treating process and the annular pop off setting of 1800 psig.. O6/25/98 2:24 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIMEI RATEBPM ANNP WHP ISTAGEI CUM I PSIG PSIG BBL BBL PUMPING SUMMARY COMMENTS The temperature of gel as it was received on location was 40 to 50 deg. This was considerably below the design temperature and had to be heated with a hot oil unit prior to the frac. During the data frac it created problems getting design rates and constant rates due to difficulty in getting adequate suction pressure at the pumps. This was compounded by the use of the Hallibudon 6" flow meter instead of the 8" flow meter. All gel used was 60 ppt HEC. HEC being utilized due to incompatibility of guar gel with Propbok. The pH was 5.5 to 6.0 prior to adding the PropLok and 7 after it was added. Fluid temperature downstream of the blender was 85 deg. Gel was circulated to the end of the tubing on both the injectivity and dat frac to save on brine and reduce the amount of fluid lost to the formation. INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP, psi ISIP, NWB friction, Treat grad, BPM Pumped bpm PSI psi psi/ft max. 100 19.5 977 877 100 0.66 DATA FRAC Bbls Bbls HEC gel Time gel on Final STP, psi ISIP, psi NWB friction, Treat grad, Pumped to Perfs perfs psi psi/ft 200 200 12.5 min. 970 900 70 0.66 FRAC Sand Lead prop Tail prop Design total Tresaver pumped, behind pipe, behind behind pipe, Liner Sand, rubber left in Job was Ma Ma pipe, Ma Ma Ma hole? /size /size Screened out 76.0 Ma 66.2 Ma not 50 Ma 9860 # not on flush 12/20 applicable applicable Ft of sand Estimated Final IA ISIP, psi ISIP Incr Actual TSO, design, TSO, . in Pipe sand top STP, over datafrac sand:pad min Nolte psi ratio Plot 1700 not not 19.4 not appl. applicable applicable DATE/TIME OPERATIONS SUMMARY 05/19/98 2115 Pre-job safety meeting ~2210 Pressure test surface treating lines to 5700 psi. Set trips to 4400 psi. 2218 Start circulating 100 bbl. 60# HEC get to the end of tubing. 2243 Bring rate up to max. for injectivity test. 2250 S/D pumps and monitor pressure falloff. ISIP = 877 psig. 2322 Start circulating 200 bbl. gel to the end of the tubing. 2344.5 Attempt to bring rate up to 20 BPM for data frac. 2357 S/D pumps and monitor pressure fall off. ISIP -- 900 psig. 0130 Determine that gel temperature is inadequate. Postpone frac until gel can be heated. 05/20/98 1036 Start pump frac as per redesign. 1102 Wellbore pressured out. S/D pumps. Prepare to turn well over to rig for reverse out. PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM BPM PSIG PSIG BBL BBL COMMENTS 05/19/98 INJECTIVITY TEST DISPLACEMENT = 86.4 BBLS 2218 0 / 8 151 1858 0 0 Start circulating gel to end of tubing. 2225 8.0 153 2087 86 86 2227 8 / 2 150 2069 84 84 Gel at EOT. Slow rate down to 2 bpm and close in choke, bullhead gel to perforations at matrix rate. 2237 2.0 / 0 990 2302 86 86 S/D pumps with gel at perfs allow pressure to stabilize and microfractures to close. 2243 0 / 20 737 856 86 86 Bring up rate for injectivity. Unable to reach desired rate due to trips set at too Iow a pressure. 2244 15 1032 3945 94 94 2245 15 9992 4001 100 / 0 100 Switch to KCI. 2246 19.1 959 3547 31 131 Rates fluctuating trying to get max. rate but losing suction pressure. 2250 15.1 977 92.3 192.3 With gel overdisplaced by 5 bbls. S/D pumps and monitor pressure falloff. IA ISIP - 877 psi 2251 0 851 947 2253 0 819 929 2255 0 807 924 2300 0 785 897 ~2310 0 759 870 2320 0 741 847 PUMPING SUMMARY TIME RATE I ANNP WHP STAGE CUM BPM I PSIG PSIG BBL BBL COMMENTS DATA FRAC 2317 min. n/a 8150 0 PT surface treating lines to 8150. Set trips to 7500 psi. 2322 0 / 8 87 0 192.3 Start circulating gel to the end of the tb_g. 2323 8 190 1826 196 2327 8.0 168 1845 231 2330 8 / 2 149 1936 255 2331 2 800 1927 257 Slow rate to 2 bpm and close in choke. Bullheading fluid into formation at matrix rate. 2335 2.2 911 2055 75 267 2340 2.0 / 0 885 2092 84.7 277 With gel at perfs S/D pumps and allow several minutes for pressure to stabilize and microfractures to close. 2344.5 ( / 20 821 930 84.7 277 Attempt to bring rate up to 20 BPM for dat frac. Unable to reach rate due to losing suction pressure (thick fluid). 2347 10.0 964 3158 311 Rates variable while trying to maximize rate but maintain suction 2349 14.8 982 3360 343 2352 16.7 975 3470 200 / 0 392 Switch to KCl water for flush. Rather than have wide fluctuations in rate try to maintain 17 bpm. for remainder of data frac. 2354 17.34 966 3818 428 Tbg. pressure increasing due to friction pressure of water. 2357 17 / 0 955 5630 91 483.4 Gel overdisplaced by 5 bbl. S/D pumps. Monitor pressure falloff. 2359 0 867 975 483.4 ~05/20 0001 0 861 947 0005 0 821 1007 0010 0 832 92O 0020 0 818 902 0030 0 805 892 0040 0 801 888 0045 0 797 883 FRAC 1036 0 567 543 0 0 Stadfrac. Pumping 62 bbl. 60# HEC gelpad 1038.5 18.5 961 6919 20 20 1039 19.7 965 6901 31 31 1040.5 20.6 959 4548 62/0 62 Stad 1 ppg slurry. PUMPING SUMMARY TIME RATE ANNPI WHP STAGE CUM COMMENTS BPM PSIG! PSIG BBL BBL 1041.5 19.9 963 3619 24 86 Pad on perfs. 1043 20.1 1021 3756 115 1044 19.9 1018 ! 3794 148 1 ppg starting on perfs 1046.5 20.1 1018 I 4150 186 2 ppg starting on perfs 1048 20.2 1003 4406 207 4 ppg starting on perfs . 1049.5 1989 1001 4580 249 6 ppg starting on perfs 1052 20.2 1014 4777 300 1053 20.1 1025 4777 321 8 ppg starting on perfs. Sudden increase in treating pressure. Grit teeth. 1055 20.1 1166 4882 358 Treating pressure stabilized. 1056 20.1 1161 4846 381 1057 20.1 1177 4868 400 1058 20.2 1190 4759 420 1059 19.7 1212 4901 440 Cut sand 1059.5 450 Call flush 1101 20.6 1248 4763 480 1102 20 / 0 1700 4800 496.3 Pressured out on annulus. S/D pumps. Turn wellbore over to the rig to reverse out. Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 483 Bbls FRAC: 496 Bbls 979 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME FLUID ADDITIVES BS 60# / Mgal HEC system w/2.5 gpt J-134, 2 gpt F-75N. Mixed by Baroid. Milne Point Unit, Alaska TO: Hendrix FROM: H. Thackeray Well Name: I MPG-15 Main Category:I;DRLG Sub Category: ELINE PERF Operation Date: 15/21-22-23/98 Date: 15-23-98 I Objective: Eline tractor convey perforate the Schrader Bluff "CA" sands. Sequence of Events: 5/21-22/98 MI RU Atlas E-line unit. MU perf gun and toolstring on rollers. One barrel of EP-Lub had been used in circulating fluid to help tools over 81 degree hump encountered at --, 6500' in prior job. PJSM. PT Lubricator. Start in hole. Tools not reading. POOH. Found O-ring failure. Repair and run back in hole. Bouncing and dragging to 3150'. Unable to make corner where angle increases. Extremely hard pulling out of hole. Tools and rollers clogged with EP-Lub. Cleaned tools and added tractor. Start back in hole. Slow going to 3040'. Started tractor and motored down to 3800' pulling hard at ,-,10 fpm. Received distress call from Rig 18E at S pad and ordered to POOH and RD. 5/21-22/98 Rig 4ES circulated warm fluid to clean out EP-Lub while waiting on Eline return. Atlas came back and RU toolstring and perf gun without tractor. Rolled all the way to bottom at ,-,100 fpm. Correlated to MWD Icg. PBTD determined at 9461'. Positioned gun and perforated "CA" sand from 9430-9455'. POOH RD Atlas. Results: Perforated "CA" sand from 9430-9455' (25') with 4 spf Big Hole charges at 0-180 degree phasing. Learned that EP-Lub is good stuff but very sensitive to temperatures in permafrost. Aisc followed Murphy's Law of E-Line - no matter when you start, all eline jobs shall be done in the middle of the night. Tie in Icg/date: Sperry Sun MWD Ioq 7/25/97 .......... Interval Measured Depth ......... Top Ft. Base Ft. Gun Diameter Shot Density Orientation I4 Phasing BP EXPLORATION (ALASKA)INC. Milne Point Unit 'FO: J. Spearman/J. Hendrix FROM: J. Fox DATE: 05 / 23 / 98 RE: MPU G-15 'CA' SAND DATA FRAC AND PROPLOK FRAC SERVICE CO'S.: Dowell, Halliburton, Nabors, and Peak JOB SUMMARY Approximately 33.5 M # of 12-20 PropLok resin coated natural sand was placed behind pipe. Design (50 M#) plus 4800 lbs. excess was pumped before the wellbore screened out. Achieved approx. 320 psi of net pressure build before screen out. There was a gentle decline in treating pressure as the slurry entered the formation until 6 ppg hit the and then there was a steady pressure build until sudden screen out with 8 ppg (maximum design prop. concentration) having just reached the perfs. All of the proppant was coated at 3/8 gal. / 100# Halliburton PropLok resin.. Because of recent problems getting adequate resin coverage the following changes were made from past practices: · Decreased gel pH to 5.5 to 6.5 · Doubled concentration of resin plasticizer concentration. · No color dyes were used. · heated gel to approx. 100 deg. · 12/20 natural sand was used for the first time. The 12 - 20 sand was initially proposed based on better coating by the resin. It also has the added benefits of better retention in the formation due to more angularity of the sand grains as well as potential cost savings (relative to Carbolite). Note: · It was intended to run a Petredat gauge in a GLM at the end of the tubing however the GLM O.D. was too large to fit through the casing patch. The casing patch was only tested to 2000 psig so that was the determining factor on maximum inner annular pressure during the treating process and the annular pop off setting of 1800 psig.. · All gel used was 60 ppt HEC. HEC being utilized due to incompatibility of guar gel with PropLok. The pH was 7.0 prior to adding the PropLok and 8 after it was added. Fluid temperature downstream of the blender was 96 deg. Gel was circulated to the end of the tubing on both the injectivity and dat frac to save on brine and reduce the amount of fluid lost to the formation. Some difficulty was experienced getting rate when pumping gel on injectivity due to thick fluids. Once on KCI water for displacement there seemed to be little problem (although it required considerably more pump pressure to maintain rate - i.e. friction pressure). The first frac attempt was aborted shortly after starting the slurry due to PropLok resin not making it to the blender when required. The 600 # of proppant pumped was flushed 10 bbls. into the perfs. Annular pressure was limited to 1800 psi due to a casing patch in the DV collar tested to 2000 psi. 06/25/98 2:25 PM DATA FRAC & FRAC SENT VIA MICROSOFT MAIL TIME RATE ANNP WHP STAGE CUM BPM PSIG PSIG BBL BBL PUMPING SUMMARY COMMENTS INJECTIVITY TEST Design Rate, Bbls Max Rate, Final lAP, ISIP, NWB friction, Treat-grad, BPM Pumped bpm psi PSI psi psi/ft max. 100 25 918 820 100 0.65 D~TA FRAC Bbls Bbls HEC gel Time gel on Final IA STP, ISIP, psi NWB friction, Treat grad, Pumped to Perfs perfs psi psi psi/ff 200 200 11 min. 931 918 10 0.655 FRAC Sand Lead prop Tail prop Design total Tresaver pumped behind pipe, behind behind pipe, Liner Sand, rubber left in Job was M# pipe, M# M# M# hole? /size /size Screened out w/ 54,856 # 33.5 M# not 50 M# 21,300 # not 8 ppg on perfs 12/20 applicable applicable Ft of sand Estimated Final IA ISIP, psi ISIP Incr Actual TSO, design, TSO, in Pipe sand top STP, over datafrac sand:pad min Nolte psi ratio Plot 1700 not not 12.6 not appl. applicable applicable DATE/TIME OPERATIONS sUMMARY 05/23/98 1115 Pre-job safety meeting 11145 Pressure test surface lines to 8000 psi. Set trips at 7500 psi. Annulus pop offs set at 1800. 1150 Start circulating 100 bbl. 60 ppt HEC gel pill down tbg. @ 8 bpm taking returns to the pits. 1159 With gel at the end of the tubing slow pump rate to 2 bpm and shut in choke. Bullhead :~ into formation at matrix rates to get gel to perfs. 1214 Bring rate up to max. to start injectivity test. 1220.5 Shut down pumps with gel overdisplaced b~, 5 bbl. Monitor pressure falloff. 1257 Start circulating 200 bbl. HEC pill to end of frac string at 8 bpm. 1306 With gel at the end of the tubing slow pump rate to 2 bpm and shut in choke. Bullhead into formation at matrix rates to get gel to perfs. 1320 Bring rate up to 20 BPM for dat frae. 1327 Switch to KCI for flush. 1331.5 With 5 bbl. of overdisplacement S/D pumps and monitor pressure falloff. ISIP - 918 psig 1506 Start pumping 45 bbl. HEC pad 1509 When it is realized that the PropLok was not making it to the blender sand was cut and flushed 10 bbl. into formation. 1525 Re-start frac job. 1529.5 Pad on perfs. 1532 Proppant on perfs. 1542 Wellbore pressured out. S/D pumps. Turn over to rig to reverse out, PUMPING SUMMARY TIME RATE ANNP WHPISTAGEj CUM GPM PSIG PSIGt BBLI BBL COMMENTS PUMPING SUMMARY TIME I RATE ANNP WHP STAGE CUM COMMENTS I BPM PSIG PSIG BBL BBL 05/23/98 INJECTIVITY TEST DISPLACEMENT = 86.5 BBLS 1149.5 0 / 6 81 968 0 0 Start circulation down tubing. 1154 7 147 1790 43 43 1 !59 8 ! 2 144 1861 62 62 Slow down to 2 bpm and shut in choke. 1200 2 1034 1234 64 64 Bull heading into formation at matrix rates. 1205 1,9 764 1673 73 73 1211 2 ! 0 799 1770 86.5 86.5 With gel at perfs shut down for several minutes. 1214 0 ! max. 750 776 86.6 86.6 Start displacement of gel for injectivity test. 11216 var. 900 2831 8 108 On KCI water. Lost prime 1217 20 948 4356 24 124 At rate. 1218 23 940 6160 49 149 1219 25 921 70 170 1219.5 20 / 2 916 5834 80 180 Slow to 20 bpm for the last 20 bbl. 1220,5 2 ! 0 918 6156 93.8 193.8 With 5 bbl. of over displacement S/D pumps and monitor pressure falloff. 1222 0 763 881 1225 0 730 826 1230 0 704 794 1240 0 671 762 1250 0 636 726 DATA FRAC 1251 0 514 ! 529 0 193.8 Prepare to start - open choke J 1257 0 ! 8 23 ! 155 99 ! 1435 0 193.8 Start circulating 200 bbl. HEC gel down the tbg.' 1300 8 164 1541 213 1305 8 ! 2 147 1710 61 255 Slow down to 2 bpm and shut choke. Bullheading into formation at matrix rates. 1306 2.0 481 1303 64 258 Choke closed. 1310 2.0 854 1641 72 266 1316 1.9 / 0 850 1650 85 279.0 S/D pumps for several minutes, 1320 0 / 20 814 840 85 279 Start data frac. 1321 20 933 4447 291 At 20 bpm design rate. 1326 20.2 937 4122 375 1327 20.2 942 4100 200 392 Switch to KCI for displacement, 1328 20.4 940 4104 417 329 19.9 937 I 4630 436 1 1330 20.0 933 I 5651 452 1331 19.9 933I 6984 472 , ~ PUMPING SUMMARY TIME RATE ANNP WHP STAGE CUM COMMENTS BPM PSIG PSIG BBL BBL 1331.5 20 / 0 931 675 91.6 485.4 With 5 bbl. of over displacement S/D pumps and monitor pressure falloff. 1333 0 836 927 1335 0 812 900 1340 0 785 868 1350 0 752 836 1400 0 739 822 1410 0 724 808 ,1416 0 713 799 FRAC 1506 0 583 666 0 0 Prepare to start. Pumping 45 bbl HEC pad. 1506.5 20 900 6709 15.3 15.3 At design rate 1509 20.4 894 5903 45 / 0 45 Start slurry. 1510 20.1 893 4768 15 60 No PropLok - abort frac cut sand and go to flush. ~1512 19.9 920 4150 100 1515 20 / 0 880 1243 150.2 Shut down pumps and prepare to restart. 1525 0 / 20 777 849 0 0 Restart frac 1526.5 20 970 4585 15 At design rate. 1528 20.2 971 4443 45 / 0 45 Start slurry - I ppg 1529.5 19.9 966 4054 86 Pad on perfs. 1530.5 19.7 964 4081 100 1532 19.9 959 4246 131 Propppant on perfs. 1533 20.1 953 4859 168 2 ppg just reaching perfs. 1534.5 20.1 938 4930 180 3 ppg just reaching perfs. 1536 20.2 929 5033 204 5 ppg just reaching perfs. 1537 20.1 938 5038 228 6 ppg. just reaching perfs. 1538 20.1 955 5111 252 7 ppg just reaching perfs. 1540.5 20.1 1055 5129 300 8 ppg just reaching perfs. 1541 20.1 1158 5152 310 Pressure starting to build quickly. 1542 20 / 0 6000 1800 328.6 Pressured out. S/D pumps and turn wellbore over to rig to reverse out. The end. Page 6 FLUIDS PUMPED DOWNHOLE INJ TEST& DATA FRAC: 485 Bbls FRAC: 478 Bbls 963 TOTAL FLUIDS PUMPED DOWN HOLE LOAD VOLUME FLUID ADDITIVES DS 60#/Mgal HEC system w/2.5 gpt J-134, 2 gpt F-75N. Mixed by Baroid. SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 SPT Y-SUN DRILLING SERVICES ANCHORAGE ALASKA DATE OF SURVEY: 072597 MWD SURVEY KELLY BUSHING ELEV. = OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -58.80 112.00 112.00 53.20 203.78 203.78 144.98 296.12 296.12 237.32 387.41 387.38 328.58 0 0 N .00 E .00 .00N .00E 0 0 N .00 E .00 .00N .00E 0 22 N 84.07 E .40 .03N .29E 0 36 N 65.01 W 1.03 .27N .15E 1 47 N 67.07 W 1.29 1.03N 1.61W .00 .00 -.08 .20 1.54 477.24 477.12 418.32 569.21 568.85 510.05 659.16 658.22 599.42 752.95 750.79 691.99 842.28 838.11 779.31 3 6 N 67.43 W 1.47 2.51N 5.15W 5 1 N 44.27 W 2.70 6.35N 10.26W 7 52 N 40.33 W 3.22 13.87N 17.00W 10 34 N 41.62 W 2.88 25.20N 26.88W 13 43 N 40.59 W 3.53 39.38N 39.22W 4.21 9.64 19.10 33.25 50.93 932.01 924.64 865.84 1027.16 1014.87 956.07 1119.32 1100.85 1042.05 1211.55 1185.26 1126.46 1305.25 1269.26 1210.46 16 58 N 32.52 W 4.34 58.51N 53.19W 19 58 N 30.73 W 3.21 84.21N 68.97W 22 12 N 35.59 W 3.07 lll.91N 87.15W 25 17 N 33.89 W 3.42 142.45N 108.29W 27 17 N 32.85 W 2.20 177.12N 131.11W 73.84 103.51 135.93 172.06 212.64 1397.14 1350.90 1292.10 1489.91 1432.48 1373.68 1582.58 1512.91 1454.11 1674.09 1591.71 1532.91 1766.42 1669.63 1610.83 27 19 N 31.31 W 29 31 N 34.77 W 30 2 N 37.33 W 31 2 N 36.73 W 33 50 N 35.50 W .77 2.96 1.48 1.13 3 12 212.84N 153.50W 249.82N 177.61W 287.03N 204.70W 324.16N 232.70W 364.18N 261.88W 254.06 297.27 341.78 386.55 434.43 1857.79 1744.56 1685.76 1949.83 1817.79 1758.99 2041.18 1888.40 1829.60 2134.22 ~ 1957.22 1898.42 2227.96 2021.92 1963.12 35 56 N 36.00 W 38 37 N 38.37 W 40 7 N 37.50 W 44 26 N 37.71 W 48 14 N 37.50 W 2 32 3.31 1 74 4.65 4 06 406.58N 292.41W 450.97N 326.13W 496.67N 361.75W 546.25N 399.94W 599.97N 441.31W 485.03 538.63 594.15 654.21 719.29 2317.62 2080.24 2021.44 2408.39 2135.64 2076.84 2502.45 2188.33 2129.53 2594.42 2235.18 2176.38 2685.80 2278.09 2219.29 50 35 N 37.05 W 54 9 N 34.66 W 57 41 N 32.92 W 61 3 N 30.36 W 62 55 N 28.66 W 2 66 4.44 4 05 4.38 2.62 654.14N 482.54W 712.42N 524.61W 777.17N 567.91W 844.55N 609.39W 914.75N 649.11W 784.74 854.32 930.38 1008.22 1088.05 2778.84 2319.21 2260.41 2872.47 2357.26 2298.46 2965.53 2389.65 2330.85 3058.75 2416.04 2357.24 3151.56 2435.74 2376.94 64 37 N 24.10 W 67 25 N 20.70 W 71 49 N 19.31 W 75 16 N 18.57 W 80 11 N 18.05 W 4.76 989.50N 686.16W 4.46 1068.59N 718.73W 4.94 1150.54N 748.55W 3.78 1235.10N 777.56W 5.33 1321.17N 806.04W 1171.16 1256.67 1343.86 1433.18 1523.72 ORIGINAL SPt' Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 072597 MWD SURVEY JOB NUMBER: AK-MM-70216 KELLY BUSHING ELEV. = 58.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3246.23 2450.67 2391.87 81 39 3338.08 2463.97 2405.17 81 41 3430.27 2476.85 2418.05 82 14 3522.38 2490.80 2432.00 80 19 3615.15 2506.16 2447.36 80 36 N 17.40 W 1.68 1410.21N 834.49W N 17.66 W .28 1496.87N 861.87W N 17.42 W .64 1583.92N 889.38W N 19.09 W 2.74 1670.36N 917.89W N 19.47 W .50 1756.72N 948.10W 1617.01 1707.70 1798.79 1889.68 1981.12 3708.55 2521.60 2462.80 3800.06 2536.77 2477.97 3891.74 2552.07 2493.27 3987.75 2569.01 2510.21 4083.25 2586.84 2528.04 80 21 80 33 80 13 79 26 79 2 N 19.16 W .42 1843.65N 978.57W N 18.95 W .31 1928.95N 1008.03W N 18.96 W .36 2014.44N 1037.39W N 20.98 W 2.23 2103.24N 1069.66W N 20.57 W .59 2190.96N 1102.94W 2073.17 2163.35 2253.67 2348.13 2441.94 4177.30 2605.07 2546.27 4270.04 2622.27 2563.47 4369.09 2639.28 2580.48 4464.49 2655.07 25.96.27 4560.01 2670.82 2612.02 78 36 8O 0 80 12 80 44 80 16 N 20.09 W .68 2277.48N 1134.99W N 20.60 W 1.60 2362.92N 1166.67W N 20.81 W .29 2454.19N 1201.17W N 20.48 W .65 2542.24N 1234.34W N 21.52 W 1.18 2630.19N 1268.10W 2534.20 2625.31 2722.88 2816.96 2911.16 4655.51 2685.85 2627.05 4751.26 2700.72 2641.92 4845.68 2715.79 2656.99 4941.14 2732.09 2673.29 5036.38 2749.41 2690.61 81 37 80 29 81 9 79 10 79 51 N 21.15 W 1.47 2718.03N 1302.41W N 21.56 W 1.26 2806.12N 1336.85W N 21.75 W .73 2892.75N 1371.25W N 22.98 W 2.42 2979.71N 1407.03W N 22.11 W 1.15 3066.20N 1442.93W 3005.47 3100.05 3193.25 3287.28 3380.90 5132.23 2767.96 2709.16 5227.66 2787.86 2729.06 5321.25 2806.94 2748.14 5416.13 2826.10 2767.30 5514.21 2845.30 2786.50 77 49 78 6 78 21 78 20 79 4 N 22.10 W 2.13 3153.31N 1478.32W N 21.91 W .36 3239.85N 1513.29W N 21.87 W .27 3324.86N 1547.45W N 22.40 W .55 3410.94N 1582.46W N 21.88 W .92 3500.03N 1618.70W 3474.91 3568.24 3659.86 3752.77 3848.94 5608.34 2861.79 2802.99 5703.50 2877.33 2818.53 5798.68 2894.00 2835.20 5894.53 2911.32 2852.52 5990.18 2927.98 2869.18 80 44 80 28 79 20 79 49 80 6 N 21.51 W 1.81 3586.13N 1652.96W N 23.74 W 2.33 3672.77N 1689.07W N 23.38 W 1.23 3758.66N 1726.52W N 24.67 W 1.42 3844.76N 1764.90W N 24.00 W .75 3930.58N 1803.71W 3941.60 4035.44 4129.07 4223.23 4317.29 6085.12 2944.07 2885.27 6181.62 2959.83 2901.03 6277.14 2975.72 2916.92 6372.66 2991.43 2932.63 6468.29 3006.95 2948.15 80 22 80 49 8O 1 81 3 80 16 N 24.01 W .27 4016.05N 1841.78W N 23.85 W .50 4103.07N 1880.39W N 23.80 W .85 4189.23N 1918.44W N 23.99 W 1.10 4275.37N 1956.60W N 22.55 W 1.70 4362.05N 1993.88W 4410.75 4505.85 4599.95 4694.07 4788.36 SPt Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 072597 MWD SURVEY JOB NUMBER: AK-MM-70216 KELLY BUSHING ELEV. = 58.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6564.42 3024.00 2965.20 6660.10 3041.00 2982.20 6755.16 3058.00 2999.20 6850.94 3074.99 3016.19 6946.06 3091.43 3032.63 79 18 80 13 79 9 80 24 79 41 N 22.34 W 1.03 4449.49N 2030.00W N 21.75 W 1.15 4536.76N 2065.34W N 21.14 W 1.29 4623.80N 2099.53W N 21.30 W 1.30 4711.67N 2133.65W N 21.37 W .74 4798.93N 2167.73W 4882.95 4977.09 5070.61 5164.87 5258.55 7039.07 3109.14 3050.34 7135.57 3128.12 3069.32 7228.60 3145.80 3087.00 7327.22 3163.81 3105.01 7365.67 3170.67 3111.87 78 20 78 58 79 6 79 50 79 37 N 20.59 W 1.68 4884.18N 2200.42W N 21.33 W 1.00 4972.53N 2234.27W N 20.64 W .74 5057.81N 2266.98W N 21.25 W .96 5148.36N 2301.64W N 21.36 W .64 5183.60N 2315.38W 5349.85 5444.46 5535.79 5632.75 5670.58 7460.90 3188.02 3129.22 7554.82 3205.24 3146.44 7651.51 3222.83 3164.03 7747.05 3242.81 3184.01 7842.30 3265.94 3207.14 79 22 79 29 79 33 76 18 75 35 N 20.66 W .77 5271.01N 2348.95W N 20.96 W .34 5357.32N 2381.75W N 20.85 W .13 5446.14N 2415.68W N 21.00 W 3.41 5533.39N 2449.04W N 21.22 W .77 5619.59N 2482.32W 5764.22 5856.54 5951.61 6045.03 6137.42 7938.65 3290.26 3231.46 8034.51 3317.22 3258.42 8130.22 3350.10 3291.30 8225.85 3389.53 3330.73 8320.39 3431.76 3372.96 75 9 72 10 67 37 63 40 63 16 N 20.77 W .65 5706.62N 2515.72W N 21.18 W 3.13 5792.51N 2548.64W N 20.28 W 4.85 5876.54N 2580.46W N 20.00 W 4.14 5958.32N 2610.45W N 20.14 W .44 6037.77N 2639.48W 6230.65 6322.63 6412.48 6499.56 6584.13 8415.68 3476.43 3417.63 8511.81 3525.65 3466.85 8607.15 3578.96 3520.16 8700.59 3635.46 3576.66 8795.79 3697.39 3638.59 60 48 57 34 54 25 51 9 47 40 19.37 W 2.68 6116.96N 2667.93W 19.42 W 3.36 6194.83N 2695.34W 17.34 W 3.78 6269.81N 2720.28W 17.75 W 3.51 6340.76N 2742.71W 18.22 W 3.69 6409.52N 2765.02W 6668.24 6750.75 6829.68 6903.93 6976.09 8890.40 3763.11 3704.31 8984.91 3832.84 3774.04 9080.60 3906.36 3847.56 9175.94 3980.50 3921.70 9271.73 4055.16 3996.36 44 18 40 35 38 59 38 55 38 40 N 19.46 W 3.67 6473.92N 2786.97W N 21.61 W 4.22 6533.65N 2809.30W N 24.36 W 2.49 6590.01N 2833.18W N 23.87 W .33 6644.72N 2857.67W N 23.70 W .28 6699.64N 2881.88W 7044.06 7107.82 7169.01 7228.88 7288.84 9366.46 4129.18 4070.38 9462.50 4204.46 4145.66 9558.23 4279.85 4221.05 9653.14 4354.97 4296.17 9748.95 4431.17 4372.37 38 32 38 13 37 52 37 29 37 7 N 23.57 W .15 6753.79N 2905.58W N 23.79 W .37 6808.41N 2929.53W N 24.08 W .41 6862.33N 2953.46W N 24.38 W .44 6915.23N 2977.27W N 24.46 W .38 6968.11N 3001.28W 7347.91 7407.49 7466.42 7524.36 7582.35 SP5 .r-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 072597 MWD SURVEY JOB NUMBER: AK-MM-70216 KELLY BUSHING ELEV. = 58.80 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 9768.48 4446.74 4387.94 37 6 N 24.75 W .90 9845.00 4507.77 4448.97 37 6 N 24.75 W .00 6978.83N 3006.19W 7594.11 7020.76N 3025.51W 7640.20 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7644.92 FEET AT NORTH 23 DEG. 18 MIN. WEST AT MD = 9845 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 338.70 DEG. TIE-IN SURVEY AT SURFACE 0.00' MD PROJECTED SURVEY AT 9,845.00' MD SP° '~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 072597 JOB NUMBER: AK-MM-70216 KELLY BUSHING ELEV. = 58.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH .00 .00 -58.80 1000.00 989.28 930.48 2000.00 1856.91 1798.11 3000.00 2400.04 2341.24 4000.00 2571.26 2512.46 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 N .00 E .00 76.41 N 64.29 W 10.72 10.72 475.62 N 345.59 W 143.09 132.37 1181.59 N 759.34 W 599.96 456.87 2114.49 N 1073.97 W 1428.74 828.78 5000.00 2743.01 2684.21 6000.00 2929.67 2870.87 7000.00 3101.25 3042.45 8000.00 3306.97 3248.17 9000.00 3844.30 3785.50 3033.02 N 3939.42 N 4848.36 N 5761.77 N 6542.78 N 1429.45 W 2256.99 828.25 1807.65 W 3070.33 813.34 2186.97 W 3898.75 828.42 2536.78 W 4693.03 794.28 2812.92 W 5155.70 462.67 9845. 00 4507. 77 4448.97 7020.76 N 3025.51 W 5337.23 181.53 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPI Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 072597 JOB NUMBER: AK-MM-70216 KELLY BUSHING ELEV. = 58.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -58.80 58.80 58.80 .00 158.80 158.80 100.00 258.80 258.80 200.00 358.82 358.80 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .00 N .01 E .00 .00 .10 N .50 E .00 .00 .68 N .79 W .02 .01 458.89 458.80 400.00 559.12 558.80 500.00 659.75 658.80 600.00 761.10 758.80 700.00 863.62 858.80 800.00 2.13 N 4.23 W .09 .07 5.72 N 9.65 W .32 .23 13.93 N 17.05 W .95 .62 26.34 N 27.89 W 2.30 1.36 43.41 N 42.52 W 4.82 2.51 967.85 958.80 900.00 1074.08 1058.80 1000.00 1182.40 1158.80 110.0.00 1293.48 1258.80 1200.00 1406.05 1358.80 1300.00 67.69 N 58.94 W 98.16 N 77.72 W 132.34 N 101.43 W 172.58 N 128.18 W 216.35 N 155.66 W 9.05 4.23 15.28 6.23 23.60 8.32 34.68 11.08 47.25 12.57 1520.16 1458.80 1400.00 1635.69 1558.80 1500.00 1753.43 1658.80 1600.00 1875.44 1758.80 1700.00 2002.47 1858.80 1800.00 262.07 N 186.11 W 308.32 N 220.87 W 358.34 N 257.69 W 414.99 N 298.59 W 476.89 N 346.56 W 61.36 14.11 76.89 15.54 94.63 17.73 116.64 22.02 143.67 27.03 2136.46 1958.80 1900.00 2283.85 2058.80 2000.00 2448.73 2158.80 2100.00 2643.43 2258.80 2200.00 2876.54 2358.80 2300.00 547.50 N 400.90 W 633.32 N 466.81 W 739.72 N 543.20 W 881.64 N 631.01 W 1072.12 N 720.05 W 177.66 33.98 225.05 47.39 289.93 64.88 384.63 94.70 517.74 133.12 3302.25 2458.80 2400.00 3931.40 2558.80 2500.00 4487.68 2658.80 2600.00 5088.39 2758.80 2700.00 5589.74 2858.80 2800.00 1463.09 N 851.11 2051.41 N 1050.10 2563.68 N 1242.35 3113.59 N 1462.18 3569.05 N 1646.23 W 843.45 325.71 W 1372.60 529.15 W 1828.88 456.28 W 2329.59 500.71 W 2730.94 401.35 6175.13 2958.80 2900.00 6759.40 3058.80 3000.00 7298.81 3158.80 3100.00 7813.61 3258.80 3200.00 8152.54 3358.80 3300.00 4097.21 N 1877.80 4627.69 N 2101.03 5122.29 N 2291.50 5593.68 N 2472.26 5895.83 N 2587.57 W 3216.33 485.39 W 3700.60 484.27 W 4140.01 439.41 W 4554.81 414.80 W 4793.74 238.93 SPI Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPG-15 500292278400 NORTH SLOPE BOROUGH COMPUTATION DATE: 8/22/97 DATE OF SURVEY: 072597 JOB NUMBER: AK-MM-70216 KELLY BUSHING ELEV. = 58.80 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE 8379.52 3458.80 3400.00 6087.18 N 2657.45 W 4920.72 8571.96 3558.80 3500.00 6242.35 N 2711.48 W 5013.16 8737.25 3658.80 3600.00 6367.68 N 2751.37 W 5078.45 8884.34 3758.80 3700.00 6469.90 N 2785.56 W 5125.54 9019.10 3858.80 3800.00 6554.33 N 2817.49 W 5160.30 VERTICAL CORRECTION 126.98 92.44 65.30 47.09 34.75 9148.05 3958.80 3900.00 6628.70 N 2850.58 W 5189.25 9276.39 4058.80 4000.00 6702.31 N 2883.05 W 5217.59 9404.33 4158.80 4100.00 6775.42 N 2915.01 W 5245.53 9531.56 4258.80 4200.00 6847.39 N 2946.78 W 5272.76 9657.97 4358.80 4300.00 6917.91 N 2978.48 W 5299.17 28.95 28.35 27.93 27.24 26.41 9783.60 4458.80 4400.00 6987.11 N 3010.00 W 5324.80 9845.00 4507.77 4448.97 7020.76 N 3025.51 W 5337.23 25.63 12.44 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS State of Alaska Alaska Oil & Gas Conservation Comm. Atten: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 30-May-98 Transmittal of Final Prints. Please sign and return copy to the following: Western Altas Logging Services Pouch 340013 Prudhoe Bay, AK 99734-0013 and BP Exploration (Alaska)Inc. Petrotechnical Data Center MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Well Name Services Bluelines R/F Sepia Film ~t ' I ~'~ MPG-15 GR/PERF 1 1 ~ MPG-15 GR/PERF I 1 Contact Rebecca Lange if you have a question concerning this transmittal at (907) 659-2816 or Fax (907) 659-2602. 0 I~ I I--I--I IM G SEI~ICES WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3 001 Porcupine Dr. Anchorage, Alaska 99501 ~ ~ [~ r~ MWD Formation Evaluation Logs - MPG-15, AK-MM-70216 September 17, 1997 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention off Tan Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 Ml~o-15: 2" x 5" MD Resistivity and Cramma Ray Logs: 50-029-22784-00 2" x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22784-00 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc, Company WELL LOG TRANSMITI'~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 September 17, 1997 RE: MWD Formation Evaluation Logs - MPG-15 AK-MM-70216 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of~ Ytm Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, CIG, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-22784-00 R CEIVED S EP '1 7 1997 0il & Gas 0ohs. Commit~0n Anchom§e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 19, 1997 Tim Schofield Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 1966 ! 2 Anchorage, AK 99519-6612 Milne Point Unit MPG- 15 BP Exploration (Alaska), Inc. Permit No. 97-122 Sur. Loc: 2074'NSL.3455'WEL.SEC 27.TI3N.R10E.UM Btmholc Loc:3726'NSL, 1132'WEL.SEC 21.T13N.R10E. UM Dear Mr. Schoficld: Enclosed is thc approved application for permit to drill the above referenced well. The permit to drill docs not exempt you from obtaining additional pcrmits required bx' law from other governmental agcncics, and docs not authorize conducting drilling operations until all other required permitting determinations arc made. Blowout prevention cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of thc BOPE test performed before drilling below thc surf'acc casing shoe must be given so that a rcprcscntativc of thc Commission max' witness thc test. Notice mav be givcn bv contacting thc Commission pctrolcum ficld inspector on thc North Slope pager at 659-3607. Sin . - David W. Johnston Chairman BY ORDER OF THE COMMISSION -- STATE OF ALASKA ALASKA OI-L ,-~ND GAS CONSERVATION COMM.,.,SION PERMIT TO DRILL 20 AAC 25.005 la. Type of work ~] Drill I-IRedrill lb. Typeofwell [--I Exploratory I--IStratigraphicTest I~ Development Oil [] Re-Entry [] Deepen []Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 59.30' Milne Point Unit / Schrader Bluff 3. Address 6. Property Designation P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 315848 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2074' NSL, 3455' WEL, SEC. 27, T13N, R10E, UM Milne Point Unit At top of productive interval 8. Well Number Number 2S100302630-277 3399' NSL, 1004' WEL, SEC. 21, T13N, R10E, UM MPG-15 At total depth 9. Approximate spud date Amount $200,000.00 3726' NSL, 1132' WEL, SEC. 21, T13N, R10E, UM 07/24/97 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 025516, 1132'I No Close Approach 2560 9713' MD / 4392' TVD 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e)(2)} Kick Off Depth 300' Maximum Hole Angle 79.58° Maximum surface 1380 psig, At total depth (TVD) 4200' / 1800 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.4# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 8-1/2" 7" 26# L-80 BTC-Mod 9682' 31' 31' 9713' 4392' 860 sx PF 'E', 473 sx Class 'G' 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 Surface IntermediateRECEIVED Production 0P /GINAL ." .,,:AlaskaOii&ffnaZOo na OornillisslUh Perforation depth: measured true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mark Brofka, 564-4809 Prepared By Name/Number: Kathy Campoamor, 564-5122 21. I hereby certify that the foregoing is ljrue and pqrrect to the best of my knowledge Signed ~ .~;/~;L~ '[~/ ~/~l_~/q Tim Schofield '"'//(,~'t] :: ( 22~' Title Senior Drilling Engineer Date 7 ' .~ Commission Use Only Permit Number I APl Number I Approval,Date See cover letter ~,,~-,,/.~.. ;;Z..I 50- ~:~2..~'" ~--...~--- ~' ~YI ~//'~/~3 for other requirements iCor~di~tions of Approval: Samples Required []Yes J~No Mud Log Requi[ed / []Yes I~No Hydrogen Sulfide Measures []Yes J~]No Directional Survey Required []Yes [] No Required Working Pressure for BOPE j~2M; 1--13M; I-]5M; I-'I10M; I-I15M Other: ":-,,-,~,'-,~ Signed By u, ,~,,,-'., by order of Approved By David W, Johnston Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submt cate Shared Services Drilling Contact: I Well Name: Type of Well (producer or injector): Mark J. Brofka 564-4809 IMPG-15 I Well Plan Summary ISCHRADER BLUFF PRODUCER ISurface Location: Tar~let Location: Bottom Hole Location: 2074 FSL, 3455 FEL, S27 T13N R10E UM 3399 FSL, 1004 FEL, S21 T13N R10E UM 3726 FSL, 1132 FEL, S21 T13N R10E UM I AFE Number: 1 337085 I Estimated Start Date: 124 July 1997 I I Operating days to complete: I 10 MD: I9713' I ITVD: 14392' I IKBE: I59.30 I Ri~l: I Nabors 22E Well Design: I Schrader Bluff Producer Formation Markers: Formation Tops MD TVD (bkb) KOP 3OO 3OO Base of Permafrost 1898 1784 Top of Ugnu 8402 3457 Top M Sand 8822 3711 Top NA (Target) 9127 3942 Top of Schrader Bluff Sands (EMW 8.6 ppg) NB 9170 3975 NCND 9203 4000 NE 9238 4027 NF 9302 4076 CA 9345 4109 CA4 9388 4142 OB 9436 4179 Top of Seabee 9473 4207 Base of Schrader Bluff Sands (EMW 8.3 ppg) TD 9713 4392 TD at 240' MD past base of Schrader Casing/Tub in~l Program: Hole Size ' Csg~ Wt/Ft Grade Conn. Length Top Bottom Tbg O.D. MD/TVD MD/TVD (bkb) 24" 20" 91.4# H-40 Weld 80' 32'/32' 112' / 112' 8-1/2" 7" 26# L80 BTC-MOD 9,682 31'/31' 9,713' / 4,392' Internal yield pressure of the 7" 26# casing is 7240 psi. With a full column of gas (0.10 psi/ft) to the reservoir at ±4200' TVDSS, the maximum anticipated surface pressure assuming a reservoir pressure of 1800 psi (8.65 ppg EMW), is 1380 psi, well below the internal yield pressure rating of the 7" casing. RECEIVED ~xl,~<~, ('),1 .~, ~','=~ hens. Commission Logging Program: Open Hole Logs: Cased Hole Logs: Mudloggers are NOT mc MWD from surface to TD LWD (GPJResistivity) from top of Ugnu to TD with a controlled drilling speed of no more than 200 ft/hr from 8402 - 9713' MD. Drop ESS survey tool at TD to correlate with MWD surveys. NONE GR/CCL in production casing with completion rig) uired for this well. Mud Program: Spud Mud ISpecial design considerations ISee "Drilling Hazards and Risks" section about dealing with the possibility of hydrates SPUD TO TOP OF SCHRADER BLUFF: I , . Density Marsh Yield 10 sec 10 min pH Fluid :(PPG) Viscosity Point gel gel Loss 8.5 80 15 8 10 9 10-15 (initial) to to to to to to to 9.0 100 35 15 30 10 8-10 (final) TOP OF SCHRADER BLUFF TO TD: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 50 10 3 7 9.0 4 to to to to to to to 9.3 80 (as 20 10 20 9.5 6 required) Well Control: Well control equipment consists of: Drilling Rig (Nabors 22E) 21-1/4", 2000 psi W.P. Diverter with 10" Diverter Line. Completion Rig with 5000 psi W.P. pipe rams, blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE, and drilling fluid system schematics on file with AOGCC. Directional: I KOP: I 300', Phased Build and Drop, S-shaped I Maximum Hole Angle: 79.58° Close Approach Well: NONE Waste Management: Cuttings Handling: All cuttings will be hauled to the CC-2A facility. In the event that the bridges are not usable due to breakup, all cuttings will be placed in the Milne Point A-Pad reserve pit. Fluids Handling: All drilling and completion fluids will be hauled to CC-2A for injection. If the bridges over the rivers are not usable because of breakup, class 2 waste fluids will be hauled to the Kuparuk injection well and class 1 fluids will be transferred to storage tanks for future disposal after breakup. Annular Injection: No wells on G-Pad have been permitted for annular injection. . 2. 3. 4. 5. . . . 10. 11. 12. 13. 14. 15. 16. MP G-15 Proposed Summary of Operations Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. N/U and function test 21-1/4" Hydril MSP 2M diverter system. Build Spud Mud. Drill an 8-1/2" surface hole as per directional plan to 9713' MD / 4392' TVD. Run Directional MWD and LWD GR/Res from surface to TD. Change MWD when tripping for the second bit and drill at a controlled rate of no more than 200 fi/hr through the Schrader Bluff sands. At TD, make a wiper trip to the last bit trip depth and condition hole, making sure to record any tight spots. Run and cement 7", 26#, L80, BTC-MOD casing. Cement job will be performed in two (2) stages, as per the cement program, with an ES cementer set at least 200' MD below the permafrost. N/D Diverter. N/U FMC Gen 6 Wellhead and Tree. RDMO Nabors 22E drilling rig to drill next well. (End of Nabors 22E operations) MIRU completion rig. N/U & Test BOPE. Drill out ES cementer and clean out the well. Run GR/CCL tool. Perform completion job. MPG-15 will be a single trip completion candidate. Set BPV. N/D BOP stack and N/U X-mas tree. RDMO with completion rig. Install Surface Lines and Wellhouse and tum well over to production. DRILLING HAZARDS AND RISKS: The well is planned as a Schrader Bluff single casing string producer. The well will be drilled, cased, and cemented with Nabors 22E which will then suspend the well and move on. The well will be completed at a later date by a completion rig. See the latest Milne Point G-Pad Data Sheet prepared by Pete Van Dusen for information on G pad. The MPU PE group MAY be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. ,1. Hydrates: Hydrates have occurred on nearby E and H pads and there is a possibility that hydrates may be encountered in the drilling of MPG-15. in the eight wells previously drilled on G-pad, only G-8 encountered gas-cut mud, but only a minor amount. Hydrates on MPG-15 are not expected, but if hydrates are encountered, mud weights will be increased to 10.2 ppg, or heavier if required, and lecithin (DrillTreat) will be added to the mud system. The cement program includes an ES cementer set below the permafrost. Should hydrates be encountered while drilling, the cement program will be modified to include a Permafrost C tail on the second stage to ensure a high quality cement seal above the hydrate zones. Also, weighted spacers will be used during the cement displacement to maintain the hydrostatic head on the formation so as to prevent the movement of hydrates into the wellbore. 2. Close Approach: There are no close approach problems with MPG-15. 3. Lost Circulation: Lost circulation has been experienced when drilling the Schrader sands and can be countered by having LCM on hand. To date, losses seen on past wells in the area have been minor. 4. Stuck Pipe Potential: No stuck pipe incidents have occurred on G Pad to date, but the rig crew should remain attentive and take precautions to prevent stuck pipe from occurring. If heavy gravels are encountered, operations should be immediately stopped while the mud funnel viscosity is increased to 150 cp and maintained through the gravel section. 5. Formation Pressure: The expected pore pressure for this well is 8.6 ppg EMW in the Schrader Bluff NA and NB sands, and 8.3 ppg EMW at TD just past the OB sands. 6. Directional Drillinq Concern.~ Also, due to the relatively shallow depth of the Schrader Bluff wells and the large stepouts, some directional drilling will have to be done in the permafrost. The rig crew should be particularly attentive to the wellbore trajectory to ensure that the target objectives are met. Note that care must be taken when drilling through the base of the permafrost as severe doglegs may develop. Also, the producer wells will have a high sail angle and then drop into the reservoir section to allow for the completion. 7. Other There have been only a handful of wells drilled on the North Slope with an 8-1/2" surface hole and it is important that bit and directional performance is closely monitored and reported so that lessons learned can be included in the next well program. None of the drilling hazards and risks identified above are expected to be magnified by the change in hole size. MPG-15 7" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 7" CIRC. TEMP SPACER: 50 bbls fresh water spacer (1307' in 7" casing). STAGE1 LEAD: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder + CELLO-FLAKES (0.25 Ib/sk) 12.0 ppg YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk 430 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. ANNULAR VOLUME FROM THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (8322' MD) TO THE ES CEMENTER STAGE TOOL (2100' MD > 200' MD BELOW BASE OF PERMAFROST) + 30% EXCESS. 'STAGE1 TAIL CEMENT TYPE: ADDITIVES: i WEIGHT: I APPROX #SACKS: FLUID LOSS: PREMIUM SILICATE (15 #/sk), CFR-3 (0.2%), HALAD-344 (0.75%) 13.1 ppg YIELD:2.05 ft3/sk MIX WATER: 11.0 gal/sk 473 SACKS THICKENING TIME: Greater than 4 hrs at 50° F. 0-55 cc/30min TAIL CEMENT FROM TD (9713' MD) TO THE GREATER OF EITHER 100' TVD OR 500' MD ABOVE THE TOP OF THE UGNU "M" SANDS (8322' MD) + 30% EXCESS + 80' OF 7" 26# CASING CAPACITY FOR SHOE TRACK. STAGE2: ADDITIVES: WEIGHT: APPROX #SACKS: TYPE 'E' PERMAFROST Retarder 12.0 ppg 43O SACKS YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. PUMP UNTIL RETURNS ARE OBSERVED AT SURFACE BEFORE DROPPING CLOSING PLUG. +/- 250% EXCESS IS EXPECTED FROM THE ES CEMENTER TO SURFACE. WELLHEAD STABILITY CEMENT TYPE: Permafrost E NOTE: ADDITIVES: Retarder WELLHEAD STABILITY CEMENT WILL BE PUMPED ONLY IF THE CEMENT TOP FALLS BELOW SURFACE AFTER THE PUMPS ARE SHUT DOWN. WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sk MIX WATER: 11.63 gal/sk RECIPROCATE CASING STRING WHILE CEMENTING IF POSSIBLE/PRACTICAL CENTRALIZER PLACEMENT: 1. Centralize the casing from TD to 100' MD above Ugnu "M" Sands with 7-1/8" x 8-1/4" Rigid Straight Blade Centralizers - two (2) per joint on the bottom twenty-five (25) joints of 7" casing (50 Rigid Straight Blade Centralizers). 2. Run two (2) Rigid Straight Blade Centralizers on either side of the ES cementer tool. OTHER CONSIDERATIONS: Perform any necessary laboratory tests on samples of the water to be used in the cement job to ensure that it is adequate. Also perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 4.5 - 6.0 bpm - pump rates are crucial to keep ECD's Iow. Mix slurry on the fly -- batch mixing is n. ot necessary. Be sure to keep detailed records of the cement job, and to report the amount of returns seen from both stages so that volumes can be modified on future wells if necessary. CEMENT VOLUME: 1st Stage: 1. The lead slurry volume is calculated to cover from the ES cementer tool (200' MD below base of permafrost) to the top of the tail slurry, at the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands, with 30% excess. 2. The tail slurry volume is calculated to cover the greater of either 500' MD or 100' TVD above the top of the Ugnu "M" Sands to TD with 30% excess. 3. 80' of 7', 26# capacity for the float joints (baffle collar, float collar, and float shoe). 2nd Stage: The slurry volume is calculated to cover from the ES cementer to surface with an excess of 250% expected to be required. Ensure that additional sacks of cement aro onsite and available for use The slurry will be pumped until cement returns aro seen at surface. Note that in the event that hydrates aro encountered, the Operations Drilling Engineer should be notified and a modified cement program will be submitted to ensure isolation of the hydrate zone. DISPLACEMENT OF CEMENT: Because Nabors 22E will be moving off of the well after the cement job, displacement fluid is an important consideration as the fluid will be left in the hole for some time. The proposed displacement procedure is as follows: 1. Pump away first stage as per the detailed cement program and displace with seawater a volume equal to the capacity of the 7" casing from TD up to surface. 2. After bumping the plug, quickly check to ensure that the floats aro holding and then shear the ES cementer to the open position. 3. Circulate seawater through the ES cementer for two hours to clean and condition the contaminated cement. 4. Pump the second stage as per the detailed cement program, circulating the water through the ES cementer and across the permafrost to surface. When cement returns are seen at surface, drop the second stage plug and displace with diesel. The completion rig will recover the diesel freeze protection fluid for rouse on another well. Anadrlll Schlumberger Anchorage, AK 995i8 (907) 349-451£ Fax 344-2£60 DIRHCTIONA~ ~;HLL PLA~ for SHARHD SERVICES DRILLZ~ ~ell ......... : MPG-IS(P4) Field ........ : Milne Point, G-Pad Com~utation..: Minimum Curvature Un£ts ........ : FEET Surface Lat..: 70.45027840 N Surface Long.: [49.53375038 ~ Legal Description Surface ...... : 2074 FSi 3455 FHb 827 T13N RlO~ UM TarDet ....... : 3399 FSi ~004 FSi S21 TZ3N R10H UM LOCATIONS - AhASKA Zone: 4 X-Coord Y-Coord 557147.69 60X4509.68 554255.~0 6021093.00 554[[4.~1 6021442.49 PROPOSHD WELL PROFII~ STATION £DHNTIFICATfON M~ASURED INCLN DIRECTION V~RTICAL-DHPTHS DHPTH ANGL~ AZIMUTH TVD SUB-SHA KB 0.00 0.00 0,00 0.00 -59.30 KOP/BUILD 1,5/100 300.00 0.00 0,00 300.00 240.70 B~£LD 2/100 350.00 0.75 310,00 350.00 290.70 400.00 1.75 310,00 399.99 340.69 CURVH 2,5/100 500.00 3.75 310.00 499.87 440.57 600.00 6.19 316.45 599.48 540.18 700.00 8.67 319.25 698.64 639.34 800.00 £1.15 320,80 797.14 737.84 900.00 [3.64 321.80 894.80 835-50 1000.00 16.~4 322,49 991.43 932.13 SECTION DEPART 0,00 0.00 0.29 1.25 5.46 L3.33 25.43 41.75 62.26 86.90 Prepared ..... : 09 Jun 1997 Vert 0ect az.: 338.57 KB elevation.: 59.30 ft Ma~p~etic Dcl~: ~28,045 (H) Scale Factor.: 0.99990391 Conver9 COORDrNATHS-FROM ANAD~ILI_ AKA-DPC APPROVED FOR, PERMI ING ONLY PLAN ALASKA Zone 4 0.00 0,00 0.21 0.gL 4.00 X Y 0.00 E 557147.69 6014509.68 O.00 E 557147.69 6014509.68 O.25 W 557L47.44 6014509.89 1-09 W 557146.&0 6014510.58 4.76 ~ 557L42.90 6014513.64 TOOL FACH 300 HS 0.00 501 0,00 501 1.50 505 2.00 44L 2,00 10.01 19.62 32.82 49.59 69.88 10.98 14 19.62 14 30.65 14 44.05 ~1 59.81 14 557136.63 6014539.60 557327.93 6014529.15 557116.80 6014542.27 557103.26 6014558.92 557087.35 6014579.09 10R 2.50 7R 2,50 5R 2.50 4R 2,50 4R 2-50 LL00.00 18.63 323.00 1086.86 1027.56 1200,00 21.~3 323,40 1180-89 1123.59 1L5.65 148-43 93.67 N 120.89 N 77.89 W 557069.~0 6014602.74 98.25 W 557048.53 6014629.81 3R 2.5Q 3R 2.50 Z (Anadrill (c) 97 MPG15P04 3.0C 30:39 AM P) ~ MPG - 15 (P4 ~ PROPOSED WHL/a PROP]LB 09 Jun 1997 Page STAT ION ]OENTI FICATION Z ~D 3,5/loo cuRw DROP 4/100 M~&SURED IECLN AIgGLR 1300.00 23.62 L400.O0 26.L2 LS00.00 28.62 L600.O0 3L.22 1700.00 33-62 1800.00 36.12 1867.79 37.81 1898.24 37.81 1927.79 37,81 2000.00 40.19 2100.00 43.51 2200.00 46.86 2300.00 50.22 2400.00 53.59 2500.00 56.97 2600.00 60.36 2700.00 63.76 2800.00 67.17 2900.00 70.58 3000.00 73.99 3100.00 77.41 3163.53 79.58 7937.26 79,58 8000.00 77.07 8100.00 73.07 8200-00 69.07 8300.00 65.07 8400.00 61.07 DIRHCTEON AZ I NK~H 323.7L 323.99 324.LB 324.37 324.53 VERTICKh-DEPTHS SSCT£ON COORDINATES-FROM q"JD SUB-SEA DEPART HRLI2iF_akD 1273,36 1214.06 185.20 151,52 N 120.86 1364.07 1304.77 225,88 105.48 ~ L45,67 1452.87 1393.57 270.39 222.$1 N 172.64 1539.58 1480.28 318.65 263.24 N 201.7] £624.04 1564.74 370,56 306.69 N 232.B4 324.66 [706.08 1646.78 324.75 1760.24 L700,94 324.75 1784.30 1725,00 324.75 1807,65 ~748.35 326.09 1863.76 L804.46 426,03 353.28 465,61 386,55 483.73 401.80 501.32 416.59 545.57 454,01 327.75 1938,24 1878.94 610.91 509.92 329.21 2008.71 1949.42 680.75 570.39 330,52 2074.92 2015.62 754.81 635.20 331.7l 2136.6£ 2077.31 832.83 704.12 332.80 2193.56 2134.26 914.51 776.85 333.81 2245.55 2186.25 999.56 853.15 N 334,75 2292.40 2233.10 108~.64 932.74 N 335.64 2333.91 2274.61 1178.44 L015.31 N 336.49 2369.95 2310,65 1272.62 1100,55 N 337.30 2400.37 2342,O7 £366,82 L288.L6 N 338-08 338.57 338.57 338.57 338.57 2425.07 2365,77 2437-74 2378.44 3301.04 3241.74 3313.73 3254.43 3339.49 3280.19 3371.92 3312-62 3410.87 3351.57 3456.15 3396.85 ALASKA Zone 4 ¥ 557025.69 6014660,25 557000.62 6014694.02 5~6973.37 6014731.04 556943.99 6014771.24 556912.53 60148L4.55 FAC~ 100 3R 2.50 2R 2.50 2R 2.50 2R 2.50 2R 2.50 338.57 338.57 338.57 265.95 W 556879.06 6014B60.88 2R 2.50 289.50 W 556855.26 6014893.96 HS 2.50 300.27 N 556844.37 60L4909.12 HS 0.00 310,73 W 556833.81 6014923.84 20R 0.00 336.51 W 556807.75 6014961.05 19R 3.50 372.89 ~ 556770.94 6015016.68 LBR 3.50 409.95 ~ 556733.42 6015076.86 LTR 3.50 447.54 W 556695,33 6015Z41.37 L6R 3.50 485.53 ~ 556656,82 6015209.97 L5R 3.50 523.78 ~ 556618.02 6015282,41 15R 3.50 562.13 W 556579.09 6015358.41 600.45 W 556540.16 6035437.~0 638.60 W 55650/.38 60155L9.96 676.44 W 556462.90 6015604.91 713.81 W 556424.86 6015692.22 14R 3.50 lqR 3.50 13R 3.50 L3R 3.50 L3R 3,50 1463,70 1525,95 6220.96 6282.40 63'/9.0;. 1277.79 N 750.59 H 556387,40 6015701.56 L2R 3.50 1337.64 N 773.58 H 556363.97 6015839.22 HS 3.50 5706.00 N 2489-13 W 554615.~2 6020195.88 LS 0.00 5763.20 N 2511.58 W 554592.24 6020252.89 LS 4.00 5853.32 N 2546.88 W 554556.25 6020342.54 LS 4-00 6473.58 6565.66 6654-80 594L.35 N 2581.43 W 554521.02 6020430.29 LS 4.00 6026.87 N 26LS.0B W 554486.73 60205i5.74 LS 4.00 6/09.84 N 2647.65 W 554453.52 6020598.45 I~S 4,00 (AnadriLl (c)97 MPGL5P04 3.0C 10:37 AM P) Z F- ITl m:,o- ts STATION MHASi/R~D INCLN IDENTIFICATION DEPTH ANGLE TOP UGNU 8402.37 60.98 8500.00 57.07 8600.00 53.07 8700.00 49.07 8800-00 45.07 TOP M SA/SD 8821.92 44,19 8900.00 41.07 ~ 4/100 DROP 8926.78 40.00 NA 9226.78 40.00 TARGET ~~~****~ 9326.78 40.00 TOP SCHRADER 9126.78 40.00 ~ 9369.86 40.00 NC/ND 9202.50 40.00 NE 9237.74 40.00 NF 9301.71 40.00 GA 9344.79 40.00 GA4 9387.87 40.00 OB 9436.17 40.00 BASE ~CHRADER 9472,72 40.00 7" CA~ING ~0£I~IT 9712.72 40.00 9712.72 40.00 PROPOSED WELL PROFILE DIRI{CTION I/HRTICAL-DEPTRS AZI[~GTH TVD SUB-SEA 338.57 3457,30 3390.00 338.57 3507,54 3448.24 338.57 3564,78 3505.48 338.57 3627.6k 3568.32 330.57 3695.70 3636.40 SECTION DBPART 6656.88 6740.57 6822.54 6900.31 6973.52 330,57 371L.30 3652.00 6988.92 338,57 3768.74 3709.44 7041.80 330.57 3789.09 3729.79 7059-20 338.57 3942.30 3883.00 7187.76 338.57 3942.30 3883.00 7187.76 338.57 3942.30 3883.00 7187.76 338.57 3975.30 3916.00 7215.45 338.57 4000.30 3941.00 7236.43 338.57 4027.30 3968.00 7259.08 338.57 4076.30 40~7.00 7300.20 338.57 4109,30 4050.00 7327,89 338.57 4142.30 4083.00 7355.58 3]8.57 4179.30 4120.00 7386.63 338.57 4207.30 4148.00 7410.£2 338.57 4391.~5 4331.85 7564.39 338.57 4391.15 433L.05 7564.39 09 Jun L997 Page 3 OOORDINATES-PROM AI~ASKA gore 4 TOOL DL/ WELLI{IIAD X Y PACE 100 6111,~ N 2648.41 W 554452.75 6020600.38 LS 4.00 6189.68 N 2678.99 ~ 554421.58 6020675.03 LS 4,00 6265.9~ N 2708.94 W 55439~.04 6020754.10 LS 4.00 6338.38 N 2737.36 ~ 554362.O7 6020826,27 LS 4.00 6406.52 N 2~64.11 W 554334.80 6020894.20 LS 4.00 6420.86 ~ 2769.74 ~ 554329.07 6020908.49 LS 4.00 6470.08 N 2789,06 W 554309.37 6020957.55 LS 4,00 6486.20 N 2795.42 W 554302.89 6020973.71 ~S 4.00 6605.95 N 2842.39 W 554255.00 6021093.00 HS 0.00 660~.95 N 2842.39 W 554255.00 6021093.00 IES 0-00 6605.95 N 2842-39 ~ 554255.00 6021093.00 ES 0.00 6631.72 N 2852.51 ~ 554244.69 602£Z38.69 ES 0.00 6651.25 N 2860.18 ~ 554236.87 602~138.16 ES 0.00 6672.34 N 2860.45 W 554220,43 6021159.LB HS 0.OO 6710.6~ N 2883.48 W 554213.~2 6021~97.34 BS 0.O0 6736-39 N 2893,60 W 554202.80 6021223.03 HS O.00 6762-16 N 2903.71 W 554192.49 6021248.73 HS O.00 6791-06 N 2915.06 W 554180.92 6021277.53 bis 0.00 68L2.93 N 2923.64 W 554172.17 6021299.34 ]iq 0.00 6956.54 N 2980.01 W 554114.71 6021442.49 0.00 6956.54 N 2980.01 W 554114.71 6021442.49 0.00 (Anadril[ (c) 97 [WPG15P04 3,0C 10:57 AM P) "A~ADRiLL AKA_DP'C:"{ APPROVED FOR PERMITTING ONLY PLAN SHARED SERVICES DRILLING Anadr] ]] Schlumberger ii i ~ I imlll I III I I MPG- ! 5 (P4) VERTICAL SECTION VIEVi ANADRILL AKA-DPC · i ~kPPRDVEI?, -ITVO Scale.'. ~ inch =~000 feet ~-' [ FOR PERJV~IT'I-ING IDep $ca~e.: 1inch :_ !070 leet __ ,-, Ot, I Ly,~ [ PLAN ,. ~PkBP IdenLification ~ 8KB SECTN ]HCLI , _~ ~"~ B) KOP/BUILD __ , C) BUILD 2/100 350 350 0 8.7' D) CURVE 2,5/~00 500 500 5 3.7 ..... E) END 2.5/100 CURVE ~868 ~7~ 466 37.B ...................................... ~ ~r'~ F) CURVE 3.5/t00 1928 ]BOB 501 37.8 ,, G) END 3.5/~00 CURVE 3~64 2438 1526 79,5 H) D~P 4/~00 7937 3301 6221 79.5 I) E~ 4/~00 D~P 8927 3789 7059 40.0 J) T~GE1 ~..~~x 9127 3942 7~88 40.0 ~~ K) 7' CAS]~ POINT 9713 4391 7564 40.0 ~~~~~ L) TD 97t3 439~ 7564 40.0 -~-~ - ~, - -~- 'TB~ -33~i ...... ~5 ~ ~~ ..... ~ :: -- '' 'K , O 500 tO00 1500 2000 2500 3000 3500 4000 4500 5000 550(] 6000 6500 7000 7500 84)00 8500 Section Departure (Anad['it] [cJ9? NPG"JSF]04 3.0C lO:4;] AH I~ feet J z 06/09/1997 11:17 907-344-21G0 AN~DRILL DPC PAGE 18 /-. SHARED SERVTCES BRILLTN6,'," I -- lll~ ...... MPC- .5 (P4) VERTICAL SECTION VIEW 3650 ....... Section at: 338.57 TVD Scale.' i inch : ~00 feet · Oep Scale.- ~ inch = 100 feet 3700 ; ---ta~-~s~ ~nIDrawn 09 Jun ~997 3750 ~ .... ~ ,4nadnl]] Sch]umDerger 3800 A N ,, Marker Identification MD BKB SECTN INCLN ~1 END 4/100 DROP 8927 3789 7059 40.00 8) TARGET ~w~~w 9127 3942 7~.88 40.00 C) 7' CASING POINT 97t3 4391 7564 40.00 3850- ~ D) TO 9713 439~ 7564 ~0.00 3900 X ' ' .,, Tar, g.,t,_~ad.i,J.S_lliO_fEet ) .~LNIArH~I I AI,'A ~'N-'"' APr ROVED '~-~ ................... 4000 Nc/u) ,~o~ ........................ ~ C)NL¥ ~o~o .... PI.AN y~""- ., ~ . ~.L .......... -~ ,...~,~,,,.~,_~ ,. -~ - ~/~ ..................... 4~00 - , 4~5o_~- -~r~'................ ,"' .~ ~ ....................... .. _ 4200 · · 'cPA' ~,.~- '~L~7' %-- .................. 4250- _.~_N - 4300 I . ._ ~ . I \ 4350-- - · - ,~400 ........ 4450 .... - ............ ' 4500 .... 7000 7050 7100 7J. 50 7200 7250 7300 7350 7400 7450 7500 7550 7600 7650 7700 .Sect !o,.p Departure ., (~nadrill [c)97 [vJ3Gl,~P04 3.0C 4.0:44 AN P) 06/09/1997 11'17 907-344-2160 ~NADRILL DPC ~uh l~ SHARED ,,SERV I CE ' "DR-i LL I NS .... I ii i i ~) K8 0 o N 0 E CURVE 2.5/100 500 4 N 5 W E) END 2,5/100 CURVE ~86B ~87 N 29o w CLOSURE · 756B feet at Azimuth 33~.8~ F) CURVE 3.5/~00 ~928 4~7 N 3~ W G) END 3.5/~00 CURVE 3~64 133~ N 774 ~ DECLINATION.' +28.045 (E) H) DRDP 4/~00 7937 5706 N ~489 W SCALE ' ~ ~nC~ = ~200 feet I) E~ 4/tO0 DROP 8927 64B6 N ~79~ W d) TARGET ~)~~ gI27 6608 N 2842 W DRAWN ' 09 dun ~997 K) 7" 6~SING PO)NT 97~3 6957 N 8980 W L) TD 9713 6957 N ~980 W m ~nadr~ ]] Schlumberger - -7800 i A~fABRIL~ A~,-bP~ ...... - 7200 ~ APP~',OVE D ,~FO~PE~,MIT'rtN(;~~ ..~u~ ~)o ~ --~oo ~,._ _ PLaiN ~~ ~ ...... - ~ooo ..... ~ ...... .... ~00 , 5~o0 '" 3000 ...... m" 2400 ~800 ........ ~2Do - .... ~oo 7800 7~00 ~$00 [000 5aO0 ~80~ a~O0 3800 3000 ~00 ....... m m m m mmm lmm m (~naarill (C)97 ~6ISPOd 3,0C tO: 44 ~M P) WELL PERMIT CHECKLISToo Y WELL NAME~ GEOL Ai{EA PROGRAM: expD dev~redrlO servD wellbore seg~ ann disp para req~ ADMINISTRATION 1. Permit fee attached ................... Y. 2. Lease number appropriate ............... Y 3. Unique well name and number .............. 4. Well located in a defined pool .............. 5. Well located proper distance from drlg unit boundary. . 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... 8. If deviated, is wellbore plat included ........ 9. Operator only affected party ............. . 10. Operator has appropriate bond in force ........ ' 11. Permit can be issued without conservation order .... 12. Permit can be issued without administrative approval. 13. Can permit be approved before 15-day wait ....... ENGINEERING APPR DA~E 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ O N 16. CMT vol adequate to circulate on conductor & surf csg..~ N ~~_~ 17. CMT vol adequate to tie-in long string to surf csg . . N 18. CMT will cover all known productive horizons ...... N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............ .~-) N 21. If a re-drill, has a 10-403 for abndnmnt been approved.--X-----~~ 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N ~~ 24. Drilling fluid program schematic & equip list adequate .~ N 25. BOPEs adequate .................... .~ N 26. BOPE press rating adequate; test to ~ psig~_~ N 27. Choke manifold complies w/API RP-53 (May 84) ...... ~ N 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of ~2s g~s probable ............. Y ~ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis of shallow gas zones ......... 33. Seabed condition survey (if off-shore) ....... / Y N 34. Contact name/phone for weekly progress reports . ./. . Y N [explorator~ only] REMARKS GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/dlf- A:\FORMS\chekiist rev 01/97 Well HistorY File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Fri Sep 12 15:03:00 1997 Reel Header Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKI~OWN Comments ................. STS LIS Writing Library. Technical Services Scientific Tape Header Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... %TNKIflOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Physical EOF Comment Record TAPE HEADER MILNE POINT UNIT MWD/MAD LOGS # WELL NAME: API AK/M~ER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN 2 AK-MM-70216 ZIEMKE ANGLEN ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: Date_ OI - 0 3 - 01 MPG-15 500292278400 BP EXPLORATION (ALASKA), INC. SPERRY-SUN DRILLING SERVICES 12-SEP-97 27 13N 10E 2074 3455 Rd. CE VED SEP 1 7 '1997 Alaska Oil & Gas .~ons. Commis~o.~ Anchorage .00 58.80 29.80 K~LL CASING RECORD !ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 20.000 112.0 8.500 9845.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 IS DIRECTIONAL ONLY AND IS NOT PRESENTED. 3. MWD RUN 2 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) . 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND MARK VANDERGON OF BP EXPLORATION (ALASKA), INC. ON 08 SEPTEMBER 1997 . 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9845'MD, 4508 'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP S PACING ). SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ File Header Service name ............. STSLIB. 001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record.. 65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH FET 7339.5 RPD 7339.5 RPM 7339.5 RPS 7339.5 RPX 7339.5 GR 7348.5 ROP 7398.5 STOP DEPTH 9787 0 9787 0 9787 0 9787 0 9787 0 9794 0 9845 0 $ BASELIIFE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 7398.0 9845.0 $ REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD AAPI 4 1 68 RPX MWD OH~ 4 1 68 RPS MWD OHM~ 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHP~ 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 7339.5 9845 8592.25 5012 ROP 5.4366 798.244 189.507 4894 GR 17.7301 114.439 60.9373 4892 RPX 1.5162 107.741 9.35584 4896 RPS 1.5716 80.0106 9.46171 4896 RPM 1.501 78.1915 9.33588 4896 RPD 1.5562 79.037 9.79711 4896 FET 0.1582 19.2491 1.07528 4896 First Reading 7339 5 7398 5 7348 5 7339 5 7339 5 7339 5 7339 5 7339 5 Last Reading 9845 9845 9794 9787 9787 9787 9787 9787 First Reading For Entire File .......... 7339.5 Last Reading For Entire File ........... 9845 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File T!zpe ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN ~ER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FET 7339.5 9787.0 RPD 7339.5 9787.0 RPM 7339.5 9787.0 RPS 7339.5 9787.0 RPX 7339.5 9787.0 GR 7348.5 9794.0 ROP 7398.5 9845.0 $ LOG HEADER DATA DATE LOGGED: 25-JUL-97 SOFTWARE SURFACE SOFTWARE VERSION: 5.06 DOWN-HOLE SOFTWARE VERSION: 5.46 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9845.0 TOP LOG INTERVAL (FT) : 7398.0 BOTTOM LOG INTERVAL (FT): 9845.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 37.1 MAXIMI/M ANGLE: 79.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY P0768CRG6 P0768CRG6 EWR4 ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 8.5 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT) : MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EKq{ FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 SPUD 9.20 78.0 9.0 1000 4.2 2.900 2.361 2.175 4.350 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD 2 AAPI 4 1 68 RPX MWD 2 OHMM 4 1 68 RPS MWD 2 OHMM 4 1 68 RPM MWD 2 OHMM 4 1 68 RPD MWD 2 OHIO4 4 1 68 ROP MWD 2 FT/H 4 1 68 FET MWD 2 HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32.2 Name Min Max Mean DEPT 7339.5 9845 8592.25 GR 17.7301 114.439 60.9373 RPX 1.5162 107.741 9.35584 RPS 1.5716 80.0106 9.46171 RPM 1.501 78.1915 9.33588 RPD 1.5562 79.037 9.79711 ROP 5.4366 1887.89 190.181 FET 0.1582 19.2491 1.07528 Nsam 5012 4892 4896 4896 4896 4896 4894 4896 First Reading 7339.5 7348.5 7339.5 7339.5 7339..5 7339.5 7398.5 7339.5 Last Reading 9845 9794 9787 9787 9787 9787 9845 9787 First Reading For Entire File .......... 7339.5 Last Reading For Entire File ........... 9845 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/09/12 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/09/12 Origin ................... STS Reel Name ................ UANfNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File