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Home My WebLink About205-072 · . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q5 - Q 7 ~ Well History File Identifier o Two-sided 11111111111111 1111/ Organizing (done) o Rescan Needed 1/1/11/1111/1111111 RESCAN ~olor Items: o Greyscale Items: DIGITAL DATA \Ø6¡Skettes, No. a.. o Other, No/Type: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: o Other: OVERSIZED (Non-Scannable) o Logs of various kinds: NOTES: vnf IIIIIIIIIIII~ 11111 f Date 7 j :)'3} D7 I'; VYl ~ x 30 = (ðt'J + L~ = TOTAL PAGES 7 7 Daleo / a 3/ D (Count does nol '~~ude cove' sheel) mf 1 7 1111111111I11 ""I Date7/d3jD7 o Other:: BY: ~ 151 Project Proofing BY: C MariV Scanning Preparation BY: ~ Production Scanning Stage 1 Page Count from Scanned File: r¡<6 (Count does include cover sheet) ~ES Stage 1 Page Count Matches Number in Scanning Preparation: ~ Date: 7/~/07 If NO in stage 1 page(s) discrepancies were found: YES NO 151 vvt P NO BY: BY: Maria Date: 151 11111111I1111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1//11111111I11 ,,11/ BY: Maria Date: 151 Comments about this file: Quality Checked 11111111/111111111/ 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA T E OF ALA III OIL AND GAS CONSERVATION COMMISSION SEP 2 8 2012 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Performed: ✓ I °Y))1:1 ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Enter Suspended Well 1/1/, ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver iff Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension l) Lilj E5Pj I() SSA li ,i et j1 141" P 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory - 205 - 072 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 - 029 - 23263 - - 7. Property Designation (Lease Number): 8. Well Name and Number: ADL047438 A55- 13 1011 MPE - 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 9042' feet Plugs (measured) None feet true vertical 4368' feet Junk (measured) None feet Effective depth: measured 9042' feet Packer: (measured) 6162', 6576' feet true vertical 4368' feet Packer: (true vertical) 4265', 4398' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 113' 113' 1490 470 Surface 3275' 10 -3/4" 3310' 2669' 5210 2480 Intermediate Production 6469' 7 -5/8" 6502' 4384' 6890 4790 Liner 2676' 4 -1/2" 6366' - 9042' 4342' - 4368' 8430 7500 Perforation Depth: Measured Depth: Screens 6649' - 8997' True Vertical Depth: Screens 4404' - 4368' Tubing (size, grade, measured and true vertical depth): 4 -1/2 ", 12.6# 13Cr85 6365' 4342' Packers and SSSV (type, measured and true vertical depth): 7 -5/8" x 4-1/2" HES TNT Packer 6162' 4265' Pay Zone "ESP" Packer 6576' 4398' 12. Stimulation or cement squeeze summary: Intervals treated (measured): 4 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: 454 43 98 220 182 Subsequent to operation: 437 48 108 1557 178 14. Attachments: ❑Copies of Logs and Surveys run 15. Well Class after work: ❑ Exploratory ® Development ❑ Service ❑ Stratigraphic ® Daily Report of Well Operations Well Schematic Diagram 16. Well Status after work: — ® Oil ❑ Gas ❑ WDSPL ❑ 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 David Bjork, 564 -5683 N/A Printed m Joe ; ast la I Title Drilling Technologist Prepared By Name /Number Signature I it Phone 564 4091 Date �� Joe Lastufka, 564 -4091 Form 10-404 Re ' d 11/2011 '' EMS SEP 2 8 X012 4 Submit Original Only GP • Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/11/2012 12:00 - 16:00 4.00 MOB P PRE PJSM FOR RIG MOVE, PREPARED AND MOBILIZED RIG F/ MPE -11 TO MPE -31 - MOVE CUTTING TANK AWAY FROM RIG - INSPECTED FLOW BACK TANK - MOVE RIG OFF MPE -11 - MOVE RIG ON MATS FROM MPE -11 TO MPE -31 16:00 - 19:00 3.00 MOB P PRE MOVED RIG MATS F/ MPE -11 TO MPE -31 - STAGED RIG TO PULL OVER WELL STAGED CIRCULATING EQUIPMENT AROUND WELLHEAD 19:00 - 21:30 2.50 MOB P PRE SPOT AND SHIM RIG OVER MPE -31 - BACKED RIG OVER WELL AND NOTIFIED PAD OPERATOR - LOWERED STAIRS - PREP PITS FOR FLUID - CHANGED WELL SIGN - RIG ACCEPTED AT 21:30 HOURS ON 08/11/2012 21:30 - 23:30 2.00 RIGU P PRE PJSM, R/U OVER MPE -31 - R/U CELLAR MANIFOLD AND CIRCULATING LINES - SPOT CUTTINGS TANK AND CREW CHANGE TRAILER - SPOT FLOWBACK TANK AND R/U LINES - HUNG STABBING BOARD 23:30 - 00:00 0.50 RIGU P PRE PERFORM RIG EVACUATION DRILL W/ BOTH RIG CREWS - ALL PERSONAL NOTIFIED, INCLUDING TRUCK DRIVERS AND THIRD PARTY CREW - EVACUATED TO WELL SITE LEADER OFFICE - AAR PERFORMED - DISCUSSED EGRESS ROUTES, ALL SITE PERSONNEL WERE MONITORING HUB AND REPORTED TO MUSTER AREA 8/12/2012 00:00 - 06:00 6.00 KILLW P DECOMP PJSM, RIG UP AND PREPARE TO KILL WELL - LOAD PITS WITH 9.2, 115 DEGREE BRINE - TEST HARD LINE TO FLOW BACK TANK, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - TEST ALL CELLAR LINES AND KILL MANIFOLD, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - R/U AND FUNCTION TEST SSV REMOTE PANEL - R/U AND TEST WELL SUPPORT LUBRICATOR , 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - PREPARE TO PULL BPV AT 6:00 06:00 - 06:30 0.50 KILLW P DECOMP PJSM. PULL BPV, SITP = 350 PSI, SICP = 550 PSI, 0/A = 200 PSI. - LAY DOWN LUBRICATOR. Printed 9/25/2012 8:29:28AM a•° Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:30 - 08:00 1.50 KILLW P DECOMP PRE KILL MEETING WITH ALL PARTIES INVOLVED. - BP SUPERINTENDENT PRESENT. - SIM -OPS ON MPE -02, MET WITH THEM AND DISCUSSED OPERATIONS. - ALL OUTSIDE ACTIVITIES CONFINED TO DRILLER SIDE OF THE RIG. DISCUSSED IMPORTANCE OF VALVE ALIGNMENT AND GOOD COMMUNICATION TECHNIQUES. - JOB ASSIGNMENTS AND SHUT IN PROCEDURES IF NECESSARY. 08:00 - 11:00 3.00 KILLW P DECOMP BLEED GAS OFF OF VA TO TIGER TANK (10 MIN TO FLUID RETURNS). - EQUALIZE PRESSURE WITH MUD PUMP & OPEN UP TO TUBING. - PUMP DOWN TUBING TAKING RETURNS UP GA THRU H KE T TI R TANK. PUMPING HEATS 5.2 PPG BRINE. (45 BBCS). ICI= 2 'S1 @ 3 BPM, F'CP= 700 PSI @ 3 BPM. MAINTAINING 600 PSI BACK PRESSURE ON I/A. - CLOSE CHOKE AND BULLHEAD (50) BBLS @ 4 BPM, ICP = 800 PSI. - FCP = 900 PSI @ 4 BPM. SHUT DOWN. SITP = 200 PSI, SICP = 550 PSI. - BRING ON PUMP @ 4 BPM HOLDING 600 PSI BACK PRESSURE ON CHOKE. - PUMPING 4 BPM @ 800 - 900 PSI, PUMP 125 BBLS AND SHUT DOWN, SHUT IN. - EMPTY TIGER TANK (82) BBLS. FILL PITS. MONITOR WELL, TBG ON VACUUM. LOST 91 BBLS TO THIS POINT. 11:00 - 14:30 3.50 KILLW P DECOMP OPEN BACK UP AND CONTINUE TO _ IJ2CULATE 9.2 PPG BRINE. - PUMPING DOWN TBG, TAKING RETURNS UP I/ A THRU CHOKE. - HOLDING ENOUGH BACK PRESSURE TO MAINTAIN 4 BPM @ 800 - 900 PSI. - 620 BBLS SINCE BULLHEAD PUMPED BEFORE GOOD 9.2 PPG RETURNS. - STRAP AND EMPTY TIGER TANK. 214 MORE BBLS RECOVERED. - TOTAL LOST TO WELL DURING WELL KILL = 372 BBLS 14:30 - 15:30 1.00 KILLW P DECOMP MONITOR WELL, SITP AND SICP HOLDING @ 20 PSI. - FLUID RETURNS ON VA A BIT OILY. 15:30 - 16:00 0.50 KILLW P DECOMP LINE UP AND CIRCULATE ANOTHER (50) BBLS DOWN THE TUBING. - TAKING RETURNS UP THE VA THRU THE CHOKE, 4 BPM @ 800 PSI. 16:00 - 17:00 1.00 KILLW P DECOMP BLEED OFF ALL PRESSURE, MONITOR WELL. - TUBING AND VA ON A VACUUM. - 0/A PRESSURE MONITORED THROUGHOUT, INITIAL 0/A PRESSURE @ 200 PSI, FINAL 0/A PRESSURE @ 400 PSI. Printed 9/25/2012 8:29:28AM e Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 18:00 1.00 KILLW P DECOMP RIG DOWN CHOKE MANIFOLD AND LINES - BLOW DOWN LINES - CLEAR CELLAR - 17:00 HRS, BOB NOBLE OF AOGCC WAIVER STATES RIGHT TO WITNESS BOPE TEST. (24) HR NOTICE GIVEN. 18:00 - 19:00 1.00 BOPSUR P DECOMP "'R/U BOPE TEST EQUIPMENT - R/U FLOOR SAFETY VALVES FOR TESTING R/U 2 7/8" AND 4 1/2" TEST JOINTS 19:00 - 21:00 2.00 WHSUR P DECOMP PJSM, R/U WELL SUPPORT LUBRICATOR - TEST LUBRICATOR, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED : INSTALL TWC - PERFORM ROLLING TES T FROM BELOW, 3 1314/1= 200 PSI, 10 MIN, 36 BBLS PUMPED - TEST TWC FROM ABOVE, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - R/D LUBRICATOR AND RELATED TEST EQUIPMENT 21:00 - 23:30 2.50 WHSUR P DECOMP PJSM, N/D TREE - DRAIN FLUID, N/D TREE AND ADAPTER FLANGE - FMC REP CHECKED HANGER THREADS AND LOCK DOWN FOR FREEDOM OF MOVEMENT - MADE DUMMY RUN WITH 2 7/8 XO INTO HANGER = 9.5 RH TURNS 23:30 - 00:00 0.50 BOPSUR P DECOMP PJSM, INSTALL BOP - SET BOP ON WELL HEAD - OA = 200 PSI - TOTAL 24 HOUR FLUID LOSS = 410 BBLS - MAINTAIN CONTINOUS FILL TO IA. - LOSING 15 - 20 BPH TO WELL. 8/13/2012 00:00 - 02:30 2.50 BOPSUR P DECOMP PJSM, CHANGE OUT CREW - PERFORM SPCC AND EQUIPMENT CHECKS - N/U BOPE - INSTALL TEST JOINT IN BOP - FILL LINES AND STACK WITH FRESH WATER, PURGE AIR 02:30 - 08:00 5.50 BOPSUR P DECOMP PJSM, TEST BOP'S PER AOGCC REGULATIONS AND DOYON TEST PROCEDURE - TEST ALL BOPE AND CHOKE MANIFOLD VALVES TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES, CHARTED - TEST ANNULAR USING 2 7/8" TEST JOINT - TEST 2 7/8" X 5" VBR PIPE RAMS USING 2 7/8" AND 4 1/2" TEST JOINTS - TEST BOTH SETS OF 2 7/8" AND 4" FLOOR VALVES - TEST USING FRESH WATER - PERFORM DRAW DOWN TEST ON ACCUMULATOR. - CONTINUOUS HOLE FILL DURING THIS OPERATION. - DID NOT GET PASSING TEST ON THE MPLS ON THE LOWER PIPE RAMS W/ A 2 7/8" TEST JT. 4" TEST JT PASSED. - BOB NOBLE OF AOGCC WAIVED STATES RLGHT TO WITNESS BOPE TEST Printed 9/25/2012 8:29:28AM • M Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 09:00 1.00 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT. DECOMP - BLOW DOWN ALL LINES. 09:00 12:00 3.00 BOPSUR P PJSM. SUCK OUT STACK, PICK UP OPSO - LOPSO. CHECK THREADS ON PORTED 2 7/8" EUE 8 ROUND X 4 1/2" IBTC X/O. - CHANGE OUT 4 1/2" PUP. THREADS GALDED. 12:00 - 15:30 3.50 BOPSUR P DECOMP PJSM. PICK UP /RIG UP OPSO - LOPSO. - CLOSE ANNULAR AND PRESSURE TEST @ 250 / 3500 PSI, 5 MIN / CHARTED. - PULL TWO WAY CHECK VALVE, 2ND ATTEMPT. UD TOOLS. 15:30 16:30 1.00 BOPSUR P DECOMP PJSM. RIG UP CENTRILIFT TOOLS. - MAKE UP LANDING JT W/ FLOOR VALVE AND TBG HANGER. 16:30 - 17:00 0.50 WHSUR P SURE RECEIVED ORDERS TO SUSPEND OPERATIONS R/D LANDING JT AND FLOOR VALVE 17:00 - 18:30 1.50 WHSUR P SURE INSTALL TWC - PERFORM ROLLING TEST FROM BELOW, 3 BPM = 250 PSI, 10 MIN, 42 BBLS PUMPED, CHARTED - TEST TWC FROM ABOVE, 250 PSI LOW, 3500 I, CHARTED 18:30 - 19:30 SURE 1.00 BOPSUR P PJSM HGH , N/D , 5 BOP MIN - R/D TONGS AND CASING EQUIPMENT - BLOW DOWN ALL SURFACE LINES 19:30 00:00 4.50 BOPSUR P SURE NIPPLE DOWN BOP AND RISER - REMOVE ALL RAMS FROM BOP - BREAK HYDRIL CAP CONNECTION 1/4 TURN - REMOVE CHOKE AND KILL HCR HOSES AND ALL KOOMY LINES FROM BOP - R/D AND MOVE REMOALL 4 V D E CEN ILL SPOOLING NIT - RE" R PIPE TRILIFT FROM PIPE SHED REMOVE ALL DEBRIS AND METAL FROM RIG ROOF - LOSSES TO WELL LAST (24) HOURS = 257 BBLS. 8/14/2012 00:00 01:30 1.50 BOPSUR P SURE CONTINUE NIPPLE DOWN BOP AND RISER - REMOVE ALL RAMS FROM BOP 01:30 - 03:30 2.00 WHSUR P SURE PJSM, PERFORM SPCC AND EQUIPMENT CHECKS ADAPTER FLANGE AND TREE 03:30 05:30 2.00 WHSUR P SURE TEST N/U ADAPTER FLANGE AND TREE - TEST ADAPTER FLANGE VOID BY FMC REP TO 5000 PSI, 30 MINUTES - TEST TREE TO 250 PSI LOW, 5000 PSI HIGH, 5 MIN EACH, CHARTED 05:30 - 08:00 2.50 WHSUR P SURE PJSM, R/U WELL SUPPORT LUBRICATOR - TEST, 250 PSI LOW / 3500 PSI HIGH, 5 MIN, CHARTED - PULL TWC - C/O RUNNING TOOL - TEST LUBRICATOR, 250 PSI LOW / 3500 PSI HIGH, 5 MIN, CHARTED - SET BPV Printed 9/25/2012 8:29:28AM e 4 a r . 1 Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 08:30 0.50 WHSUR P SURE TEST BPV - PERFORM ROLLING TEST FROM BELOW, 5 BPM = 350 PSI, 10 MIN, CHARTED 08:30 - 10:30 2.00 WHSUR P SURE RIG DOWN CELLAR - SECURE TREE, CLOSE ALL VALVES - BLOW DOWN ALL CELLAR LINES - FLUSH ALL LINES AND PUMPS WITH HOT FRESH WATER - CLEAN AND EMPTY PITS 10:30 - 12:00 1.50 WHSUR P SURE PJSM, CUT DRILING LINE - SLIP AND CUT 61' OF DRILLING LINE 12:00 - 18:00 6.00 WHSUR P SURE PJSM, CHANGE OUT CREWS, PERFORM SPCC AND EQUIPMENT CHECKS - CLEAN AND CLEAR FIG FLOOR - CLEAN UNDER DRAW WORKS AND DRIP PANS - REMOVE ALL SLIPS, ELEVATORS, TONGS, SUBS, ETC FROM RIG FLOOR - BRIDLE UP BLOCKS FOR DERRICK LAY -OVER - PREP RIG FOR MOVE OFF WELL - LOSSES TO WELL LAST (18) HOURS = 131 BBLS. - RELEASE RIG AT 18:00 HOURS 8/28/2012 00:00 - 02:30 2.50 RIGD P PRE CREW CHANGE, PJSM. - FINISH REMOVING BOP STACK FROM CELLAR. - PJSM, REVIEW DDI SOP FOR (JD DERRICK. - PREP AND L/D DERRICK. 02:30 - 09:00 6.50 MOB P PRE PJSM, PREP AND INSTALL REAR BOOSTER. - VAC UP RAIN WATER FROM SPILL CONTAINMENT. - SUCK OUT TEST WATER FROM PITS. - INSTALL FRONT BOOSTER BRACE. INSTALL FRONT BOOSTER. - PREP RIG FOR MOVE. 09:00 - 09:30 0.50 MOB P PRE PJSM, JACK RIG UP. - MOVE TO POSITION RIG AT MPA PAD AND MPU SPINE INTERSECTION. - RIG BREAKING THROUGH ON MPA -PAD. 09:30 - 12:00 2.50 MOB N WAIT PRE PJSM WITH RIG MOVE COORDINATOR AND CREW. - MOBILIZE MATS FROM MPU SPINE. 12:00 - 17:30 5.50 MOB N WAIT PRE CREW CHANGE. PJSM FOR RIG MOVE. - CONTINUE TO MOBILIZE MATS FROM MPU SPINE RD. - AND LAY MATS ON MPA -PAD TO SPINE INTERSECTION. - POSITION RIG ON MATS AT MPU SPINE RD AND A -PAD INTERSECTION. 17:30 - 20:30 3.00 MOB N WAIT PRE LOAD AND MOBILIZE MATS FROM BEHIND RIG. - LAY MATS ON MPU SPINE RD IN FRONT OF RIG. - MPU CREW CHANGE. 20:30 - 21:15 0.75 MOB P PRE MOVE RIG FROM MPA -PAD INTERSECTION TO TRACK 14 RD. Printed 9/25/2012 8:29:28AM a•° • Common Well Name: MPE -31 d AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 En Date: X4- OOVQX- E. (2,150,000.00 ) Project: Milne Point Site: M Pt E Pa Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mea E n Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:15 00:00 2.75 MOB P PRE STAGE RIG ON PULL OUT. LET TRAFFIC BY, INCLUDING TRUCKS WITH MATS LOADED. 8/29/2012 00:00 00:30 0.50 MOB P PRE CREW CHANGE. PJSM FOR RIG MOV WITH E. REVIEW LEVEL 2 RISK ASSESMENT ONCOMING C - DISCUSS RIG MAT LAITH MPU CREW' YOUT W CREW CHANG. REVIEW Dm SOP FO RIG MOVE. KS. CTION MAKE EQUIPMENT CHEC 00:30 02:00 1.50 MOB P PRE - MOVE RIG FROM TRACK 14 INTERS-ION. TO MPU SPINE /MPE -PAD INTERSECTION. TRAVELING ON R IG MATS. 02:00 08:00 6.00 MOB P PRE WAIT ON MATS TO BE SE FROM INTERSECTION ONTO MPE -PAD. - RIG REMAINS POISED AT THE INTERSECTION. COMPLIANC E WITH H ALL THE AGREED ON POINTS OF THE LEV RISK ASSESSMENT. A LL CREW CHANGES DONE IN A SAFE AND EFFICIENT MANNER WITH REGARD TO MILNE POINT AND SEISMIC CREWS. 08:00 11:30 3.50 -- MOB P PRE MOVE RIG ON TO M PAD. Y TIRES. PE - STAGE RIG, RERICK. MOVE AUXILLIAR - PJSM. RAISE DER 11:30 16:00 4.50 MOB P PRE CONTINU M MPE -31. RUCKS BE M OVING RIG MATS ROUND A LOCATION TO - NOTE: VED CH2MHILL BED TING REPAIRED. ALL RIG MATS MO W A ITH LOA 16:00 17:30 1.50 WITNESS. MOB P PRE PJSM. GN RIG VALVES S CLOSED. - - MOVE RIG WELL. R PRESENT T TO BACK AND SPOT RIG OVER WELL. LEVEL AND SHIM RIG. 17:30 19:30 2.00 RIGU P PRE PJSM. R/U KILL TANK. MANIFOLD AND LINES. SPOT CUTTINGS - LOAD PITS WITH 9.3 PPG BRINE KWF 100 DEG. - VERIFY BRINE WEIGHT AND TEMP 4250 PSBEFORE OFFLOADING. - VERIFY # 1 MP POP VALVE SET AT I. NOTIFY AOGCC BOB NOBLE FOR 24 HR BOP TEST NOTIFICATION AT 18:00 HRS - NEEDS UPDATE IN THE MORNING. RIG ACCEPTED ON MPE -31 AT 19:30 HRS. - 0/A- TIGER PSI. I /A= 100 PSI. 19:30 00:00 4.50 RIGU P PRE SPOT TIGER TANLINE. K. - DSM R/U HARD CONTINUE TO LOAD PITS WITH 9.3 PPG 100 DEG BRIN R/U REMOTE ACTUO OPERATE E KWF. ATOR T SSV FROM R IG FLOOR. - VERIF ACTUATOR OPER TEST HIGH LEVEL ALARM IN TIGER TANK. Printed 9/25/2012 8:29:28AM • Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- OOVQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/30/2012 00:00 - 00:30 0.50 RIGU P PRE CREW CHANGE. i s CONDUVA DUE TO ASSEMBLED AT MUSTER MOKE ONN CT RIG. RIG CREW AND THIRD E PARTY WORKERS AREA CUATION , DRILL TOOL PUSHER STAYED ON RIG. ALL HANDS ACCOUNTED FOR. LOADER CLOSED OFF PAD ENTRANCE. WSL AND TOOL PUR SIMULATE EMERGENCY CALLS. AAR. SHE Ti RR NEW WARNING LIGHT IN MOTOR ROOM OD USED TO SWEEP THE RIG. - REVIEW HANDLING SMALL FIRE DURING THE RIG AND EVACU . 00:30 - 02:30 2.00 KILLW P DECOMP PJSM. TEST KILL MANIFORD AND LINES PER DDI SOP. - TEST KILL MANIFOLD AND LINES TO 250 PSI AND 3500 PSI 5 MIN EACH. - S HO OWBACK ANK TO 250 TE PSI AND ARD 3500 LINE PSI 5 FL MIN EACH. T - CHART T RECORD ALL T TESTS. 02:30 - 03:15 0.75 KILLW P DECOMP PJSM WITH . BPV. - REVIEW DDI SOP DSM AND FOR RIG PULLIN - R/U LUBRICATOR. - PRESSURE TEST LUBRICATOR TO 250/3500 PSI. 5 MIN EA. - CHART RECORD TEST. 03:15 - 03:30 0.25 KILLW : P DECOMP PULL BPV. - TBG= 68 PSI. 1 /A= 85 PSI. O /A= 225 PSI. SHUT IN TREE VALVES. R/D LUBRICATOR. 03:30 04:00 0.50 KILLW P DECOMP NOTIFY WTL WITH SHUT IN PRESSURES. - DECISION WAS MADE TO PERFORM DAYLIGHT WELL KILL. - NOTIFY RWO FIELD SUPERINTENDANT. 04:00 07:00 3.00 KILLW P WAIT DAYLIGHT WELL KILL. 07:00 - 07:30 0.50 KILLW P LOAD 4" DRILL PIPE INTO PIPESHED. DECOMP DECOMP PRE JOB ON MEETING WITH REGARD TO WELL CIRC OUT. - DISCUSSED VALVE ALIGNMENT AND MAXIMUM PRESSURES. - EMPHASIZED COMMUNICATION NIQUES AND HOW TO SHUT THE WELL IN. SUPERINTENDANT GOOD PRESENT. - BARRIERS OUT, MILNE PT AND PAD OPERATOR NOTIFIED. PRESSURE RELIEF VALVE ON MUD PUMP SET @ 4250 PSI. Printed 9/25/2012 8:29:28AM • Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 09:30 2.00 KILLW P DECOMP OPEN VA THROUGH CHOKE TO TIGER TANK. - OBSERVE FLUID TO TIGER TANK, NO GAS. - LINE UP TO PUMP DOWN TUBING, TAKING RETURNS UP VA THRU CHOKE AND OUT TO TIGER TANK. - BRING PUMP GRADUALLY UP TO 4 BPM / 1200 PSI ICP. CHOKE WIDE OPEN. PUMP 300 BBLS, SEE PUMP PRESSURE STABILIZE @ 650 PSI @ 4 BPM. - SHUT DOWN PUMP, SHUT IN AND STRAP TIGER TANK. - RECOVERED 195 BBLS FROM TIGER TANK, LOST 105 BBLS TO WELL. 09:30 - 11:00 1.50 KILLW P DECOMP RESUME PUMPING DOWN TUBING, TAKING RETURNS UP VA, THRU CHOKE AND TO TIGER TANK. - PUMPING 4 BPM / 650 PSI, CHOKE FULLY OPEN. - PUMP 125 BBLS, CHECK RETURNS, 9.24 PPG BRINE COMING BACK. - SHUT DOWN, SHUT IN WELL. 11:00 - 12:00 1.00 KILLW P DECOMP MONITOR WELL & EMPTY TIGER TANK. TOTAL FLUID LOST TO WELL DURING CIRCULATION = 140 BBLS. - TUBING AND VA ON VACUUM, 0/A = 250 PSI. 12:00 - 13:30 1.50 KILLW P DECOMP BLOW DOWN & R/D LINES. - RIG DOWN CHOKE MANIFOLD IN CELLAR. 13:30 - 15:00 1.50 WHSUR P DECOMP PICK UP LUBRICATOR, STAB ON TO WELL. _ TEST @ 250 / 3500 PSI / 5 MIN EACH, CHARTED, OK. - SET TWO WAY CHECK VALVE. 15:00 - 16:30 1.50 WHSUR P DECOMP ATTEMPT ROLLING TEST UNDER TWO WAY CHECK VALVE. PUMP RATE 5 BPM / 5 MIN / ACHIEVED 200 PSI. (FAILED) - TEST FROM THE TOP @ 250 / 3500 PSI / 5 MIN EACH/ CHARTED, OK. 16:30 - 18:30 2.00 WHSUR P DECOMP PJSM. REVIEW DDI SOP FOR N/D TREE AND N/U BOPE. - BLOW DOWN, RIG DOWN LINES, SUCK OUT TREE. - FMC MAKE CHALK MARK FOR ALIGNMENT PINS. - FUNCTION LDS. - WITH 2 BARRIERS IN PLACE, TESTED TWC AND 9.2 PPG BRINE KWF. - BLEED VOID, NIPPLE DOWN TREE AND ADAPTOR FLANGE. - FMC INSPECT AND VERIFY 2 7/8" EUE HANGER THREADS. 8 1/2 TURNS. - VERIFY PENETRATOR LENGTH. - USE CONTINUOUS HOLE FILL DOWN VA WITH CHARGE PUMP AND BYPASS LINE. 18:30 - 20:30 2.00 BOPSUR P DECOMP N/U 4 PREVENTER BOP STACK. - INSTALL ACCUMULATOR LINES. - NOTIFY AOGCC BOB NOBLE AT 20:15 HRS. WITH BOP TEST TIME_UPDATE. - WANTS 1 HR UPDATE BEFORE STARTING BOP TEST. Printed 9/25/2012 8:29:28AM • i i � PS ' I, : Common Well Name: MPE 31 AFE No Event Type: WORKOVER (WO) Pt E Pad Start Date: 8/11/2012 End Date: X4- OOVQX- E. (2,150,000.00 ) Project: Milne Point Site: M Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 00:00 3.50 BOPS P DECOMP PJSM FOR C/O RAMS. - INSTALL 3 1/2" X 6" VBR IN TOP UPPER BOP. - INSTALL 2 7/8" RAMS IN LOWEST BOP. - CONTINUE WITH CON TINUOIBS: HOLE FILL. WELL TAKING 7- 8 BPH 9.2 P BRINE KWF. - LAST 12 HRS WEL TOO 82 LS 9.2 PPG BRINE KWF. LAST 24 HRS WELL TOOK 22 BLS 9.2 PPG BRINE KWF. 8/31/2012 00:00 - 02:00 2.00 BOPSUR P DECOMP PJSM. CREW CHANGE - NIPPLE BOP NG THIS - INSTALL 3 1/2" X 6" VBR ON T INSTALL 2 7/8" FIXED RAMS ONE BOTTOM - RIG UP B ELL NIPPLE AND RISER - FUNCTION TEST ALL RAMS - RIG UP TO TEST BOP. AOGCC UP REP BOB NOBLE NOTIFIED OF PENDING TEST AT 01:00 HRS CONTINUOUS HOLE FILL DURI OPERATION TEST BOP P PROCEDURE 02:00 07:30 5.50 BOPSUR P DECOMP PJSM. ER AOGCC REGULATIONS A- ND DOYON TEST TEST ALL BOP AND CHOKE MANIFOLD VALVES TO 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES, CHARTED - TEST ANNU LAR USING 2 7/8" TEST JOINT TEST 2 7/8" LOWER PIPE RAMS USING 2 7/8" TEST JOINT TEST 3 1/2" X 6" VBR UPPER PIPE RAMS USING 4" AND 4 1/2 " TEST JOINTS ALL RAMS TESTED WITH MPL ENGAGED w - ACCUMULATOR MANIFOLD PRESSURE AT0PSI. - TEST 2 7/8" AND 4" FLOOR VALVES TEST USING FRESH WATER PERFORM DRAW DOWN TEST ON ACCUMULATOR. - _AOGCC REP BOB_NOBLE WIT RING THIS NESS TEST CONTINUOUS HOLE FILL DU OPERATION. 07:30 09:00 1.50 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT. - BLOW DOWN LINES AND LINE UP CHOKE MANIFOLD. 09:00 09:30 0.50 BOPSUR P DECOMP PERFORMED RIG EVACUATION DRILL. - ALL HANDS ACCOUNTED FOR, 4 MINUTES TO MUSTER AREA. WELL SECURED, PAD ENTRANCE CONTROLLED. - AAR, DISCUSSED WHAT LINE IN CASE HERE OF FIRE. FIRE ALARMS ALWAYS MANDATE IMMEDIATE SECURING OF THE WELL. (1) EXTINGUISHER MAY BE USED, THEN EVACUATE AND CALL FIRE DEPT. SIREN FOR RIG EVACUATION YET (ACTION ITEM). Printed 9/25/2012 8:29:28AM I .'> ; Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4 -OOVQX E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 11:30 2.00 WHSUR P DECOMP PJSM. PICK UP LOPSO OPSO TO PULL TWC. - PRESSURE TEST @ 250 / 3500 PSI / CHARTED / 5 MIN EACH / GOOD. - PULL TWO WAY CHECK VALVE, UD EQUIPMENT. - STATIC LOSS RATE = 8 BPH. 11:30 - 13:30 2.00 PULL P DECOMP PJSM. HANG SHEAVE & TRUNK FOR CABLES. FILL MUD GAS SEPERATOR. RIG UP CENTRILIFT. - FLUID LOST TO WELL FROM 00:00 TO 12:00 = 124 BBLS. - PERFORM DERRICK INSPECTION. 13:30 - 15:30 2.00 PULL P DECOMP PJSM. MAKE UP LANDING JT W/ SAFETY VALVE. - BOLDS, PULL HANGER TO FLOOR. 85K UP WT. - UP WT INCLUDES 40K TOP DRIVE WT. - UD HANGER, SECURE HEAT TRACE AND ESP CABLE TO PIPE. - RBIH W/ SLICK JT ACROSS STACK. CLOSE ANNULAR PREVENTOR. 15:30 17:30 2.00 PULL P DECOMP PJSM. LINE UP TO PUMP DOWN TBG & UP ANNULUS. TAKING RETURNS THRU CHOKE & MUD GAS SEPARATOR. - PUMPING 3 BPM / 380 PSI, CIRCULATING BOTTOMS UP. 17:30 - 18:30 1.00 PULL P DECOMP OPEN CHOKE AND FLOW CHECK WELL FOR 10 MINUTES. - OPEN ANNULAS. FILL HOLE WITH 3.8 BBL. - MONITOR WELL FOR 10 MINUTES. - WELL CONTINUES TAKING FLUID AT 8 BPH. 18:30 - 19:00 0.50 PULL P DECOMP RIH AND TAG TOP OF LINER AT 6366' - PICK UP 5 JTS 2 7/8" TUBING. - SLACK OFF WEIGHT 73K INCLUDING BLOCK WEIGHT. - TAG TIE BACK SLEEVE AT 6366' - POH AND LAY DOWN 5 JTS TUBING. 19:00 19:15 0.25 PULL P DECOMP PJSM WITH CREW AND CENTRILIFT. - DISCUSSED WELL CONTROL. - REMOVAL OF SEVERAL CLAMPS PER JOINT. - CUTTING TWO CABLES REQUIRES THE USE OF A SAFETY JOINT. 19:15 20:30 1.25 PULL P DECOMP WELL CONTROL DRILL. - POH TO REMOVE 2 CLAMPS. - CUT BOTH ESP AND HEAT TRACE CABLES - LOWER PIPE SET IN SLIPS. - MAKE UP SAFETY JOINT, RIH AND INSTALL FOSV. - SIMULATE CLOSING ANNULAR. CLOSE FOSV. - CONDUCT AAR. - CENTRILIFT HAND TO STAY ON FLOOR TO REMOVE CLAMPS. - MUST REMOVE 2 CLAMPS TO MAKE ROOM TO SET SLIPS. - DUE TO NUMBER OF CLAMPS A SAFETY JOINT WILL BE USED. Printed 9/25/2012 8:29:28AM • ,7;4 Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- OOVQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 00:00 3.50 PULL P DECOMP POH LAY DOWN 2 7/8 "_ESP COMPLETION. 1 -POH AND LAY DOWN 7 JTS. CONNECT CABLES TO SPOOLING UNIT. - REMOVE ESP AND HEAT TRACE CLAMPS. - POH FROM 6255' TO 5924'. - SPOOL ESP AND HEAT TRACE CABLES TO CENTRILIFT SPOOLER. USED CONTINUOUS HOLE FILL WITH 9.2 PPG BRINE. - LAST 12 HRS WELL TOOK 160 BBLS 9.2 PPG BRINE KWF. - LAST 24 HRS WELL TOOK 284 BBLS 9.2 PPG BRINE KWF. 9/1/2012 00:00 - 00:15 0.25 PULL P DECOMP CREW CHANGE - PJSM WITH CREW AND CENTRILIFT. - DISCUSS WELL CONTROL. - REMOVAL OF SEVERAL CLAMPS PER JOINT. AND CUTTING TWO CABLES REQUIRES THE USE OF A SAFETY JOINT. 00:15 - 02:00 1.75 PULL P DECOMP POH, LAY DOWN 2 7/8" ESP COMPLETION. - REMOVE ESP AND HEAT TRACE CLAMPS. - POH FROM 5924' TO 5877'. SPOOL ESP AND HEAT TRACE CABLES TO CENTRILIFT SPOOLER. - USE CONTINUOUS HOLE FILL WITH 9.2 PPG BRINE. 02:00 - 05:00 3.00 PULL P DECOMP RIG UP TO CIRCULATE WITH HEAD PIN AND FOSV. - EXCESSIVE AMOUNT OF HEAVY CRUDE ON TUBING AND CABLES. - MIX AND PUMP SAFE -SURF SWEEP. - CIRCULATE 2 HOLE VOLUMES TO CLEAN PIPE AND CABLES. - CIRCULATE AT 4 BPM WITH 570 PSI AT 5877' - RIG DOWN HEAD PIN AND LINES. 05:00 - 12:00 7.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" EUE 8 RND TUBING. - SPOOLING HEAT TRACE AND ESP CABLE AND REMOVE CLAMPS. - CONTINUOUS HOLE FILL. POOH TO 2766'. 57K UP WT, 57K DOWN WT. - LOSSES TO WELL = 151 BBLS IN LAST (12) HRS. - 0/A = 280 PSI. 12:00 - 12:30 0.50 PULL P DECOMP SERVICE RIG, PERFORM SYSTEM CHECKS. 12:30 - 14:00 1.50 PULL P DECOMP PJSM. CONTINUE TO POOH W/ 2 7/8" TUBING FROM 2200' - SPOOL ESP CABLE AND REMOVE CLAMPS. - CONTINUOUS HOLE FILL, LOSING 12 BPH. 14:00 - 16:00 2.00 PULL N SFAL DECOMP HYDRAULIC HOSE FAILURE ON HYDRAULIC SYSTEM ON MEZANINE. - OPERATIONS STOPPED, WELL SECURED, CREW RESPONDED. - AREA AUTHORITY CALLED, MILNE PT SECURITY NOTIFIED. - MILNE PT ENVIRONMENTAL NOTIFIED, BP SUPERINTENDANT NOTIFIED. - TRACTION REPORT # 4221248. SPILL CLEANED UP. Printed 9/25/2012 8:29:28AM I . Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 20:30 4.50 PULL P DECOMP OPERATIONS R, CONTINUE TO POOH W/ 2 7/8" TUBING ESUMED FROM 2200' - POH AND L/D LAST GLM AT 226' - FLOWCHECK WELL FOR 10 MIN. - WELL TAKING 12 BPH. - USE CONTINUOUS HOLE FILL. - POH, CONTINUE L/D REMAINING TBG, PUPS AND JEWELRY. - 199 JTS OF 2 7/8" EUE 8RD TBING LAYED DOWN. 20:30 - 21:30 1.00 PULL P DECOMP PJSM CENTRI FOR LIFT L/ AND D PUMP CREW. AND MOTOR WITH - REMOVE PROTECTORS, F/G CLAMPS. - SECURE ESP CABLE ONTO SPOOL. - PULL PUMP TO RIG FLOOR. 21:30 23:00 1.50 PULL P DECOMP CENTRILIFT INSPECT PUMP. - L/D PUMP AND MOTOR. - BROKEN SHAFT IN UPPER PORTION OF PUMP. AUTOMATED DIVERTER VALVE PLUGGED WITH SAND. - RECOVER 2 F /G, 3 PROTECTOLIZERS, 2 S.S. BANDS, 2 ARMSTER GUARDS. 738 CANNON CLAMPS RECOVERED. - TOOL SERVICE NORM TEST TBG, GLMS, PUPS, CLAMPS, ESP AND HEAT TRACE CABLES, TREE, ADAPTOR FLANGE AND TBG HANGER. - WELL TOOK 124 BBLS IN LAST 12 HRS 9.2 PPG BRINE. - WELL TOOK 275 BBLS IN LAST 24 HRS 9.2 PPG BRINE - O /A= 250 PSI 23:00 00:00 1.00 CLEAN P ®- DECOMP C POWER TONGS, E TRUNK AND ESP CABLE SHEAVE. - CLEAR AND CLEAN RIG FLOOR. 9/2/2012 00:00 00:30 0.50 CLEAN P DECOMP CREW CHANGE, PJSM. INSTALL WEAR RING, 9.125" ID. RUN IN 2 LOCK DOWN SCREWS. CLEAR AND CLEAN RIG FLOOR. - USE CONTINUOUS HOLE FILL WITH 9.2 PPG BRINE. 00:30 - 01:30 1.00 CLEAN P ■- DECOMP LOAD ASSY OUT FROM CENTRILIFT PIPE SHED. PUMP AND MOTOR - LOAD BAKER BHA AND TOOLS ONTO RIG. 01:30 - 03:30 2.00 CLEAN P DECOMP PJSM, ME P MAKE U 5.73 POLISHING MILL WITH DRESSING MILL, PIN X PIN SUB, 2 BOOT BASKETS, CASING SCRAPER, BIT SUB, STRING MAGNET, BUMPER SUB, XO, 9 EA 4.75" DC. 03:30 - 10:00 6.50 CLEAN P DECOMP RIH H 1TO ' - PICK WITH UP 4 DP A SINGLES 1878 FROM PIPESHED AND DRIFT. - USE CONTINUOUS HOLE FILL. - SCRAPE AREA (3 PASSES) F/ 6170' - 6190'. - CONTINUE TO RIH. Printed 9/25/2012 8:29:28AM Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 10:30 0.50 CLEAN P DECOMP PJSM. ESTABLISH PARAMETERS. 123K UP WT, 97K DOWN WT. - 105K ROTATING WT AT 70 RPM. ALL WTS INCLUDE 40K TOP DRIVE. - POLISH TIE BACK SLEEVE PER BAKER REP. - 4 BPM / 880 PSI, SET DOWN 5K W/ ROTATING, REPEAT 3X. FINAL DEPTH = 6367' DPM. (TOP @ 6358' DPM). - SPRS = 30 SPM @ 110 PSI, 40 SPM @ 210 PSI. 10:30 - 11:00 0.50 CLEAN P DECOMP PJSM. CIRCULATE 20 BBLS HI VIS SWEEP AROUND. - CIRCULATE AT 8 BPM / 950 PSI, LOST 78 BBLS DURING CIRCULATION. 11:00 - 12:00 1.00 CLEAN P DECOMP MONITOR WELL, FLUID LEVEL DROPPING SLOWLY. - PREP TO POOH. - SAFETY MEETING WITH CREW COMING ON. TOPIC OF DISCUSSION INCLUDED MAN RIDERS AND PRESSURE RELIEF VALVES. HOW THEY WORK AND WHAT TO LOOK FOR TO MAKE SURE THEY ARE OPERATING PROPERLY. - WELL TOOK 107 BBLS 9.2 PPG BRINE LAST 12 HRS. 12:00 - 12:30 0.50 CLEAN P - DECOMP SERVICE RIG EQUIPMENT AND INSPECT AREAS. 12:30 - 16:30 4.00 CLEAN P DECOMP PJSM. POOH WITH DRESS OFF ASSEMBLY. - CONTINUOUS HOLE FILL, LOSING 8 BPH. - AT BHA, MONITOR WELL, FLUID SLOWLY DROPPING. 16:30 - 17:30 1.00 CLEAN P DECOMP PJSM. UD DRILL COLLARS. - INSPECT UPPER MILL FOR WEAR. - GOOD INDICATION OF POLISH DONE ON TOP OF TIE BACK SLEEVE. - UD BHA. 17:30 - 18:00 0.50 EVAL P DECOMP PJSM FOR M/U 7 5/8" CHAMP PACKER. - DISCUSS RIH SPEED AT 1 MIN STAND. - MONITOR FLUID VOLUMES CLOSELY. - HAVE 2 7/8" SAFETY JT READY WITH XO. - USE CAUTION NOT TO ROTATE DRILL PIPE, SET IN SLIPS GENTLY. - LOAD HES TOOLS ONTO RIG FLOOR 18:00 18:30 0.50 EVAL P ■- DECOMP 4 PACKER, SERIAL # 102 10256830 6830 PER ER HES REP. M/U 5' HT38 PUP JT. 18:30 - 22:30 4.00 EVAL P DECOMP RIH WITH 7 5/8" CHAMP PACKER ON 4" DRILL PIPE FROM DERRICK. - RIH 1 MIN PER STAND WITH 64 STANDS TO 6130' - USE CAUTION SETTING IN SLIPS AND NOT ROTATING DRILL PIPE. - USE CONTINUOUS HOLE FILL. Printed 9/25/2012 8:29:28AM • # P C Well Name: ORKOVER MPE -31 A No Event Type: W (WO) Start 12 End Date: X4- OOVQX- E:DRILL (2,15 ) Project: Milne Point 12:00:00AM Site: M Date: Pt E 8/11/20 Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of O (hr) (ft) 22:30 - 23:00 0.50 EVAL P DECOMP DRIFT AND P/UT 8 JTS 4 ' ILL PIPE. -M /U 10'4 "PUPJT. AT 6330' jAiPp WT= 114 S/O WT = 9 INCLUDES 42K OP DRIVE WT. M/U TOP DR SET CHAMP PACKER AS PER HES IN UPSTROKE, TURN 3 TIMES TO RIGHT. - LET TORQUE OUT, SET DOWN 20K. SETTINGCENTER OF PACKER ELEMENTS T 6330' 23:00 00:00 1.00 EVAL P DECOMP JSM, CLOSE ANNULAR. REP. PUMP 2 BBLS THROUGH KILL LINE AND RESSURE TO 3600 PSI. _ 7 ' _CASING FOR 30 MINUTES. CHART TEST. - MO NITO O/A FOR ANY NS OF COMMUNICATION.. - NO PRESSURE LOSS, GOO SIGNS TEST. - BLEED OFF PRESSURE SLOWLY AND THROUGH CHOKE. - 2.7 BBLS BLED BACK. - OPEN ANNULAR. SUBMIT WELLBORE INTEGRITY CALCULATOR CHART T CHART TO WTL. - RELIEVE EST APPROVAL FROM WTL TO PROCEED WITH OPS. - LOSSES TO WELL LAST 12 HRS= 98 BBLS PPG BRINE. - 9.2 LOSSES TO WELL LAST 24 HRS= 205 BBLS 9.2 PPG BRINE. -O /A =240 PSI. - CONDUCT WEEKLY SAFETY MTG WITH ONCOMING CREW PRIOR TO CREW CHANGE. - DISCUS HOW L MAN RIDER WINCH W/O POWER. TO OWER - 1=, REVIEW TY PES AND FUNCTIONS OF RESSURE RELIEF VALVES. 9/3/2012 00:00 00:30 0.50 EVAL P DECOMP CREW CHANGE. PJSM WITH HES NEW REP. RELEASE PACKER PER HES REP. - PULL TO PICKUP WT AND RELAX ELEMENTS ON PACKER. P/U 5' WITH NO OVERPULL INDICATED. - ATTEMPT TO SLACK OFF, PACKER RESET. - P/U 5' AND REPEAT RELEASE STEPS 2 TIMES. - P/U 10':RI OTATE TO LEFT 2 TURNS 10 AND RELEAS PACKER. - BREAK OE. ' P - INSTA FOSV. T 00:30 05:00 4.50 EVAL P DECOMP PJSM. FISH LOADING P DRIV 160 UD JTS 4 PU 1/2" . 12.6# VAM TO TBG INTO PIPE SHED. - DRIFT ND TALLY TBG BEFORE POH AND UD 4" DLL PIPE. - LOAD COMPLETION EQUIPMENT INTO PIPE SHED. FLOWTINUCHECK WELL FOR 10 MIN. CONO HOLE FILL - L/D FOSV. US Printed 9/25/2012 8:29:28AM ► • Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 0OVQX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 12:00 7.00 EVAL P DECOMP PJSM. POOH W/ 4" DP. - POOH. UD 4" DP, CONTINUOUS HOLE FILL THROUGHOUT. - L/D HALLIBURTON CHAMP PACKER, NOTHING MISSING. - 146 BBLS 9.2 PPG BRINE LOST TO WELL LAST (12) HOURS. 12:00 - 13:00 1.00 RUNCOM P RUNCMP PJSM. PICK UP RUNNING TOOL. - BOLDS, PULL WEAR RING, UD RUNNING TOOL. - SERVICE RIG. INSPECT EQUIPMENT. 13:00 - 16:30 3.50 RUNCOM P RUNCMP PJSM. RIG UP TORQUE TURN EQUIPMENT. - RIG UP COMPENSATOR & TUBING TONGS. - RIG UP SCHLUMBERGER I WIRE SPOOLING EQUIPMENT. 16:30 - 17:00 0.50 RUNCOM P RUNCMP PRE JOB WITH ALL PARTIES INVOLVED. - EMPHASIZE GOOD COMMUNICATION. - REVIEW PROCEDURE, ENSURE ALL IS READY. - PINCH POINTS AND WELL CONTROL - GENERATE HOT WORK PERMIT FOR TESTING I WIRE. 17:00 19:00 2.00 RUNCOM P RUNCMP PICKUP JET PUMP COMPLETION ASSEMBI Y= PER TALLY AND HES,SLB REPS. - BAKER -LOC ALL CONNECTIONS BELOW PACKER. - CONNECT SLB I -WIRE TO INTAKE GUAGE. - TEST TOP AND BOTTOM GUAGES TO 5000 PSI FOR 20 MINUTES. - USE JET LUBE SEAL GUARD THREAD COMPOUND. - MAKE UP VAM TOP CONECTIONS TO 4440 FT /LBS TORQUE. 19:00 - 00:00 5.00 RUNCOM P RUNCMP RUN JET PUMP COMPLETION ON 4 V2" 13CR -85 12.6# VAM TOP TUBING - INSTALL CANNON WIRE CLAMPS ON EVERY JOINT. - VERIFY I -WIRE CONTINUITY AND GAUGE FUNCTION EVERY 1000'. - USE JET LUBE SEAL GUARD THREAD COMPOUND. - MAKE UP VAM TOP CONECTIONS TO 4440 FT /LBS. - RIH AT 100' PER MINUTE TO 2662' - LOSSES TO WELL LAST 24 HRS= 227 BBLS 9.2 PPG BRINE. - O /A= 240 PSI. 9/4/2012 00:00 - 01:00 1.00 RUNCOM P RUNCMP CREW CHANGE. PJSM - REVIEW RUNNING PROCEDURE WITH CREW, SLB, HES AND DDI CASING HAND. - REVIEW DDI SOP WITH ALL HANDS. - DISCUSSED WORKING ON THE CROWDED FLOOR. - RENEW HOT WORK PERMIT FOR TESTING I -WIRE. Printed 9/25/2012 8:29:28AM • s o � l � �� ._. Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- OOVOX- E:DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:00 - 10:00 9.00 RUNCOM P RUNCMP RUN JET PUMP COMPLETION ON 4 1/2" 13CR -85 12.6# VAM TOP TUBING - INSTALL CANNON WIRE CLAMPS ON EVERY JOINT. - VERIFY I -WIRE CONTINUITY AND GAUGE FUNCTION EVERY 1000'. - USE JET LUBE SEAL GUARD THREAD COMPOUND. - MAKE UP VAM TOP CONNECTIONS TO 4440 FT /LBS. - RIH AT 100' PER MINUTE TO 6076' - LOCATE OUT 24 1/2' IN ON #147 AT 6370' 10:00 - 11:30 1.50 RUNCOM P RUNCMP PJSM. LAY DOWN JTS # 147, 146 & 145. - SPACE OUT USING (3) PUPS, TOTAL LENGTH = 33.26'. - MAKE UP TBG HANGER W/ LANDING JT. WLEG AT 6365' 11:30 - 12:00 0.50 RUNCOM P ® RUNCMP PJSM. TIE IN I WIRE TO HANGER. - LOSSES TO WELL LAST (12) HRS = 83 BBLS. - (148) 2' CLAMPS (3) 1/2 CLAMPS. 12:00 - 13:00 1.00 RUNCOM P ■ RUNCMP PJSM. LAND HANGER & RILDS. - 96K UP WT, 84K DOWN WT. - ALL WT CHECKS INCLUDE 40K TOP DRIVE. 13:00 - 14:30 1.50 _ RUNCOM P RUNCMP PJSM. RIG DOWN CASING TONGS AND ■ EQUIPMENT. - RIG UP LINES TO MANIFOLD IN CELLAR. 14:30 - 15:00 0.50 RUNCOM P RUNCMP PJSM. TEST LINES @ 250 / 3500 PSI, 5 MIN EACH / CHARTED. 15:00 17:00 2.00 RUNCOM P RUNCMP PJSM. REVERSE CIRCULATE HEATED 9.2 PPG BRINE. - PUMP DOWN VA TAKING RETURNS UP TBG. - PUMP 100 BBL HEATED BRINE AT 4 BPM / 250 PSI. - PUMP 167 BBLS HEATED 9.2 PPG BRINE W/ CORROSION INHIBITOR. - PUMPING @ 4 BPM / 250 PSI. 17:00 - 19:00 2.00 RUNCOM P RUNCMP DROP BALL AND ROD - WITH BALL ON SEAT, PRESSURE UP ON TUBING TO 3500 PSI AND SET PACKER. - PUMPED 1.4 BBL TO PRESSURE UP. - GOOD SURFACE INDICATION OF PACKER SET. - TEST AND CHART, 30 MINUTES, GOOD TEST. - BLEED OFF TUBING PRESSURE TO 1700 PSI. - PRESSURE UP ON ANNULUS AGAINST PACKER TO 3500 PSI, 30 MINUTES, GOOD TEST. PUMPED 2.5 BBL TO PRESSURE UP. - BLEED TUBING DOWN TO SHEAR DCK VALVE. - GOOD SURFACE INDICATION OF SHEAR VALVE OPENING. - BLEED BACK 4 BBL. - CIRCULATE DOWN TUBING, 2 BPM = 620 PSI - CIRCULATE DOWN IA, 2 BPM = 550 PSI Printed 9/25/2012 8:29:28AM • m Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 8/11/2012 End Date: X4- 00VOX -E: DRILL (2,150,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: DOYON 16 Spud Date/Time: 6/8/2005 12:00:00AM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:30 1.50 WHSUR P WHDTRE SET TWC IN TUBING HANGER - TEST TWC FROM BELOW, 2000 PSI, 30 MINUTES, CHARTED - TEST TWC FROM ABOVE, 250 LOW, 3500 PSI HIGH, 5 MIN CHARTED 20:30 - 22:00 1.50 WHSUR P WHDTRE BLOW DOWN LINES. - RIG DOWN LINES IN CELLAR. CLEAR CELLAR 22:00 - 00:00 2.00 BOPSUR P WHDTRE PJSM ON NIPPLE DOWN BOP. COMMUNICATION ET - CHECK DISCUSS THAT TOOLS COMMUNC ARE O IN M GOOD HOD. WORKING ORDER. - NIPPLE DOWN BOP. - REMOVE BELL NIPPLE, RISER AND FLOW LINE. 9/5/2012 00:00 - 05:00 5.00 WHSUR P WHDTRE P. AA SPOOL NIPPLE AND DOWN TREE. BO TER LL AD I -WIRE PTOR AND CHECK CONTINUITY AND GUAGE FUNCTION. - TEST TUBING HANGER AND VOID @ 5000 PSI / 30 CHARTED MIN. - TEST TREE @ 5000 PSI FOR 5 MIN / CHARTED. 05:00 - 07:00 2.00 WHSUR P WHDTRE PJSM. PICK UP LUBRICATOR TO PULL TWO WAY CHECK VALVE. - TEST LUBRICATOR @ 250 3500 PSI / 5 MIN EACH / CHARTED. PJSM. PULL TWO WAY CHECK VALVE. STAND BACK LUBRICATOR. 07:00 - 09:00 2.00 WHSUR P POST RIG UP LITTLE RED TO CHOKE SKID. - PRE JOB ABOUT FREEZE PROTECTING. - TEST LITTLE RED LINES @ 250 / 2500 PSI, 5 MIN EACH. - LINE UP AND PUMP70 DEGREE DIESEL DOWN VA. - TAKING RETURNS UP TBG THRU CHOKE SKID TO SLOP TANK. - PUMP @ 3BPM / 170 PSI ICP. PUMP 95 BBLS, SEE DIESEL RETURNS. - SHUT DOWN, BLEED OFF 1 1/2 BBLS. SITP = 240 PSI. - I/A SHUT IN PRESSURE = 180 PSI, 0/A = 230 PSI. - CLOSE IN VALVES ON TREE, ISOLATE LITTLE RED. 09:00 - 10:30 1.50 WHSUR P POST PJSM. PICK UP LUBRICATOR. - TEST LUBRICATOR @ 250 / 3500 PSI, 5 MIN EACH / CHARTED. - SET BPV, UD LUBRICATOR. 10:30 - 12:00 1.50 WHSUR P POST PJSM. PRESSURE TEST BPV. - LINE UP W/ LITTLE RED, PUMPING DOWN I /A. - TESTING WITH 70 DEGREE DIESEL. - TEST @ 2000 PSI / 30 MINUTES / CHARTED - BLED OFF 57 PSI, 1ST 15 MIN, AND 23 PSI 2ND 15 MIN. - GOOD TEST. BLEED OFF ALL PRESSURE, SECURE WELLHEAD. - RIG DOWN LITTLE RED, SECURE WELL. - RIG RELEASED @ 12:00 HRS 09/05/2012. Printed 9/25/2012 8:29:28AM Tree 4- 1/16" - 5M CI On . DF Elev. = 43.25 Doyon 14 Wellhead; 11" x 4.5" 51ln 6 M P E -31 Orig. GL Elev. = 10.80 Doyon 14 w/ 4.5" TC -II T &B Tubing Hanger - ' 4" CIW "H" BPV profile Note: This well has an open OA shoe. 2/14/12 Conductor 112' Note: IA tested to 3600 psi on 9/2/12 from 6330'. 2' Blast rings below tubing hanger KOP @ 200' Hole angle passes 50° @ 2300' Max angle in tubing = 67° SLB 4.5" x 1" KGB - GLM 1 2106` 67° at sliding sleeve (4236' TVD) Angle thru liner = 90 +" 7. 10 3/4" 45.5# L -80 BTC -M Csg. 1 3310'1 I ■ Min. ID through tubing 3725" @ 6307E 7 5/8" 29.7# L -80 BTC -M casing (drift ID = 6.75 ", cap = .0262 BPF w/ Tbg inside) 4.5" 12.6# 13CR -85 VAM, IBT & TC -II tubing (ID = 3.958 ", cap = .0152 BPF) .. . SLB Multi - drop Sapphire Gauge 1 6075` 1 n (3.833" ID) SGM - NDPG - Gauge TVD = 4232' 'Reverse C rcu atwn "Jet Pump fin,Rlgure4on � 4.5" HES "XD" Dura sliding sleeve) 6087' x � ' 3 .813" I ( Opens down) I T .' 1 1 1 L I ( J SLB Sngle -drop Sapphire Gauge 1 6097` 1 �� (3.833" i ID) SGM - NDPG -C i g Gauge TVD = 4240' I I y — Reservol, Flul 7 5/8" x 4.5" HES TNT Pkr 1 6162' I I _ . (3.856" ID) 4.5" HES X- Nipple (3.813" Pkg bore) 1 6237` I H 4.5" HES XN Nipple 1 6307` (3.813" x 3.725" No Go) .0 WLEG 16365' 1 Baker Tie Back Sleeve 6,366' Baker 5 1/2" x 7 5/8" ZXP Liner Top Pkr 6,377' 7 5/8" float collar (PBTD) I 6,416' I - Baker 5 1/2" x 7 5/8" HMC Liner Hanger 6,384' 7 5/8" Weatherford float shoe I 6,502' I ...._._. .._�. Pay zone "ESP" Packer @ 6,576' 4" Baker C27, Medium Excluder Screens & 4" Blank Joints 4" 9.5 #, L -80, IBT. Drift ID = 3.423" Capacity = 0.01223 bpf 6,649' - 8,997' 4.5" Baker packoff bushing 1 8,997` 11111 4.5" Baker float shoe 19,042' I DATE REV. BY COMMENTS MILNE POINT UNIT 06/29/05 MDO Drilled & Completed Doyon -14 WELL MPE - 02 -17 -08 JRP ESP Change out (3S) API NO: 50 029 - 23263 - 00 9/24/10 REH ESP Change out - Nabors 4ES 9/03/12 Hulme Convert to Jet Pump -Doyon 16 BP EXPLORATION (AK) • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 _ a0G a P- Mr. Tom Maunder AP ' Alaska Oil and Gas Conservation Commission . n ., 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPE -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPE -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, �.-- Q 2: 2 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) MPE -Pad 10/10/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal MPE -02 1851910 50029214170000 3.8 NA 3.8 NA 5.95 8/23/2011 MPE -03 1890170 50029219160000 Tanko conductor NA NA NA NA NA MPE -04 1900050 50029219970000 Tanko conductor NA NA NA NA NA MPE -05 1900810 50029220580000 Sealed conductor NA NA NA NA NA MPE -06 1910480 50029221540000 0.2 NA 0.2 NA 6.8 9/6/2011 MPE -07 1910490 50029221550000 Sealed conductor NA NA NA NA NA MPE -08 1910500 50029221560000 Sealed conductor NA NA NA NA NA MPE-09 1941320 50029225130000 14.0 NA Need top job MPE -10 1941430 50029225210000 0.9 NA 0.9 NA 7.65 8/23/2011 MPE -11 1950010 50029225410000 11.0 _ NA Need top job MPE -12 2050670 50029232620000 1.0 NA 1.0 NA 4.25 8/23/2011 MPE -13B 2020440 50029225360200 Dust Cover NA NA NA 57.8 9/6/2011 MPE -14 1970050 50029227340000 0.0 NA 0.0 NA 7.65 10/10/2011 MPE -15 1941530 50029225280000 0.8 NA 0.8 NA 8.5 8/26/2011 MPE -16 1961140 50029226860000 0.6 NA 0.6 NA 5.95 8/26/2011 MPE -17 1961150 50029226870000 12.8 NA Need top job MPE -18 1970420 50029227480000 2.3 NA 2.3 NA 17 8/23/2011 MPE -19 1970370 50029227460000 0.1 NA 0.1 NA 7.65 10/10/2011 MPE -20A 2040540 50029225610100 1.0 NA 1.0 NA 6.8 8/23/2011 MPE -21 1981150 50029228940000 3.0 NA 3.0 NA 10.2 8/23/2011 MPE -22 1950810 50029225670000 0.8 NA 0.8 NA 3.4 8/23/2011 MPE -23 1950940 50029225700000 1.6 NA 1.6 NA 15.3 9/6/2011 MPE -24A 2001860 50029228670100 0.2 NA 0.2 NA 5.1 9/6/2011 MPE -25A 2040450 50029229800100 2.0 NA 2.0 NA 15.3 8/23/2011 MPE -26 2002060 50029229940000 Dust Cover NA NA NA 5.1 9/6/2011 MPE -28 2050550 50029232590000 1.8 NA 1.8 NA 15.3 8/23/2011 MPE -29 2010370 50029230040000 Dust Cover NA NA NA 3.4 9/6/2011 MPE -30A 2010110 50029229030100 0.3 NA 0.3 NA 2.55 8/26/2011 `--)► MPE -31 2050720 50029232630000 2.0 NA 2.0 NA 13.6 8/23/2011 MPE -32 2050650 50029232610000 1.5 NA 1.5 NA 13.6 8/23/2011 MPE -33 1981280 50029228980000 4.1 NA 4.1 NA 7.65 8/23/2011 + ALASKA OIL ANDS CONSERVATION COMMISSION rCEIVED REPORT OF SUNDRY WELL OPERATION NOV 1 0 2011 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 0 .�yy r Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver ❑ Tim Ai y Cons. Commission Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ncharepe 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ID Exploratory ❑ — 205 -0720 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 r � r -. 50- 029 - 23263 -00 -00 8. Property Designation (Lease Number) : 1 9. Well Name and Number: ADLO- 025518 4 1 4 It n kt 4 - MPE -31 10. Field /Pool(s): MILNE POINT FIELD / SCHRADER BLFF OIL POOL 11. Present Well Condition Summary: Total Depth measured 9042 feet Plugs (measured) None feet true vertical 4368.16 feet Junk (measured) None feet Effective Depth measured 9042 feet Packer (measured) 6576 feet true vertical 4368.16 feet (true vertical) 4398 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 91.5# H -40 35 - 113 35 - 113 1490 470 Surface 3276' 10 -3/4" 45.5# L -80 34 - 3310 34 - 2669 5210 2480 Production 6469' 7 -5/8" 29.7# L -80 33 - 6502 33 - 4384 6890 4790 Liner 283' 4 -1/2" 12.6# L -80 6366 - 6649 4342 - 4404 8430 7500 Liner 2348' 4" 9.5# L -80 6649 - 8997 4404 - 4368 7910 6590 Liner 45' 4 -1/2" 12.6# L -80 8997 - 9042 4368 - 4368 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ Tubing: (size, grade, measured and true vertical depth) 2 -7/8" 6.5# L -80 32 - 6257 32 - 4301 Packers and SSSV (type, measured and true vertical depth) Not Cataloged , 4398 .s 4' r.�y .,, r t r" 'i l ` 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: 455 43 98 179 Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El - Service p Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil 0 0 Gas ❑ WDSPL ❑ 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: NA Contact Joe Lastufka Printed Na •e Las AK l l Title Petrotechnical Data Technologist Signatu = �,1 ` Phone 564 -4091 Date 11/9/2011 NNW • / Form 10 -404 Revised 10/201 1.--- NOV 14 Zan A `/ vee.(( Submit Original Only MPE -31 . 205 -072 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE -31 6/18/05 PER 6,649. 6,687. 4,404.31 4,407.27 MPE -31 6/18/05 PER 8,408. 8,446. 4,373.35 4,373.31 MPE -31 6/18/05 PER 8,478. 8,515. 4,373.42 4,373.59 MPE -31 6/18/05 PER 8,547. 8,585. 4,373.51 4,372.51 MPE -31 6/18/05 PER 8,616. 8,654. 4,371.56 4,370.04 MPE -31 6/18/05 PER 8,685. 8,723. 4,368.31 4,366.96 MPE -31 6/18/05 PER 8,755. 8,792. 4,366.24 4,365.76 MPE -31 6/18/05 PER 8,824. 8,861. 4,365.73 4,366.2 MPE -31 6/18/05 PER 8,890. 8,928. 4,366.61 4,367.02 MPE -31 6/18/05 PER 8,959. 8,997. 4,367.34 4,367.71 MPE -31 6/18/05 PER 8,340. _ 8,377. 4,375.02 4,373.86 MPE -31 6/18/05 PER 8,270. 8,308. 4,379.41 4,376.56 MPE -31 6/18/05 PER 7,980. 8,018. 4,398.65 4,396.61 MPE -31 6/18/05 PER 7,722. 7,759. 4,400.68 4,400.86 MPE -31 6/18/05 PER 6,877. 6,914. 4,408.31 4,407.85 • MPE -31 6/18/05 PER 6,946. 6,984. 4,407.6 4,407.36 MPE -31 6/18/05 PER 7,012. 7,050. 4,407.36 4,407.98 MPE -31 6/18/05 PER 7,082. 7,119. 4,408.75 4,409.9 MPE -31 6/18/05 PER 7,151. 7,189. 4,410.99 4,411.64 MPE -31 6/18/05 PER 7,290. 7,327. 4,411.03 4,409.99 MPE -31 6/18/05 PER 7,514. 7,552. 4,405.27 4,403.75 MPE -31 6/18/05 PER 7,583. 7,621. 4,402.56 4,401.59 MPE -31 6/18/05 PER 7,653. 7,690. 4,401.02 4,400.66 MPE -31 6/18/05 PER 7,221. 7,258. 4,411.81 4,411.61 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED • MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • MPE -31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/22/2011 +T /I /0= 425/420/250. (ESP acid treatment) Pump 10 bbls 10% DAD acid down tbg followed by 3 bbls 60/40. meth & 28 bbls produced water. Pump 2 bbls 60/40 meth to freeze protect surface lines. Let acid soak for 2 hrs. Well support attempted to start i ESP and flow well. Well would not surface fluid. Displace acid back into formation w/ i90 bbls produced water. Freeze protect tbg w/ 15 bbls 60/40 meth. FWHP= 380/440/300. IA & OA OTG. FLUIDS PUMPED BBLS 11 10% DAD ACID 118 PRODUCED WATER 20 60/40 METH 149 TOTAL TREE: 2 -9116" - 5M FMC 31 Orig. DF Elev. = 43.25 Doyon 14 M P E - WELLHEAD: 11" x 2- 9/16" 5M FMC Gen 5 Orig. GL Elev. = 10.80 Doyon 14 Tub Hgr. Dual ported 11" x 2 -7/8" 8rd T &B r 2.5" CIW -H BPVT PI Conductor ( 112' Camco 2 -7/8" x 1" KOP @ 200` sidepocket KBMM GLM 141' Angle passes 50° 0 2300' Max Angle in Tbg = 67° 0 6200' Angle thru liner = 90 +° I 10 3/4" 45.5# L -80 BTC -M Csg. ( 3310'1 I j 11 I Centrilift Heat Trace to 3300' 2 7/8" 6.5# EUE 8RD, L -80 tBG. ; Drift Id: 2.441 "Capacity: 0.00579 7 5/8" 29.7 ppf, L -80, BTC -Mod casing ( drift ID = 6.75 ", cap. = 0.0459 bpf ) (cap w/ 2 7/8" tbg inside = 0.0379 bpf) Camco 2-7/8" x 1" 1 6031 ` 1:1: sidepocket KBMM GLM 2 -7/8" XN nipple 61801 ( No-Go ID 2.250" ) Automatic Divert Valve 6202' Note: 2 318" Discharge Head �_ Discharge Head -FPHVDIS 1 6207` D= 1.69" - . r Pum Model - PMSXD 140 -P10 6,207` 1 1 Intake Gas Separator 6,225' GRSFTXARH6 Tandem Seal Section 6 GSB3DB UT /LT i . Motor, 76 HP, 1360 V, 34 amp,Model KMHGAS /76 6,244` C Phoenix XTO w /Centralizer 6,252` s w Baker Tie Back Sleeve 6,366' Baker 5 1/2" x 7 5/8" ZXP Liner Top Pkr 6,377' 7 5/8" float collar (PBTD) I 6,416' ( - Baker 5 1/2" x 7 5/8" HMC Liner Hanger 6,384' 7 5/8" Weatherford float shoe I 6,502' I Pay zone "ESP" Packer @ 6,576' 4" Baker C27, Medium Excluder Screens MEI & 4" Blank Joints 4" 9.5 #, L -80, IBT. Drift ID = 3.423" Capacity = 0.01223 bpf 6,649` - 8,997' 4.5" Baker packoff bushing 1 8,997` 4.5" Baker float shoe 19,042' DATE REV. BY COMMENTS MILNE POINT UNIT 06/29/05 MDO Drilled & Completed Doyon -14 WELL MPE - 02 -17 -08 JRP ESP Changeout (3S) API NO: 50 029 - 23263 - 00 9/24/10 REH ESP Changeout - Nabors 4ES BP EXPLORATION (AK) STATE OF ALASKA ALAS AND GAS CONSERVATION COMMII&N REPORT OF SUNDRY WELL OPERATIONS 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 ❑ Perforate ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory `; 205 -072 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 % 50 -029- 23263 -00 -00 7. Property Designation: v ' 8. Well Name and Number: ADL 025518 & ADL 047438 ° MPE - 9. Field / Pool(s): Milne Point Unit / Schrader Bluff 10. Present well condition summary Total depth: measured 9042 feet Plugs (measured) None true vertical 4368 feet Junk (measured) None Effective depth: measured 9042 feet Packer: measured 6576' feet true vertical 4368 feet true vertical 4398' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 113' 113' 1490 470 Surface 3275' 10 -3/4" 3310' 2669' 5210 2480 Intermediate Production 6469' 7 -5/8" 6502' 4384' 6890 4790 Liner 2676' 4 -1/2" 6366'-9042' 4342'-4368' 8430 7500 Perforation Depth: Measured Depth: Screens 6649'- 8997' RMN EE) NOV 5 20 1 0 True Vertical Depth: Screens 4404'- 4368' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 80 6256' MD 4301' TVD Packers and SSSV (type, measured and true vertical depth): Pay Zone "ESP" Packer 6576' MD 4398' TVD 11. Stimulation or cement squeeze summary:, ° 4 Intervals treated (measured): Treatment description including volumes used and final pressure: / V Q 10 OY 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 93 7 22 130 0 Subsequent to operation: 479 22 123 220 179 13. Attachments: ❑ Copies of Logs and Surveys run 14. Well Class after work: • Daily Report of Well Operations # ® Development ❑ Service ❑ Exploratory ❑ Stratigraphic • Well Schematic Diagram 15. Well Status p ® Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ Suspended after work: ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG 16. 1 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 Hank Baca, 564 -5444 N/A Printed Name Sondra Stewman Title Drilling Technologist r t Prepared By Name/Number: Sig re �� C ~, Phone 564 -4750 Date! - ( "�" P D Sondra Stewman, 564 -4750 Form 10-404 Revised 07/2009 Sub it Original Only RBDMS NOV 0 5 2010 ( �� ' / O W `V/0h TREE: 2- 9/16" - 5M FMC Orig. DF = 43.25 Doyon 14 WELLHEAD: 11" x 2- 9/16" 5M FMC GO M P E -31 Orig. GL = 10.80 Doyon 14 Tub Hgr. Dual ported 11" x 2 -7/8" 8rd T &B 2.5" CIW -H BPVT Conductor 112' KOP @ 200' Camco 2 -7/8" x 1" sidepocket KBMM GLM Angle passes 50 @ 2300` Max Angle in Tbg = 67 @ 6200` Angle thru liner = 90 +° oo 10 3/4" 45.5# L -80 BTC -M Csg. F331 O` ol Centrilift Heat Trace to 3300' 2 7/8" 6.5# EUE 8RD, L -80 tl3G. Drift Id: 2.441 "Capacity: 0.00579 7 5/8" 29.7 ppf, L -80, BTC -Mod casing ( drift ID = 6.75 ", cap. = 0.0459 bpf) Camco 2 -7/8" x 1" (cap w/ 2 7/8" tbg inside = 0.0379 bpf) 6031 ` sidepocket KBMM GLM 2 -7/8" XN nipple 6180` — L ( No -Go ID 2.250" ) Automatic Divert Valve 6202` Note: 2 3/8" Discharge Head Discharge Head - FPHVDIS 6207` ID= 1.69" Pump, Model - PMSXD 140 -P10 6,207` Intake Gas Separator 6,225` GRSFTXARH6 Tandem Seal Section 6,230` GSB3DB UT /LT Motor, 76 HP, 1360 V, 34 amp,Model KMHGAS /76 6,244` Phoenix XTO w /Centralizer 6,252` Baker Tie Back Sleeve 6,366` Baker 5 1/2" x 7 5/8" ZXP Liner Top Pkr 6 377` 7 5/8" float collar (PBTD) 6,416' Baker 5 1/2" x 7 5/8" HMC Liner Hanger 6,384` 7 5/8" Weatherford float shoe 6,502` Pay zone "ESP" Packer @ 6,576' 4" Baker C27, Medium Excluder Screens & 4" Blank Joints 4" 9.5 #, L -80, IBT. Drift ID = 3.423" Capacity = 0.01223 bpf 4.5" Baker packoff bushing 87997` 6,649' - 8,997' 4.5" Baker float shoe 9,042` DATE REV. BY COMMENTS MILNE POINT UNIT 06/29/05 MDO Drilled & Completed Doyon -14 WELL MPE -31 02 -17 -08 JRP ESP Changeout (3S) API NO: 50- 029 - 23263 -00 9/24/10 REH ESP Changeout - Nabors 4ES LBIP EXPLORATION AK MPE -31 Well History Date Summary 08/02/10 * ** WELL S/I ON ARRIVAL * ** (trouble shoot esp) RUN 2.05" CENT,2' X 1.25" STEM (2 -10 1/4" ext made together) W/ 1.50" LIB. S/D @ 3980' UNABLE TO SEE JARS WORK PAST. STOP @ 4500' SLM. 750# PICK UP WEIGHT ( SURFACE OF LIB IS PEPPERED W/ IMPRESSION OF SCALE) WELL S/I ON DEPARTURE * ** DSO NOTIFIED » » >NOTE:2 3/8" DISCHARGE HEAD W/ 1.69" I.D 08/05/10 "'" WELL S/I ON ARRIVAL * ** (trouble shoot esp) RUN 2.05" CENT,2' X 1.25" STEM (2 -10 1/4" ext made together) W/ 1.50" LIB. S/D @ 3980' UNABLE TO SEE JARS WORK PAST. STOP @ 4500' SLM. 750# PICK UP WEIGHT ( SURFACE OF LIB IS PEPPERED W/ IMPRESSION OF SCALE) * ** WELL S/I ON DEPARTURE * ** DSO NOTIFIED » » >NOTE:2 3/8" DISCHARGE HEAD W/ 1.69" I.D 08/21/10 CTU #5 w/ 1.75" CT: Job Scope: FCO /Restart ESP: MIRU Coiled tubing unit. MU and RIH with 1.75" DJN w/ side jets cleanout BHA while jetting diesel Tag pump at 6206' ctmd. Jet diesel at max rate on top of pump and circulate bottoms up. Attempt to bullhead diesel through pump. No injectivity. MU and RIH with DJN BHA. Jet on pump. No injectivity established. Spot 12 % DAD acid on pump in stages and soak. No injectivity with acid, pooh change BHA up. Rih with 1.5" DJN and stinger below 1.75" tools. 08/22/10 CTU #5 w/ 1.75" CT: RIH with 1.5" tools on bottom of 1.75" tools to be able to bump the pump. Bump pump and cycle pressures, pump turned momentarily and seized up, was not able to turn again. Displaced acid to tank. RDMO CT unit. ** *Job Complete * ** 08/25/10 ** *WELL S/I ON ARRIVAL ** *(rig prep) PULLED 1" BK -DGLV FROM ST #1 @ 6032' MD. CURRENTLY RIH W/ KJ, 2.12" CENT, SHOCK ABSORBER, XO, DUAL SPARTEK GAUGES 08/26/10 * * *CONT'D FROM 08- 25 -10 ** *(rig prep, sbhp) RAN KJ, 2.12" CENT, SHOCK ABSORBER, XO, DUAL SPARTEK GAUGES. MADE 30 MIN GRADIENT STOP @ 5,693' SLM (5705' MD) MADE 3 HOUR BHP STOP @ 6,187' SLM (6,199' MD) WELL LEFT S /I, TURN OVER TO DSO. ** *JOB COMPLETE * ** 08/26/10 TWO = 400/150/340. Freeze protected tubing w/ 15bbls 90 *F diesel. Freeze protected both production and test headers w/ 2bbls 60/40, 3bbls 90 *F diesel, 2bbls 60/40. FWHP's = 400/200/340. Swab, Wing, SSV, both laterals = shut. Master, IA, OA = open. 09/01/10 T /I/O= BPV/180/340, Temp =Sl. PPPOT-T (PASS), PPPOT -IC (PASS). Pre RWO. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely (1 "). Pressured void to 5000 psi for 30 min test, lost 0 psi in 30min (PASS). Bled void to 0 psi PPPOT -IC: Stung into test port (200 psi), bled to 0 psi. Functioned LDS, all moved freely (.75 "). Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 0 psi in 30 min (PASS). Bled void to 0 psi. 09/08/10 * ** WELL S/I ON ARRIVAL * ** (sbhps) ASSISTED SUPPORT TECHS PULL BPV. RUN 2.12" CENT,S.S,DUAL SPARTEK GAUGES.MADE 30 MINUTE STOP @ 5705' MD & 6 HOUR STOP @ 6199' MD. 09/09/10 * ** CONTINUED FFROM 09 -08 -10 (sbhps) RAN 2.12" CENT,S.S,DUAL SPARTEK GAUGES.MADE 30 MINUTE STOP @ 5705' MD & 6 HOUR STOP @ 6199' MD. ASSISTED SUPPORT TECHS INSTALL BPV. » »> BPV SET « «< * ** WELL S/I ON DEPARTURE * ** Page 1 of 2 MPE -31 Well History Date Summary 09/12/10 LRS Unit 64 Load & Trans ort Diesel 09/25/10 T /1 /0= 0/0/220. Freeze protect. Pumped 15bbls crude down tubing. Pumped 90bbls crude down IA. FWHP's = BPV /200/220. Swab, SSV, wing = shut. Master, IA, OA = open + 09/26/10 MPU Well Support Techs Rehooked well foundation, flowlines, well house 9- 25 -10, 9 -26 removed 2nd IA P6S work valve. PT flowlines to 1150 psi for ten mints with diisel passed, them removed « « « < » » »» (� from well boar. V Page 2 of 2 North America - ALASKA - BP Page 1.of Operation Summary Report Common Well Name: MPE -31 AFE No Event Type: MOBILIZATION (MOB) Start Date: 9/1512010 End Date: X4- OORFJ -E (35,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datu MPE -31: @56.3 (abo Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/18/2010 06:00 14:00 8.00 RIGD P PRE RIG DOWN - PJSM. SCOPE DOWN AND LAY OVER DERRICK PREP RIG COMPONENTS FOR MOVING. 14:00 - 19:00 5.00 MOB P PRE PJSM. MOVE RIG F/ MPK PAD TO MPE PAD 19:00 00:00 5.00 RIGU P PRE PJSM. MATT UP AROUND WELL, LAY HERCULITE. - SPOT UP ON WELL, DS OPERATOR PRESENT - SPOT VARIOUS RIG COMPONENTS & RIG UP. 9/19/2010 00:00 03:00 3.00 RIGU P PRE PJSM. RAISE AND SCOPE DERRICK. LEVEL RIG, LOWER BEAVER SLIDE - RIG UP VARIOUS RIG COMPONENTS - RIG ACCEPTED 03:00 HRS. 09/19/2010 Printed 10/14/2010 11:36:54AM North Arrlrica - Af,ASKA= BP. PaceF1 affil«: J opera #ions Summary'Repoirt Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Da tum: MPE -31: @56.30ft (ab Mean Sea Level Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/19/2010 103:00 - 04:30 1.50 KILLW P DECOMP TAKE ON 8.7 PPG HEATED BRINE TO PITS - RIG UP LINES TO TIGER TANK AND WELLHEAD RIG ACCEPTED @ 03:00 HRS, 09/19/2010 04:30 06:00 1.50 KILLW P DECOMP PJSM. RU LUBRICATOR AND TEST TO 250 / 2000 PSI. - GOOD TEST. 06:00 07:00 1.00 KILLW P DECOMP PULL BPV AND LID. = LID LUBRICATOR. 07:00 - 07:30 0.50 KILLW P DECOMP PERFORM PRE -TOUR CHECKS AND SERVICE RIG. CHECK AND SET PVT ALARMS. INSPECT DERRICK AND GREASE CROWN. SERVICE DRAWWORKS. PERFORM ENVIRONMENTAL WALK AROUNDS. 07:30 - 08:00 0.50 KILLW P DECOMP PRESSURE TEST SURFACE EQUIPMENT TO 3500 PSI -GOOD TEST. PRESSURE TEST LINES TO TIGER TANK TO 500 PSI- GOOD TEST. 08:00 08:30 0.50 KILLW P DECOMP PJSM FOR WELL KILL. - HELD A PJSM WITH RIG CREW, RIG LEADERSHIP, SPOC, AND VAC TRUCK DRIVERS. - DISCUSSED WELL KILL OPERATION & EMERGENCY MUSTER LOCATION AND j PROCEDURES. 08:30 - 14:30 6.00 KILLW P DECOMP WELL KILL: - INITIAL WELLHEAD PRESSURES: OA = 300 PSI, IA = 210 PSI, AND TBG = 190 PSI. - BLED OFF OA TO 75 PSI BEFORE PUMPING FLUIDS. - BLED OFF BOTH IA AND TUBING PRESSURES THROUGH CHOKE TO TIGER TANK. - OA = 75 PSI, IA = 30 PSI, AND TBG = 10 PSI. - BEGIN CIRCULATING DOWN THE TBG TAKING RETURNS THROUGH THE CHOKE TO THE TIGER TANK. - PUMPED 44 BBLS AT 3.5 BPM IA = 130 PSI, TBG = 350 PSI. CLOSED CHOKE AND BULLHEADED 55 BBLS 4 -5 BPM IA = 390 -630 PSI, TBG = 660- 1200 PSI. i -SHUT DOWN & MONITOR: SITP 20 PSI, SICP 300 PSI - CONTINUE CIRCULATING DOWN TUBING & UP VA. PUMP 485 BBLS @ 6BPM / 1400 - 1500 PSI SEE SIGNIFICANT AMOUNTS OF GASSED UP (VERY THICK, VERY LIGHT) CRUDE IN RETURNS CIRCULATE TILL IT CLEANS UP, (485 BBLS), BLEED BACK 24 BBLS IN 40 MIN. - 279 BBLS LOST TO FORMATION W/ KILLING WELL. SITP 0 PSI, SICP 0 PSI. Printed 10/14/2010 11:34:13AM 'AMorth America - ALASKA - BR Page 'of 8 Qperatian Summary Report Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9116/2010 End Date: X4- OORFJ -E (365,000.00) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 18:00 3.50 WHSUR P DECOMP SET TWO WAY CHECK VALVE. TEST FROM BELOW @ 500 PSI / 5 MIN/ CHARTED, (ROLLING TEST) TEST FROM ABOVE @ 3500 PSI, (SOME TROUBLE GETTING A TEST) - TEST @ 3500 PSI / 5 MIN / CHARTED .. GOOD TEST. 18:00 - 18:30 0.50 WHSUR P DECOMP CONDUCT PRE TOUR CHECKS, DO WALK AROUNDS - SERVICE RIG EQUIPMENT. 18:30 23:00 4.50 BOPSUR P DECOMP PJSM. N/U 13 5/8" X 5M BOPE 23:00 - 00:00 1.00 BOPSUR P DECOMP CONDUCT WEEKLY SAFETY MEETING REVIEW PREVIOUS (2) WEEKS OF INCIDENTS - GOOD DISCUSSION ON EACH, PARTICULARLY GOOD RESPONSE OF 7ES RIG CREW WHEN H2S ALARMS SOUNDED ERRONEOUSLY. 9/20/2010 00:00 - 05:30 5.50 BOPSUR P DECOMP PJSM. CONDUCT FULL TEST ON 13 5/8" X 5M BOPS. - AOGCC STATE REP BOB NOBLE WAIVED n WITNESSING, 24 HR NOTICE GIVEN D `KJ - TEST ALL COMPONENTS, VALVES, RAMS AND ANNULAR @ 250 / 3500 PSI. - NO FAILURES. CONDUCT ACCUMULATOR DRAWDOWN TEST, OK. 05:30 06:00 0.50 BOPSUR P DECOMP RIG DOWN BOPE TEST EQUIPMENT. 06:00 07:00 1.00 BOPSUR P DECOMP CONDUCT PRE TOUR CHECKS, SERVICE RIG. 07:00 10:30 3.50 BOPSUR P DECOMP PJSM. INSTALL DUTCH SYSTEM RISER. - R/U LUBRICATOR, PRESS TEST @ 250 / 3500 PSI _ - PULL TW WAY CHECK VALVE. UD TOOLS. 10:30 - 14:30 4.00 CLEAN P DECOMP PJSM. SECURE HEAT TRACE AND ESP CABLE TO TUBING. - CLOSE ANNULAR, LINE UP TAKING RETURNS THROUGH CHOKE. - CBU, 4 BPM @ 570 PSI. PUMPED 355 BBLS, LOST 94 BBLS. - NO HYDROCARBONS AT SURFACE. MONITOR WELL, WELL STABLE. 14:30 - 15:00 0.50 CLEAN P DECOMP RIH W/ (3) SINGLES, TAG TOL @ 6374' 15:00 - 16:00 1.00 CLEAN P DECOMP CIRCULATE BOTTOMS UP, 5 BPM '/ 960 PSI. - 34 BBLS LOST W/ CIRCULATING. 16:00 - 16:30 0.50 CLEAN P DECOMP MONITOR WELL, WELL STABLE. 16:30 18:00 1.50 PULL P DECOMP PJSM. UD (3) JTS, POOH W/ ESP COMPLETION. - RUN HEAT TRACE AND ESP CABLES OVER SHEAVES. - CONTINUOUS HOLE FILL W/ POOH. 2 BPH LOSS RATE. 18:00 18:30 0.50 PULL P DECOMP CONDUCT PRE TOUR CHECKS, SERVICE RIG 18:30 - 20:30 2.00 PULL P DECOMP CONTINUE TO POOH W/ 2 7/8" EUE 8 RND ESP COMPLETION. - SPOOLING UP HEAT TRACE AND ESP CABLE, CONTINUOUS HOLE FILL. Printed 10/14/2010 11:34:13AM orth amenca - ALASKA - BP= Page 3 Qfi� Operation Summary Report Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) i Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date i From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:30 - 21:00 0.50 PULL P DECOMP LOSS RATE REPORTED FOR LAST (2) HRS, 38 BBLS. -19 BPH AVERAGE. CONTACT TOWN ENGINEER. - DECISION MADE TO PUMP HI VIS PILL, (100 BBLS) - PILL IS MADE UP AND IN TRUCK, ON LOCATION 121:00 - 22:30 1.50 LCR P DECOMP PJSM. RIH W/ (3) STANDS & (3) SINGLES - RECLAMPING CABLES, SECURE CABLES TO PIPE. 22:30 23:00 0.50 LCR P DECOMP CONDUCT H2S DRILL: - DRILL ANOUNCED OVER RIG RADIO AND HARMONY - RIG EVACUATED TO SAFE ZONE, (SHOP) - TRUCK DRIVER & CENTRILIFT HANDS NOTIFIED & EVACUATED - LOADER OPERATOR TO SPOC SHACK FOR HEAD COUNT LIST DRILLER AND FLOOR HAND DONNED SCBAS AND SECURED WELL - SIMULATED EMERGENCY SHUT DOWN OF RIG ENGINES SIMULATED NOTIFICATION OF SUPERINTENDANT AND MILNE PT. - SIMULATED WAKING UP OF CAMP INHABITANTS AND MUSTERING TO SAFE AREA. - DRILLER AND FLOORHAND REENTERED RIG AREA WHILE DONNING SCBAS AND SNIFFED FOR GAS, THEN ANNOUNCED AREA SAFE FOR REMAINDER OF CREW. - AAR: (1) TRUCK DRIVER WENT OFF LOCATION W/O SIGNING OFF, CH2MHILL NOTIFIED, WILL ADDRESS AT MEETINGS. - REMINDER THAT IT IS NOT ADVISED TO EVACUATE THROUGH MUD PITS, UNLESS AN SCBA IS DONNED. - CREW EVACUATED TO SAFE AREA IN UNDER 2 MINUTES. - DRILLER AND FLOORHAND (W/ SCBAS) TO SAFE AREA IN 5 MINUTES. 23:00 - 00:00 1.00 LCR P DECOMP PJSM. PREP TO SPOT AND BULLHEAD PILL. - LINE UP AND PUMP 200,000 LSRV FLO PRO PILL PUMP 35 BBLS @ 5 BPM / 870 PSI. BULLHEAD 45 BBLS, 4 BPM / 1250 PSI FINAL BULLHEAD PRESSURE 9/21/2010 100:00 - 00:30 0.50 LCR P DECOMP CHASE PILL OUT OF TUBING, LEAVE (5) BBLS IN. PUMPING BPM / 700 PSI. LOST 73 BBLS DURING BULLHEAD OPERATION. - LOSSES SLOWED TO LESS THAN 1 BPH AFTER PUMPING PILL. Printed 10/14/2010 11:34:13AM orth America -,AL - BP Page 4'at 2 JL Operation Summary Report = Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean S ea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 06:00 5.50 PULL P DECOMP POOH W/ 2 7/8" EUE 8 RND ESP COMPLETION STRING. - SPOOLING HEAT TRACE AND ESP CABLE. - CONTINUOUS HOLE FILL. - MEG HEAT TRACE CABLE TO VERIFY INTEGRITY, OK. -PUMP 10 BBLS DOWN TUBING TO CLEAR OF PILL. - CONTINUE TO POOH, STANDING BACK TUBING. 06:00 - 07:00 1.00 PULL P DECOMP SERVICE RIG PERFORM DERRICK INSPECTION. CHECK AND SET PVT ALARMS. SERVICE DRAWWORKS. PERFORM ENVIRONMENTAL WALK AROUND. 07:00 - 10:30 3.50 PULL P DECOMP CONTINUE TO POH W/ ESP COMPLETION STANDING BACK 2 7/8" TBG. LD LAST OF HEAT TRACE. SECURE HEAT TRACE ON SPOOL IN SPOOLING UNIT. CONTINUOUS HOLE FILL. LOSSES STILL LESS THAN 1 BPH. i 10:30 - 13:30 3.00 PULL P DECOMP CONTINUE TO POH W/ ESP COMPLETION STANDING BACK 2 7/8" TBG. CONTINUOUS HOLE FILL. LOSSES STILL LESS THAN 1 BPH. LD LAST 2 JTS ABOVE PUMP, BECAUSE OF SEVERE PITTING. - DISHCARGE HEAD AND ARMSTER GUARDS ALSO SHOW SIGNS OF SEVERE CORROSION. - FLAT GUARDS RECOVERED: 6'- 532 EA, 4' - 15 EA, 3'- 10 EA. - BANDS RECOVERED: 1651 -CLAMPS RECOVERED: 51 LASALLE, 4 PROTECTOLIZERS, 2 ARMSTER GUARDS. 13:30 16:00 2.50 PULL P DECOMP LD ESP PUMP AND MOTOR ASSEMBLIES. 16:00 - 18:00 2.00 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR. - REMOVE CLAMPS, FLAT GUARDS, AND CUT BANDS FROM RIG FLOOR. - CLEAN RIG FLOOR. - SLB REDRESSED GLMS. 18:00 18:30 0.50 PULL P DECOMP SERVICE RIG CHECK AND SET PVT ALARMS - SERVICE DRAWWORKS. PERFORM ENVIRONMENTAL WALK AROUNDS. 18:30 21:00 2.50 PULL P DECOMP RU TO RIH WI ESP COMPLETION. - LOAD ESP PUMP AND MOTOR ASSEMBLIES IN PIPE SHED. - RE- STRING ROPE THROUGH ELEPHANT TRUNK TO PULL ESP AND HEAT TRACE LINES. - PU CANNON CLAMPS AND BRING THEM TO THE RIG FLOOR. Printed 10/14/2010 11:34:13AM W orth- America - ALASKA - BP Pa of 8 Operation Summary Report Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 21:00 - 00:00 3.00 PULL P DECOMP PJSM FOR PICKING UP ESP COMPLETION VERIFY SIZE AND HORSE POWER OF THE ESP. - PU & MU MOTOR AND PUMP ASSEMBLY AS PER CENTRI PULL ESP OVER SHEAVE PREP RIG FLOOR TIH WITH ESP COMPLETION ON 2 -7/8" 6.5 # L -80 TUBING FROM THE DERRICK. - LOSS RATES STAYING AT — 1 BPH 9/22/2010 00:00 02:00 2.00 BOPSUR P RUNCMP SET TEST PLUG AND RU TEST EQUIPMENT - RE -TEST ANNULAR TO 250 LOW AND 3500 HIGH, GOOD TEST - RD TEST EQUIPMENT 02:00 - 03:00 1.00 RUNCOM P RUNCMP RIH WITH MADE UP MOTOR AND PUMP ASSEMBLY MU 10' PUPS AND XN, CENTRILIFT REP TO MEG TEST W/ ASSEMBLY IN FLUID MOTOR TEST "FAILED", SECOND MEG TEST UNIT WAS BROUGHT OUT TO VERIFY TEST, SECOND TEST FAILED. 03:00 - 04:00 1.00 RUNCOM N DFAL RUNCMP TOH WITH PUMP & MOTOR ASSEMBLY, REMOVED CLAMPS - RE- TESTED OUT OF WATER, MOTOR FAILED TEST PUMP WAS TESTED, TESTED "GOOD" 04:00 - 06:00 2.00 RUNCOM N DFAL RUNCMP BREAK OUT ASSYMBLY ABOVE MOTOR & SETBACK LD MOTOR TO PIPESHED WAIT ON CENTRILIFT FOR NEW MOTOR & GUAGE 06:00 - 07:00 1.00 RUNCOM N _ DFAL RUNCMP SERVICE RIG. PERFORM PRE -TOUR CHECKS. SET AND TEST PVT ALARMS. SERVICE DRAWWORKS. - DERRICK INSPECTION AND GREASE CROWN. STILL WAITING FOR CENTRILIFT TO BRING OUT NEW MOTOR AND SENSOR ASSEMBLY. 07:00 10:00 3.00 RUNCOM N DFAL RUNCMP PICK UP AND MAKE UP NEW ESP MOTOR RIH WITH MADE UP MOTOR AND POW ASSEMBLY - MU 10' PUPS AND XN, - CENTRILIFT REP TO MEG TEST W/ ASSEMBLY IN FLUID, ALL TESTS WERE GOOD 10:00 - 16:00 6.00 RUNCOM P RUNCMP RIH W ITH NEW ESP COMPLETIO RIH W/ ESP COMPLETION ON 2 -7/8" 6.5 # L -80 EUE TUBING FROM THE DERRICK TIH WITH 91 JNTS , — 2800' 16:00 17:30 1.50 RUNCOM P RUNCMP RIGGING UP HEAT TRACE TERMINATOR HOOK UP TERMINATOR 5' IN ON JNT # 91 TEST HEAT TRACE LINE & TERMINATOR, ALL TESTS GOOD BRINGING UP CLAMPS TO RIG FLOOR Printed 10/14/2010 11:34:13AM o►th America - ALASKA - BP Page 6 of 8 Operation Summary Report" Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: M PE -3 1: @56 .30ft (a Mean Sea Le Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 21:30 4.00 RUNCOM P RUNCMP RIH WITH ESP COMPLETION - RIH WITH (99) JOINTS, TO — 3038' - PINCHED HEAT TRACE IN THE CROSS COLLAR CLAMP, REMOVED ARMOR AND INSPECTED LEADS. - RE -TEST HEAT TRACE, MEG TEST- GOOD - OHM TEST FAILED, ALL THREE PHASES NOT EQUAL. 21:30 22:00 0.50 RUNCOM N DFAL RUNCMP DECISION WAS MADE TO TOH TO CHECK THE HEAT TRACE TERMINATOR - T OH & FOUND 4 PINCHED SPOTS ON JN 91 &'92. 22:00 00:00 2.00 RUNCOM N DFAL RUNCMP DECISION WAS MADE TO CUT BACK 150' TO THE LAST PINCHED POINT ON THE (HT) - CENTRILIFT NOTIFIED THEIR ENGINEER BRAD YINGST. CHANGED OUT THE TERMINATOR. RE- TESTED THE (HT) AFTER CUTTING BACK THE 150', TESTED GOOD - TESTED THE NEW TERMINATOR BEFORE MAKING THE SPLICE, TESTED GOOD - MADE THE HEAT TRACE SPLICE TO THE NEW TERMINATOR MONITORING HOLE DURING DOWN TIME, LOSSES STILL MAINTAINING @ LESS THAN 1 BPH 9/23/2010 00:00 - 01:30 1.50 RUNCOM N DFAL RUNCMP DECISION WAS MADE TO CUT BACK 150' TO THE LAST PINCHED POINT ON THE (HT) - CENTRILIFT NOTIFIED THEIR ENGINEER BRAD YINGST. CHANGED OUT THE TERMINATOR. RE- TESTED THE (HT) AFTER CUTTING BACK THE 150', TESTED GOOD - TESTED THE NEW TERMINATOR BEFORE MAKING THE SPLICE, TESTED GOOD - MADE THE HEAT TRACE SPLICE TO THE NEW TERMINATOR - MONITORING HOLE DURING DOWN TIME, LOSSES STILL MAINTAINING @ LESS THAN 1 BPH 01:30 - 02:30 1.00 RUNCOM N DFAL RUNCMP REMOVE TWIST IN THE HEAT TRACE LINE BEFORE PROCEDING SECURED HEAT TRACE AND TERMINATOR TO JNT # 93, — 3267 MD - HELD A SHORT MEETING TO DEVISE A PLAN TO PREVENT ANY MORE PINCHED HEAT TRACE CABLE. Printed 10/14/2010 11:34:13AM IVorfh America - ALASKA - BP Page 7 of s Operation Summary Report Common Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) P M il ne P Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 21:00 18.50 RUNCOM P RUNCMP -CONTINUED TO TIH WITH ESP COMPLETION & HEAT TRACE ON 2 -7/8" 6.5# EUE TUBING FROM THE DERRICK, 198 JNTS TOTAL. EQUIPMENT IN THE HOLE: -(3) PROTECTOLIZERS -(2) ARMSTER GUARDS -(6) PUMP CLAMPS -(2) S.S. BANDS -(93) 2' CROSS COLLAR ESP CANNON CLAMPS -(102) 2' DUAL CHANNEL CROSS COLLAR CANNON CLAMPS -(18) 2' MID JNT DUAL CHANNEL CANNON CLAMPS -(517) 5' MID JNT DUAL CHANNEL CANNON CLAMPS 21:00 - 22:00 1.00 RUNCOM P RUNCMP PU /MU LA NDING JOINT& TUBING HANGER -FMC CHANGED OUT HANGER SEAL FMC INSTALLED TWC ON THE RIG FLOOR. CENTRILIFT & FMC INSTALLED HEAT TRACE AND ESP CABLE PENETRATORS 22:00 - 00:00 2.00 RUNCOM P RUNCMP CENTRILIFT MAKING HANGER SPLICES FOR THE HEAT TRACE AND THE ESP CABLE HSE: - RIG CREW AND RIG LEADERSHIP TOOK THIS TIME TO WATCH THE DEEP WATER HORIZON VIDEO FOLLOWED BY AN HSE DISCUSSION AROUND THE 8 KEY FINDINGS AND HOW WE COULD RELATE THEM TO 4 ES OPERATIONS 9/24/2010 100:00 02:00 2.00 RUNCOM P RUNCMP CENTRILIFT MAKING HANGER SPLICES FOR THE HEAT TRACE AND THE ESP CABLE CENTRILIFT REPS MAKING PIG TAIL SPLICE ON HEAT TRACE & FIELD CONNECTOR SPLICE ON THE ESP - BOTH HEAT TRACE AND ESP CABLES OHM AND MEG TESTED, BOTH TESTED GOOD. HSE: - RIG CREW AND RIG LEADERSHIP TOOK THIS TIME TO WATCH THE DEEP WATER HORIZON VIDEO FOLLOWED BY AN HSE DISCUSSION AROUND THE 8 KEY FINDINGS AND HOW WE COULD RELATE THEM TO 4 ES OPERATIONS 02:00 03:00 1.00 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR - LD THIRD PARTY TOOLS FROM RIG FLOOR. - L AND 7- 1116" X 2 -7/8" ESP TBG HANGER - PUW 57 K, SOW 45 K - FMC REP RILDS , LAY DOWN 24' LANDING JNT. 03:00 04:30 1.50 RUNCOM P RUNCMP RU TEST EQUIPMENT TEST THE ALREADY INSTALLED TWC TEST TWC TO 3500 PSI FROM ABOVE AND A ROLLING TEST FROM BLEOW TO 500 PSI BOTH TESTS FOR 10 CHARTED MIN PUMPED @ 2.5 BPM TO GET 500 PSI PUMPED A TOTAL OF 49 BBLS FOR TEST. Printed 10/14/2010 11:34:13AM orth America - ALASKA - BP Page s of 8 Operation Summary Report Co mmon Well Name: MPE -31 AFE No Event Type: WORKOVER (WO) Start Date: 9/16/2010 End Date: X4- OORFJ -E (365,000.00 ) Project: Milne Point Site: M Pt E Pad Rig Name /No.: NABORS 4ES Spud Date/Time: 6/8/2005 12:00:OOAM Rig Release: 9/24/2010 Rig Contractor: NABORS ALASKA DRILLING INC. UWI: Active Datum: MPE -31: @56.30ft (above Mea Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:30 - 06:00 1.50 RUNCOM P RUNCMP N 13 -5/8" HYDRIL BOPE' 06:00 - 07:00 1.00 RUNCOM P RUNCMP PTSM: RIG SERVIEVCE AND PRE TOUR CHECKS, ENVIRO WALK AROUND 07:00 - 10:00 3.00 RUNCOM P RUNCMP CONT: ND 13 -5/8" HYDRIL BOPE'S 10:00 16:30 6.50 RUNCOM P RUNCMP NU 2- 9/16" TRE & TUBING HEAD ADAPTE - PT HANGER VOID TO 5000 FOR 15 MIN CHARTED PT TREE TO 5000 PSI FOR 15 CHARTED MIN CENTRILIFT MAKING FINAL CHECKS 16 30 - 18:00 1.50 RUNCOM P RUNCMP PU , MU & TEST LUBRICATRO - PT TO 250 PSI LOW AND 2000 PSI HIGH, FOR 5 MIN CHARTED - PULL TWC SET BPV & LID TOOLS PT BPV TO 500 PSI ROLLING TEST, AT 1 BPM. TOTAL OF 12 BBLS PUMPED RIG RELEASED @ 18:00 Printed 10/14/2010 11:34:13AM ~~, STATE OF ALASKA ALASK~IL AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS ~~s~ck~~3"s~~Lt°..9 t~~ om~,~; .'_ 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate0 Other ^ ~. Performed: Alter Casing ^ Pull Tubing^ Pertorate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Pertorate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Wetl Class Before Work: .Permit to Drill Number: Name: Development Q Exploratory 205-0720 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ .API Number: Anchorage, AK 99519-6612 50-029-23263-00-00 8. Property Designation ease Number) : 9. Well Name and Numbe ADLO-025518/ADL047438 MPE-31 10. Field/Pool(s): MILNE POINT FIELD / SCHRADER BLFF OIL POOL 11. Present Well Condition Summary: \ 9042 feet Total Depth measured Ptugs (measured) None feet true vertical 4368.16 feet Junk (measured) None feet Effective Depth measured 9042 feet Packer (measured) 6576 true vertical 4368 feet (true vertical) 4398 Casing Length Size MD TVD Burst Collapse Structural Conductor 78 20" SURFACE - 113 SURFACE - 113 1490 470 Surtace 3275 10-3/4" 45.5# L-80 SURFACE - 3310 SURFACE - 2669 5210 2480 Intermediate Production 6469 7-5/8" 29.7# L-80 SURFACE - 6502 SURFACE - 4384 6890 4790 Liner 2676 4-1/2" 12.6# L-80 6366 - 9042 4342 - 4368 8430 7500 Liner Pertoration depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 2-7/8" 6.5# L-80 SURFACE - 6257 SURFACE - 4301 Packers and SSSV (type, measured and true vertical depth) PAY ZONE ESP PKR 6576 4398 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: 164 6 17 192 Subsequent to operation: 229 10 15 184 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ 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: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 1/12/2010 Form 10-404 Revised 7/2009 ~DMS ~ Submit Original Only /-/~ /d ~ /~,~s MPE-31 205-072 DFRF ATTA(_HMFNT • • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPE-31 6/18/05 PER 6,649. 6,687. 4,404.31 4,407.27 MPE-31 6/18/05 PER 8,340. 8,377. 4,375.02 4,373.86 MPE-31 6/18/05 PER 8,408. 8,446. 4,373.35 4,373.31 MPE-31 6118/05 PER 8,478. 8,515. 4,373.42 4,373.59 MPE-31 6/18/05 PER 8,270. 8,308. 4,379.41 4,376.56 MPE-31 6/18/05 PER 8,547. 8,585. 4,373.51 4,372.51 MPE-31 6118/05 PER 8,685. 8,723. 4,368.31 4,366.96 MPE-31 6/18/05 PER 8,755. 8,792. 4,366.24 4,365.76 MPE-31 6/18/05 PER 8,824. 8,861. 4,365.73 4,366.2 MPE-31 6/18/05 PER 8,616. 8,654. 4,371.56 4,370.04 MPE-31 6/18/05 PER 7,980. 8,018. 4,398.65 4,396.61 MPE-31 6/18/05 PER 7,722. 7,759. 4,400.68 4,400.86 MPE-31 6/18/05 PER 7,653. 7,690. 4,401.02 4,400.66 MPE-31 6/18/05 PER 6,877. 6,914. 4,408.31 4,407.85 MPE-31 6/18/05 PER 6,946. 6,984. 4,407.6 4,407.36 MPE-31 6/18/05 PER 7,012. 7,050. 4,407.36 4,407.98 MPE-31 6/18/05 PER 7,082. 7,119. 4,408.75 4,409.9 MPE-31 6/18/05 PER 7,151. 7,189. 4,410.99 4,411.64 MPE-31 6/18/05 PER 7,221. 7,258. 4,411.81 4,411.61 MPE-31 6/18/05 PER 7,290. 7,327. 4,411.03 4,409.99 MPE-31 6/18/05 PER 7,514. 7,552. 4,405.27 4,403.75 MPE-31 6/18/05 PER 7,583. 7,621. 4,402.56 4,401.59 MPE-31 6/18105 PER 8,890. 8,928. 4,366.61 4,367.02 MPE-31 6/18/05 PER 8,959. 8,997. 4,367.34 4,367.71 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE MPE-31 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY AGTIVITYDATE SUMMARY 12/29/2009~T/I/0=300/200/340 Acid Treatment Pumped 15 bbls 130* diesel, 14 bbls 12% DAD ;Acid, 3 bbls 60/40 methanol & 23 bbls crude down Tbg. DSO notified swab wing jshut, ssv master is oa open. FWHP's= 300/400/340 , 12/30/20091T/I/0=900/180/180 Dispose of Acid Returns Manifest # 281279, 200996, 305855, 200915 Pumped 216 bbls returns down Tbg. Freeze protected surface lines w/4 bbls 60/40 methanol. DSO notified swab shut, wing ssv master is oa open. FW HP's=900/120/160 FLUIDS PUMPED BBLS 15 DIESEL 14 12% DAD ACID 3 60/40 METH 32 Total TREE: 2-9/16" - 5M FMC WELLHEAD: 11" x 2-9/16" 5M FMC Tub Hgr. Dual ported 11` x 2-7/8" 8rd T&8 2.5" CIW-H BPVT Conductor 112' KOP @ 200` Angle passes 50° @ 2300' Max Angle in Tbg = 67° @ 6200' Angle thru liner = 90+° 10 3/4" 45.5# L-80 BTC-M Csg. 3310` Orig. D~v. = 43.25 Doyon 14 Orig. GL v. = 10.80 Doyon 14 Camco 2-7/8" x 1" sidepocket KBMM GLM 142` Centrilift Heat Trace to 3368' 2 7/8" 6.5# EUE 8RD, L-80 tBG. Drift Id: 2.441"Capacity: 0.00579 7 5/8" 29.7 ppf, L-80, BTC-Mod casing (drift ID = 6.75", cap. = 0.0459 bpf ) (cap w/ 2 7/8" tbg inside = 0.0379 bpf) Note: 2 3/8" Discharge Head 7 518" float collar (PBTD) 6,416` 7 5/8" Weatherford float shoe 6,502` DATE EV. BY COMMENTS 06/29/05 MDO Drilled & Completed Doyon-14 02-17-08 JRP ESP Changeout (3S) 4.5" Baker packoff bushing 8,997' 4.5" Baker float shoe 9,042` - - Camco 2-7/8" x 1" 6032` sidepocket KBMM GLM 2-7/8" XN nipple 6182` ( No-Go ID 2.250" ) MS-1 Pressure Head 6205` 4283` TVD Pump, Model - PMSXD 1.7 TYPE 141 PS 6,207` Intake Gas Separator 6 223` 4001nternalsGRSl=rxARH6 Tandem Seal Section 8 228° GSB3DBFERHLSSCVH6 SB/SB PFSA GSB3DBFERHLSSCVH6 SB/SB PFSA , Motor, 76 HP, 1360 V, ' 34 amp, Model KMH 6 242 Phoenix MS-1 w/Centralizer 6,250` 4299' TVD Baker Tie Back Sleeve 6, 366` Baker 5 1/2" x 7 5/8" ZXP Liner Top Pkr 6,377` Baker 5 1/2" x 7 5/8" HMC Liner Hanger 6,384' Pay zone "ESP" Packer @ 6,576' 4" Baker C27, Medium Excluder Screens & 4" Blank Joints 4" 9.5#, L-80, IBT. Drift ID = 3.423" Capacity = 0.01223 bpf 6,649` - 8,997' MILNE POINT UNIT WELL MPE-31 API NO: 50-029-23263-00 BP EXPLORATION STATE OF ALASKA • yG~ C~`vE® AKA OIL AND GAS CONSERVATION COMMISSION ~~ REPORT OF SUNDRY WELL OPERATIONS MAR 1 7 2008 1. Operations Performed: 8 ^ Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-En~~~ed 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 205-072 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23263-00-00 " 7. KB Elevation (ft): 56 30' r 9• Well Name and Number: . .D~ MPE-31 8. Property Designation: 10. Field /Pool(s): ADL 047438 fJl~L ©C.~?SS/~ Milne Point Unit / Schrader Bluff 11. Present well condition summary Total depth: measured 9042 ' feet true vertical 4368 ° feet Plugs (measured) None Effective depth: measured 9042 feet Junk (measured) None true vertical 4368. feet Casing Length Size MD ND Surst Collapse Structural Conductor 78' 20" 113' 113' 1490 470 Surface 3275' 10-3/4" 3310' 2669' 5210 2480 Intermediate Production 6469' 7-5/8" 6502' 4384' 6890 4790 Liner 2676' 4-1l2" 6366' - 9042' 4342' - 4368' 8430 7500 ~Gs~~J APR ~ ~~ 2008 Perforation Depth MD (ft): Screens 6649' - 8997' Perforation Depth TVD (ft): Screens 4404' - 4368' Tubing Size (size, grade, and measured depth): 2-7/8", 6.5# L-80 6257' Packers and SSSV (type and measured depth): Pay Zone "ESP" Packer 6576' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 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 0 440 0 Subsequent to operation: 0 0 0 400 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 that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Donald Reeves, 564-4080 N/A Printed Name Sondra Stewman Title Drilling Technologist Prepared By NamelNumber: ignature Ph a 564-4750 Date ~ 3'~- Sondra Stewman, 564-4750 ion Form 10~evised 04~ ~~~'r~ r V ~~ f ~ / ~-,(' !''t~~~ ~~ ~ `~/ Submit Original Only TREE: 2-9/18" - 5M fMC ~ OI~DF Elev. = 43.25 Doyon 14 WELLHEAD: 11" x 2-9116" 5 G Geri 5 M P E -31 Orig. GL Elev. = 10.80 Doyon 14 2.5' CIW H gpV7 ed 11" x 2-718" 8rd T&B ~ ~T Conductor 112' KOP @ 200' Angle passes 50° @ 2300` Max Angle in Tbg = 67° @ 6200' Angle thru liner = 90+° 10 3/4" 45.5# L-80 BTC-M Csg. 331 O' Camco 2-7/8" x 1" sidepocket KBMM GLM 142` Centrilift Heat Trace to 3368' 2 7/8" 6.5# EUE 8RD, L-80 tBG. Drift 1d: 2.441"Capacity: 0.00579 7 5/8" 29.7 ppf, L-80, BTC-Mod casing ( drift ID = 6.75", cap. = 0.0459 bpf ) (cap w/ 2 718" tbg inside = 0.0379 bpf) Note: 2 3/8" Discharge Head 7 5/8" float collar (PBTD) 6,416` 7 5/8" Weatherford float shoe 6,502' 4.5" Baker packoff bushing 8,997` 4.5" Baker float shoe 9,042` °° °°^ ° - - DATE- EV. BY COMMENTS 06/29/05 MDO Drilled & Completed Doyon-14 02-17-08 JRP ESP Changeout (3S) Camco 2-7/8" x 1° 6032` I sidepocket KBMM GLM 2-7/8" XN nipple 6182` ( No-Go ID 2.250" ) MS-1 Pressure Head 6205` 4283` TVD Pump, ` Model - PMSXD 1.7 TYPE 141 PS 6,207 Intake Gas Separator 6 223` 400 Internals cRSFTx AR Hs Tandem Seal Section 228` 6 GS63DBFERHLSSCVH6 SB/SB PFSA GSB3DBFERHLSSCVH6 SB/SB PFSA , Motor, 76 HP, 1360 V, ` 34 amp, Model KMH 6 242 Phoenix MS-1 w/Centralizes 6,250` I 4299` TVD Baker Tie Back Sleeve 6, 366` Baker 5 1/2" x 7 5/8" ZXP Liner Top Pkr 6,377` Baker 5 1/2" x 7 5/8" HMC Liner Hanger 6 384` Pay zone "ESP" Packer @ 6,576` 4" Baker C27, Medium Excluder Screens & 4" Blank Joints 4" 9.5#, L-80, IBT. Drift ID = 3.423" Capacity = 0.01223 bpf 6,649` - 8,997' MILNE POINT UNIT WELL MPE-31 API NO: 50-029-23263-00 BP EXPLORATION • BP Operations Summary Report Page 1 of 4 Legal Well Name: MPE-31 Common Well Name: MPE-31 Spud Date: 6/8/2005 Event Name: WORKOVER Start: 2/11!2008 End: 2/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ~ Task Code I NPT I Phase Description of Operations 2/11/2008 121:00 - 00:00 3.001 RIGD P 2/12/2008 100:00 - 01:00 I 1.001 RIGD I P 01:00 - 01:30 0.50 RIGD P 01:30 - 02:00 0.50 MOB P 02:00 - 03:30 1.50 RIGU P 03:30 - 12:00 8.50 RIGU P 12:00 - 13:00 1.00 KILL P 13:00 - 15:00 2.00 KILL P 15:00 - 16:00 I 1.001 WHSUR I P 16:00 - 17:00 I 1.001 KILL I P 17:00 - 19:30 I 2.501 KILL I P 19:30 - 21:00 1.501 KILL ~ P 21:00 - 22:00 1.00 KILL P 22:00 - 23:30 1.50 KILL P 23:30 - 00:00 0.50 KILL P 2/13/2008 00:00 - 02:00 2.00 WHSUR P 02:00 - 04:00 I 2.001 WHSUR I P 04:00 - 06:00 2.00 WHSUR P 06:00 - 10:00 4.00 BOPSU P PRE Rig down from MPE-28, blow down steam and water lines,scope down and lay down derrick on to carrier. PRE Unhook lines and prep rig components for move, R/D hand-i berm. PRE PJSM held with truck crew. PRE Move pits and pipe shed and carrier off MPE-28 with pad operator present. PRE Lay matting boards and herculite on MPE-31 PRE Spot carrier over well (MPE-31) with pad operator present. Lay herculite and matting boards, hand-i berm, spot pipe shed and pits. Raise and scope the Derrick. Hook up steam lines. Spot and RU the Tiger Tank. RU hard line to the Tiger Tank. RU to the Tree for killling the well. DECOMP Hold pre-kill and pre-well safety meeting with the Wellsite Leader, Toolpusher and Crew. The Rig was accepted at 12:00 hrs on 2/12/2008. DECOMP Pressure test surface lines to 3,500 psi. Pressure test the hard line to the Tiger Tank to 500 psi. Bob Noble with the AOGCC waived the state's right to witness the BOPE test at 14:15 hrs on 2/12/2008. DECOMP PU Lubricator and RU to the Tree with Well Support Techs. Pressure test the Lubricator with diesel to 500 si - OK. Pull he BPV with the Lubricator. Tubing = 270 psi , IA = 450 psi , OA = 200 psi. LD the Lubricator. DECOMP Repair the Tubing and IA digital gauges on the Super Choke Panel to ensure proper pressure readings prior to initiating the well kill. DECOMP Communicate with Milne Point and Pad Operator of venting gas prior to well kill. Attempt to bleed pressure off the Tubing and found the flex hose on the Tiger Tank was frozen. Thaw out the hose. Pre-tour safety meeting with night crew. DECOMP PJSM with all involved personnel. Bleed tubing pressure to 0 psi. Line up and pump 35 bbls of 140 degree Seawater down tubing taking returns through the choke manifold to the tiger tank. 3 bpm with 140 psi pressure. Blow down lines to tiger tank. DECOMP Line up and bullhead 35 bbls of 140 degree seawater down the tubing 3 bpm with 240 psi. Monitor pressures. 0 psi on tubing. DECOMP Line up and pump 140 degree seawater down tubing taking returns through the choke to the tiger tank. Pumped 327 bbls of seawater. Clean seawater back to surface. Recovered 280 bbls of crude and seawater in tiger tank (Sent to MPU ORT). Lost 47 bbls of seawater. DECOMP Monitor well. No pressures. Tubing on a vac. DECOMP Blow down and remove lines. Install 2-1/2" CIW Type "H"' TWC. TWC was set by FMC wellhead tech. DECOMP Test TWC from below. Formation takin 2 b m with 200 si for 30 minutes. Test TWC from above to 3 500 si for 30 min tes. Chart both tests. DECOMP Bleed the void with FMC rep. N/D down Tree and Adapter Flange. Visually inspect the Hanger threads - OK. Hanger threads are 2-7/8" EUE 8rd. DECOMP PU the BOPE off the Cradle and NU the 13-5i8" 5K BOPE. Printed: 2/27/2008 2:56:50 PM • i BP Operations Summary Report Page 2 of 4 Legal Well Common W Event Nam Contractor Rig Name: Date Name: ell Name: e: Name: From - To MPE-31 MPE-31 WORKO NABOB NABOB Hours VER S ALAS S 3S Task ~ A DRI Code LING NPT Start I Rig Rig Phase Spud Date: 6/8/2005 : 2/11/2008 End: 2/17/2008 Release: 2/17/2008 Number: Description of Operations 2/13/2008 06:00 - 10:00 4.00 BOPSU P DECOMP Spot and RU the ESP Spooling Unit. 10:00 - 18:00 8.00 BOPSU C DECOMP Work on re-wiring the BOPE remote control panel on the Rig Floor to have the controls line up with the physical components exactly like they are on the Stack. Function test all components - OK. ~~y, 18:00 - 19:00 1.00 BOPSU P DECOMP C/O air boot for flow riser. 19:00 - 23:30 4.50 BOPSU P DECOMP Test BOPE choke manifold and floor valves to 250 psi low and 3,500 psi high. Each test was held for 5 minutes. Test Koomey. No failures. AOGCC witness of test was waived by Bob Noble. 23:30 - 00:00 0.50 BOPSU P DECOMP R/D test equipment. 2/14/2008 00:00 - 02:30 2.50 PULL P DECOMP Remove single ESP sheave from derrick, hang double ESP sheave in derrick to handle ESP and heat trace cables. Hang containment trunk on sheave and snake ropes through trunk. 02:30 - 04:00 1.50 WHSUR P DECOMP P/U Opso Lopso and screw into hanger. R/U lubricator and test to 500 psi. Pull TWC. 0 psi pressure below TWC. UD lubricator and Opso Lopso. 04:00 - 04:30 0.50 PULL P DECOMP M/U landing joint and screw into hanger. Back out lock down screws. Pull hanger to floor. Hanger came off seat at 55,000# up weight. Up weight of string 55,000#. 04:30 - 06:00 1.50 PULL P DECOMP Unhook ESP and heat trace cables, UD tubing hanger. Hole took 8 bbls to fill. Attach cables to rope to pull over sheave, through contaiment trunk to the spooler. 06:00 - 07:00 1.00 PULL P DECOMP Pre-tour checks and service the Rig. Check all equipment prior to POOH. 07:00 - 13:00 6.00 PULL P DECOMP POOH with existing ESP Completion on 2-7/8" EUE 8rd Tubing. standing back in the Derrick._ Spooling up the ESP and heat trace lines in the Spooling Unit. Maintaining continuous hole fill , while POOH. Losin a roximatel 10 b h. Lay down the first two GLM Assemblies due to being type TMPD and KBMMs are to be run in the well. 15 stands out of the hole at 11:00 hrs. 13:00 - 14:00 1.00 PULL P DECOMP Stop after laying down the second GLM Assembly to circ, ulate the well and clean/condition the well. 35 stands out of the hole. It took 6 bbls to get returns. Circulate at a rate of 2.5 bpm / 150 psi. Crude returns to surface r~ulate until clean rPttirnc observed. Pumped a total of 65 bbls of seawater. 14:00 - 19:30 5.50 PULL P DECOMP Resume POOH standing back the Tubing in the Derrick maintaining continuous hole fill. 19:30 - 23:00 3.50 PULL P DECOMP Cut cable and spool up. Clean, break down and lay down ESP assembly. Recovered 531- 6' Flat Guards, 16 - 4' Flat Guards, 10 - 3' Flat Guards, 6 - protectolizers, 3 - Armster Guards, 50 - LaSalle Clamps. 1- XN assembly, 3-GLM assemblies and 197- joints of 2-7/8" tbg. 23:00 - 00:00 1.00 PULL P DECOMP R/D containment trunk and return to storage box. Run ropes for pulling ESP and heat trace cables through sheave. 2!15!2008 00:00 - 01:00 1.00 BUNCO RUNCMP Clean rig floor, wait for loader from Milne Point Roads and Pads to handle ESP spool. 01:00 - 02:30 1.50 BUNCO RUNCMP Change out ESP spools in spooling unit. R/U tubing handling equipment for RIH. 02:30 - 07:00 4.50 BUNCO RUNCMP M/U and service ESP assembly. Attach cable and perform conductivity test with Centrilift reps. 07:00 - 13:00 6.00 BUNCO RUNCMP Notice a lot of scale buildup on the inner wall of the XN Nipple Assembly. Bang on the Pup Joints and recover a full 5 gallon bucket worth. Decision made to changeout the Assembly with Printed: 2/27/2008 2:56:50 PM ~J • gp Page 3 of 4 Operations Summary Report Legal Weli Name: MPE-31 Common Well Name: MPE-31 Spud Date: 6/8/2005 Event Name: WORKOVER Start: 2/11/2008 End: 2li7/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/17/2008 Rig Name: NABOBS 3S Rig Number: Date From - To Hours ' Task .Code NPT Phase I Description of Operations I - _ -_ 2/15/2008 07:00 - 13:00 6.00 BUNCO RUNCMP anew XN Nipple (ID = 2.25") and new 10' Pup Joints from the Pipe Shed. Break out and lay down the old XN Nipple Assembly. PU 3 ea 10' Pup Joints and 1 XN Nipple and MU each connection to 2,300 ft-Ibs. Crew change out and perform pre-tour checks (1st day back on the Slope)..Lay down the 1st stand in the hole due to heav scale built u on the ID of the Pipe. PU 2 new singles from the Derrick and MU to the string above the XN Nipple Assembly. Rattle the 2nd stand of Tubing and no scale observed falling out of the stand of Tubing. 13:00 - 16:30 3.50 BUNCO RUNCMP RIH with new ESP Com letion on 2-7/8", 6.5#, L-80, EUE 8rd Tubing from the Derrick. Maintaining continuous hole fill while RIH. MU torque = 2,300 ft-Ibs and utilizing Best-O-Life Pipe Dope on all connections. Stop every 2,000 ft to check the ESP and fill the Tubing with seawater. Flush the pump with 10 bbls of seawater at each stop at a rate of 0.5 bpm / 1,800 psi. 15 stands in the hole at 14:00 hrs. 30 stands in the hole at 15:30 hrs. 16:30 - 17:00 0.50 BUNCO RUNCMP Stop with 45 stands (90 Joints) in the hole to check the ESP and flush the pump with 10 bbls of seawater at 0.5 bpm / 1,850 psi. Pull the Heat Trace Cable over the Sheave. 17:00 - 00:00 7.00 BUNCO RUNCMP Continue RIH with ESP Completion on 2-7/8" Tubing from the Derrick. Begin running Heat Trace on Joint #91 to surface. Stop with 60 (120 Joints) stands in the hole to check the ESP and flush the pump with 10 bbls of seawater at 0.5 bpm / 1,850 psi. Hole is taking 6 bph while RIH. 2!16/2008 00:00 - 11:00 11.00 BUNCO RUNCMP Continue RIH with ESP Completion with Heat Trace on 2-7/8" Tubing from the Derrick. Use Best-O-Life pipe dope on connections. M/U torque = 2,300 fUlbs. Hole taking 6 bph while RIH. Ran a total of 198 Joints of 2-7/8", 6.5#, L-80, EUE 8rd Tubing along with an XN Nipple (ID = 2.250") Assembly and 2 KBMM GLM Assemblies (one with a DGLV and the other with a DPSOV). Ran 51 LaSalle Clamps, 4 Protectolizers, 2 Armster Guards, Heat trace Guards 532 each 6', 15 each 4', 10 each 3' and 1,651 bands. 11:00 - 12:00 1.00 BUNCO RUNCMP MU TIW and Headpin. Fill the Tubing and flush the ESP Pump with 10 bbls of seawater at a rate of 0.5 bpm / 1,850 psi. 12:00 - 13:00 1.00 BUNCO RUNCMP PU Landing Joint and MU Tubing Hanger (2-718 EUE 8rd threads) with FMC rep. Install ESP and Heat Trace Penetrators in the Hanger. PUW = 50,000K and SOW = 38,000K. 13:00 - 16:30 3.50 BUNCO RUNCMP Perform Penetrator splices on the ESP and Heat Trace cables with Centrilift reps. 16:30 - 17:30 1.00 BUNCO RUNCMP Land Tubing Hanger as per FMC wellhead tech. Run in lock down screws and torque to 450 fUlbs. 17:30 - 18:00 0.50 BUNCO RUNCMP Break out and UD landing joint. 18:00 - 21:00 3.00 WHSUR P RUNCMP Install CIW 2-1/2" TWC with FMC wellhead tech and test from above to 1,000 psi for 30 minutes. Test from below by pumping 1.5 bpm at 150 psi. 21:00 - 23:30 2.50 WHSUR P RUNCMP N/D BOPE, pull riser, remove hydraulic lines, remove kill and. choke lines. Lay BOP stack on moving cradle. N/D DSA. 23:30 - 00:00 0.50 WHSUR P RUNCMP P/U tree. 2/17/2008 00:00 - 01:30 1.50 WHSUR P RUNCMP N/U and orient tree. Pad operator verified orientation. 01:30 - 03:00 1.50 WHSUR P RUNCMP FMC wellhead tech tested tree void to 5,000 psi for 30 minutes Printed: 2/27/2008 2:56:50 PM • • gp Page 4 of 4 Operations Summary Report Legal Well Name: MPE-31 Common Well Name: MPE-31 Spud Date: 6/8/2005 Event Name: WORKOVER Start: 2/11/2008 End: 2/17/2008 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 2/17/2008 Rig Name: NASORS 3S Rig Number: Date From - To i Hours ~ Task i Code j NPT j Phase Description of Operations 2117/2008 01:30 - 03:00 1.50 WHSUR P RUNCMP as per procedure. Test tree body to 5,000 psi with diesel. Good test. 03:00 - 04:00 1.00 WHSUR P RUNCMP R/U lubricator and test to 500 psi. Pull CIW 2-1/2" TWC. R/D lubricator. 04:00 - 05:30 1.50 WHSUR P RUNCMP R/U Little Red and freeze rotect well. 05:30 - 06:00 0.50 WHSUR P RUNCMP RU Lubricator with Well Support Techs. Pressure test to 500 psi with diesel. Set 2-1/2" CIW Type "H" BPV. LD Lubricator. Perform final ESP Conductivity checks with Centrilift reps: phase to phase = 2.8 ohms, phase to phase (heat trace) = 3.8 ohms, phase to ground = 1.8 Gigaohms, phase to ground (heat trace) = 11 Gigaohms, pressure at intake = 1,896 psi , temperature at intake = 97.6 degreesF, temperature at motor = 98.2 degreesF. The Rig was released at 06:00 hrs on 2/17/2008. Printed: 2/27/2008 2:56:50 PM STATE OF A~.ASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION ROPE Test Report Submit to: j3~~~_r;~~c~~~~i~~fa:~.c~c~v ~o~ t4cei;v~~st~ir~'r?i ,~ ; ,,,, Contractor: Nabors Rig No.: 3S DATE: 2/13/2008 Rig Rep.: J Frittsl E. Potter Rig Phone: 659-4487 Rig Fax: 659- 4486 Operator: BP Op. Phone: 659- 4485 Op. Fax: 659-4628 Rep.: W. Hoffman/ B. Burson Field/Unit & Well No.: MPU E~1 PTD # 205-072 Operation: Drlg: Workover: X Explor.: Test: Initial: X~____,-__~ Weekly: ~ _ _ - Bi-Weekly ._ Test Pressure: Rams: 250!3504 Annular. 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: Test Result Test Result Location Gen.; P Well Sign P Housekeeping: P Drf. Rig P PTD On Location P Hazard Sec. P Standing Order Posted P BOP STACK: Quantity Size Test Result Annular Preventer 1 i 3 518 5fl00 P Pipe Rams 1 2 7/8 P Lower Pipe Rams Blind Rams 1 Blind P Choke Ln. Valves 1 31/8" 5000 P HCR Valves 2 3 1/8" 5000 P Kill Line Valves 1 2 1/16" 5000 P Check Valve 0 NA MUD SYSTEM: Visual 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 FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 ]VT Lower Kelly 1 NT Sall Type 1 P Inside BOP 1 P CHOKE MANIFOLD: Quan#ity Test Result No. Vabes 13 P Manual Chokes 1 P Hydraulic Ghokes 1 P ACCUMULATOR SYSTEM: Time/Pressure lest Result System Pressure 3000 P Pressure After Closure 1450 P 200 psi Attained 35 sec P Full Pressure Attained 2 min 50 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg}: 4 c~D1925 Number of Failures: 0 Test Time: 4,i5 Hours Components tested ALL Repair or replacement of equipment wilt be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: ,C,'sp~rl^~ P~~;r~~l~~~~~,.ic~v Remarks: 24 HOUR NOTICE YES X NO Date 02/11/08 Time 1700 hrs start 1930 firs Finish BOP Test (for rigs) ~ ~~B ~. ~ ZOa~ BFL 11/14/07 By Bob Noble Witness Biti BursonlEverett Potter Nabors 3S BOP Test MP E-31 2-13-08.x1s Permit to Drill 2050720 MD ../ 9042 REQUIRED INFORMATION )./ J~k DATA SUBMITTAL COMPliANCE REPORT 7/2/2007 TVD Well Name/No. MILNE PT UNIT SB MPU E-31 4368 / Completion Date 6/21/2005/" Mud Log No DATA INFORMATION Types Electric or Other Logs Run: GYRO, MWD, GR, DIR, IFRlCASANDRA Well Log Information: Log/ Data Digital Type Med/Frmt ~ ------0 Asc ~DAsc ~ 4' ED D TIF 1/ ¿ C Las ~ C Lis ~ C Lis Electr Dataset Number Name Directional Survey Directional Survey LIS Verification 14103 LIS Verification 14103 Induction/Resistivity 14103 Induction/Resistivity 15020 Induction/Resistivity 15021 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Operator BP EXPLORATION (ALASKA) INC Completion Status 1-01L Current Status 1-01L Samples No 'fi'u ~ ,J ~~, \- API No. 50-029-23263-00-00 UIC N Directional sUr:'~~es ~ (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval Start Stop 7992 12787 7992 8810 72 9042 1-4 1-3 1-3 72 8810 72 8810 72 8717 72 8717 72 8717 OH/ CH Received Open 7/29/2005 Open 7/29/2005 6/8/2006 6/8/2006 6/8/2006 Open 8/30/2006 Open 4/17/2007 Open 4/17/2007 Sent Received Sample Set Number Comments - Comments PB1 Disk for this was Bad. 16- May-2006 PB1 16-May-2006 GR EWR ABI CNP SLD ROP PB1 16-May-2006 GR, ROP, FET, RHOB, NPHI (Data sent back due to corruption) LIS Veri, GR, ROP, FET, DRHO, RHOB, NCNT, NPHI, FCNT w/Graphics CGM, EMF, PDF PB1 LIS Veri, GR, ROP, FET, DRHO, RHOB, NCNT, NPHI, w/Graphics CGM, EMF, PDF e Permit to Drill 2050720 MD 9042 TVD 4368 ADDITIONAL INFORMATION Well Cored? @ Chips Received? ~ Analysis Received? ð- Comments: -- Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 7/2/2007 Well Name/No. MILNE PT UNIT SB MPU E-31 Operator BP EXPLORATION (ALASKA) INC Completion Date 6/21/2005 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? øN ~/N Formation Tops '~ Date: API No. 50-029-23263-00-00 J {J,,~ M-ö7 - e K I::.lA:: I v t:: u I STATE OF ALASKA I ALAS A Oil AND GAS CONSERVATION COM ~~O~ 0 2007 REPORT OF SUNDRY WELL qfti~l'tQN&s. Commission 1. Operations Abandon D Repair Well D Plug Perforations D Stimulate Onchorage Other 0 ACID TREATMENT Performed: Alter Casing D Pull Tubing D Perforate New Pool D Waiver D Time Extension D Change Approved Program D Opera!. Shutdown D Perforate D Re-enter Suspended Well D 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P Exploratory 205-0720 ~ 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-23263-00-00/ 7. KB Elevation (ft): 9. Well Name and Number: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 14 1 0 14 1 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil P Gas WAG 56.3 ES / A A./ JV~d' ajQ.~"'.J),p1 ADLO-025518 ~,t)L.Ot?4?.pjr 11. Present Well Condition Summary: '/- 8. Property Designation: Total Depth measured 9042 , feet true vertical 4368.16 / feet Effective Depth measured 9042 ; feet true vertical 4368 / feet Casing Length Size MD Conductor 78' 20" 92# H-40 35' - 113' Surface 3276' 10-3/4" 45.5# L-80 34' - 3310' Production 6469' 7-5/8" 29.7# L-80 33' - 6502' Liner 2676' 4-1/2"x4" 12.6#x9.5# L· 6366' - 9042' Perforation depth: Measured depth: 6649 - 8997 True Vertical depth: 4404 - 4368 - - Tubing: (size, grade, and measured depth) 2-7/8" 6.5# Packers and SSSV (type and measured depth) NIA o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations OiI-Bbl 185 186 x 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble P,;nlod Nam, Ga", P,abJe /J -/ / Signature ~..-? ~ Fonn :;:-L04t2006 RIG I N A L ~ ~-J'Þt?;I j,'f../?' MPE-31 / 10. Field/Pool(s): MILNE POINT Field/ SCHRADER BLFF OIL Pool Plugs (measured) None Junk (measured) None TVD Burst Collapse 35' - 113' 34' - 2669' 5210 2480 33' - 4384' 6890 4790 4354' - 4368' 8430 7500 - - L-80 Surface - 6257' o o o o Tubing pressure 180 188 Service GINJ WINJ WDSPl SUndry Number or NIA if C.O. Exempt: Title Data Management Engineer Phone 564-4944 Date 5/25/2007 RBDMS 8Ft .lUN 1 1 2007 Submit Original Only tit e . . MPE-15 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY (Acid treatment). Spear into tbg w/ 10 bbls crude for injectivity test. Pump 10 bbls 12% DAD acid followed by 3 bbls 60/40 meth & 28 bbls crude to spot acid at ESP. Turn well over to DSO to run pump forward & backward. FWHP=250/300/290. 5/1 90/440. (Acid returns). Pump 273 bbls acid returns down MPB-50 disposal. FWHP=900/190/440 FLUIDS PUMPED BBLS 10 12% DAD 3 60/40 METH 38 CRUDE 51 TOTAL - -- WELL LOG TR~NSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Avenue, Suite 100 Anchorage, Alaska 99501 April 13,2007 RE: MWDFonnationEvaluationLogs: MPE-31 &MPE-31 PB1, AK.-MW-3753911 MPE-3I & MPE-3I PBI: Digital Log Images: 50-029-23263-00, 70 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATTACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Artn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. .R'" ><. E·..· -.' .. ". An.._. c.' bor~...... e.' Alaska 99508 . '. CEIVEu Date: APR 1 7 Z007 Signed: ~ 0/1 & Gas Cons. COOlmission Anchorage Œ.1L-----· dO~-O-:;'d fi: I 5"0;)0 ~ [~O&i . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Christine Mahnken 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 907 -793-1005 August 28, 2006 RE: MWD Formation Evaluation Logs: lE-104, CD3-302 PB1, 05-20B, 15-46 Ll PB1, MPK-09, MPE-31, MPC-43, MPE-25A. 1E-104 ';104- Q'J":) ,~o,5'L( CD3-302 PB1 'Ðö<o- 010 1l./lOI 05-20Bv Qol..l-~4 14D4'\ 15-46 L1 PB1 JoL(-ID3 /l./lvO MPK-09 Qöt)- 0/<'[ 1"-//01.:{ MPE-31 'dOS-- Ord-,LI'D3 MPC-43 804- 03£1 t~ 10d MPE-25A U Ie.. Gol.( - 045" I g6"bi.{ Digital LIS DATA: 1 CD Rom 50-029-23234-00, 50-103-20522-70, 50-029-22137-02, 50-029-22665-70, 50-029-23247-00, 50-029-23263-00, 50-029-23200-00, 50-029-22980-01. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITT AL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petroteclmical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 15j:~o/~ Signed: G.Ø- . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 17,2006 RE: MWD Formation Evaluation Logs MPE-31 PB1, AK-MW-3753911 1 LIS formatted Disc with verification listing. API#: 50-029-23263-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COPY OF THE TRANSMIITAL LEITER TO THE A TIENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Date: Signed: 0-J.k--- RECEIVED ~.IUN 0 8 Z006 !\Iaaka Oil & Gas Cons. eommIS&Ion AndJOrage t)D~-Ot-d +t jl..li£>.? . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 May 17,2006 RE: MWD Formation Evaluation Logs MPE-31, AK-MW-3753911 1 LIS formatted Disc with verification listing. API#: 50-029-23263-00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMIITAL LEITER TO THE A ITENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 Rt;.CE\VED dU~l 0 8 2006 ~ Oil & Gas Cons. eommlssion Ancl'iorcŠge Signed: c..JJk- J 06-- (j};) l L{( ó'3 .. STATE OF ALASKA . ALASKA~ AND GAS CONSERVATION COMrJllll!!rSION¡:?'~:': ¡i ~\ ,'f..q WELL COMPLETION OR RECOMPLETION REPORT AND LOcf" A I... Wi :~ .~\Jlt5 Revision: 08J15/05, Start Production " 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3960' FSL, 2014' FEL, SEC. 25, T13N, R10E, UM Top of Productive Horizon: 3683' FSL, 3802' FEL, SEC. 19, T13N, R11E, UM Total Depth: 3998' FSL, 3780' FEL, SEC. 19, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x-~691~ y- 6016497 Zone- ASP4 TPI: x- 572512 y- 6021532 Zone- ASP4 Total Depth: x- 572529 y- 6021847 Zone- ASP4 18. Directional Survey 0 Yes 181 No 21. Logs Run: GYRO, MWD , GR , DIR , IFRlCASANDRA One Other 5. Date Comp., Susp., or Aband. 6/21/2005 6. Date Spudded 6/9/2005 7. Date T.D. Reached 6/17/2005 8. KB Elevation (ft): 56.30' 9. Plug Back Depth (MD+ TVD) 9042 + 4368 10. Total Depth (MD+TVD) 9042 + 4368 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL CASING SIZE 20" 10-3/4" 7-5/8" 4-1/2" x 4" GRADE H-40 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE lOP BOTTOM Top BOTTOM SIZE 35' 113' 35' 113' 42" 35' 3310' 35' 2669' 13-1/2" 33' 6502' 33' 4384' 9-7/8" 6366' 9042' 4354' 4368' 6-3/4" 22. wt. PER FT. 92# 45.5# 29.7# 12.6# x 9.5# 23. Perforations open to Production (MD + TVD of T<æ and Bottom Interval, Size and Number; if none, state none"): 4-1/2" x 4" Excluder Screens MD TVD MD 6649' - 8997' 4404' - 4368' 26. Date First Production: July 14, 2005 Date of Test Hours Tested PRODUCTION FOR 7/16/2005 6 TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED -.a... Press. 24-HoUR RATE"'" 24. SIZE 2-7/8",6.5#, L-80 TVD 25. .C'.H ~ c " f~ ,q'" ?".8a v.vèroa~:,,·o.h.. 181 Devel~èHP~EJ Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 205-072 13. API Number 50- 029-23263-00-00 14. Well Name and Number: MPE-31 15. Field / Pool(s): Milne Point Unit / Schrader Bluff Ft 16. Property Designation: Ft ADL 047438 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PUllED 260 sx Arctic Set (Approx.) 470 sx Arcticset Lite, 475 sx 'G' 449 sx Class 'G' Excluder Screen Liner TUBING DEPTH SET (MD) 6257' PACKER SET (MD) N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump Oll-BBl GAs-McF WATER-BBl 249 29 0 Oll-BBl 995 GAs-McF 116 WATER-BBl o I GAS-Oil RATIO 117 Oil GRAVITy-API (CORR) CHOKE SIZE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE RBDMS 8Fl AUG ,2 3 2005 , 28. , ,. e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". MA MB1 MB2 NA NB NC NE NE ND TOP OF NE TOP OF ND 5728' 5740' 5903' 6405' 6365' 6585' 7905' 8227' 8704' 8630' 8726' 4088' 4093' 4165' 4356' 4342' 4399' 4401' 4383' 4368' 4371' 4367' None 30. List of Attachments: 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _Title Technical Assistant Date Dß'-\S-OS - MPE-31 Well Number Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 David Johnson, 564-4171 205-072 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only ALASKA. AND ~ÄAST~g~S~L:;::iON COMAtION Reef: IVED WELL COMPLETION OR RECOMPLETION REPORT AND LOG JUL 2 ì 2005 Alaska Oil & Gas Cons. CorrlfTlission 1 b. Well ~íYf:11or8ne.. IBI Development D Exploratory o Stratigraphic 0 Service 12. Permit to Drill Number 205-072 13. API Number 50- 029-23263-00-00 14. Well Name and Number: 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3960' FSL, 2014' FEL, SEC. 25, T13N, R10E, UM Top of Productive Horizon: 3683' FSL, 3802' FEL, SEC. 19, T13N, R11E, UM Total Depth: 3998' FSL, 3780' FEL, SEC. 19, T13N, R11E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569129,- y- 6016497" Zone- ASP4 TPI: x- 572512 y- 6021532 Zone- ASP4 Total Depth: x- 572529 y- 6021847 Zone- ASP4 18. Directional Survey IBI Yes 0 No 21. Logs Run: GYRO, MWD , GR , DIR , IFRlCASANDRA One Other 5. Date Comp., Susp., or Aband. 6/21/2005 ./ 6. Date Spudded 6/9/2005 7. Date T.D. Reached 6/17/2005 / 8. KB Elevation (ft): 56.30' 9. Plug Back Depth (MD+ TVD) 9042 + 4368 Ft 10. Total Depth (MD+.TVD) ./ / 9042 + 4368 Ft 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 20" 10-3/4" 7-5/8" 4-1/2" x 4" WT;PER FT. 92# 45.5# 29.7# 12.6# x 9.5# GRADE H-40 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTHMI'> SETTING DEPTHTVD HOLE lOP BOTTOM Top BOTToM SIZE 35' 113' 35' 113' 42" 35' 3310' 35' 2669' 13-1/2" 33' 6502' 33' 4384' 9-7/8" 6366' 9042' 4354' 4368' 6-3/4" 22. 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 4-1/2" x 4 " Excluder Screens MD TVD MD 6649' - 8997' 4404' - 4368' 26. Date First Production: Not on Production Date of Test Hours Tested PRODUCTION FOR TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE MPE-31 15. Field I Pool(s): Milne Point Unit / Schrader Bluff 16. Property Designation: ADL 047438 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) AMOUNT PUllED 260 sx Arctic Set (Approx.) 470 sx Arcticset Lite, 475 sx 'G' 449 sx Class 'G' Excluder Screen Liner 24. SIZE 2-7/8", 6.5#, L-80 TVD TUBING DEPTH SET (MD) 6257' PACKER SET (MD) N/A DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze Protected with 80 Bbls of Crude PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): N/A Oll-BBl GAs-McF WATER-Bsl CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". rcé¡f,;i;L~ËiTOfn [~~<r¿ 1', ç,.. . Z ¡. óç¡ \I~':¡:"""nJ. ' ",-"" . ,-, I... ' , ¡ :- ). ---:/ "'-'_·"~"""P'''''_'_''_·''· Oll-Bsl 27. None RBDMS 8Ft ,JUl 25 2005 Form 10-407 Revised 12/2003 GAs-McF W A TER-BSl Oh~' \ . 1\ l H~ ,l\ L CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-Oil RATIO Oil GRAVITY-API (CORR) Gf 28. . GEOLOGIC MARKERS 29. .RMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". MA MB1 MB2 NA NB NC NE NE ND TOP OF NE TOP OF ND 5728' 5740' 5903' 6405' 6365' 6585' 7905' 8227' 8704' 8630' 8726' 4088' 4093' 4165' 4356' 4342' 4399' 4401' 4383' 4368' 4371' 4367' None . 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Leak-Off Test Summary and Well Service Report. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Sondra ~wman ~ MPE-31 Well Number Date 0 rz - 2.. ¡ -()Ç 205-072 Permit No. I Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 David Johnson, 564-4171 ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only TREE: 2-9116" - 5M FMC . WELLHEAD: 11" x 2-9116" 5M . en 5 Tub Hgr. Dual ported 11" x 2-7 . dt&B 2.5" CIW-H BPVT Conductor ~. KOP @ 200' Angle passes 50° @ 2300' Max Angle in Tbg = 67' @ 6200' Angle thru liner = 90+0 10314" 45.5# L-80 BTC-M Csg. I 3310' I . 27/S" 6.5# EUE 8RD, L-80 tBG. Drift Id: 2.441" Capacity: 0.00579 7 5/8" 29.7 ppf, L-SO, BTC-Mod casing ( drift ID = 6.75", cap. = 0.0459 bpf) (cap wI 2 7/8" tbg inside = 0.0379 bpf) MPE-31 Or~ Elev. = 43.25 boyon 14 or.. Elev. = 10.S0 Doyqn 14 Camco 2-7/S" x 1" sidepocket TMPD GLM I 144' 1 Cameo 2-7/S" x 1" sidepocket TMPO GLM 12204' 1 Cameo 2-7/S" x 1" 16031' I sidepoeket KBMM GLM 2-7/S" XN nipple 16179' I ( No-Go ID 2.250") Pump, 16 Stg. GCNPSH, I 6,201'1 85 Stg. GC1150 Model - GPMT AR 1: 1 Intake Gas Separator 16,220'1 400 Internals GRSFTX AR H6 Tandem Seal Section 16,225'1 GSB3DBUT ABIHSN PFSA GSB3DBL T ABIHSN FSA Motor, 133 HP, 2205 V, 16,238'1 37 amp, Model KMH PumpMate wlCentralizer 1 6,257' I 6,416' 1 I'.'.'.'. I ::::~ :i~I:'~:~ ~:~v;XP Liner Top Pkr 666',,333 6874~: '. Baker 5112" x 7 518" HMC Liner Hanger 1 6,502'1 ~.,. ........... ... . .... ~~,;~;.;:¡:¡~~?) Pay zone "ESP" Packer @ 6,576' 7 5/8" float collar (PBTD) 7 5/8" Weatherford float shoe 4.5" Baker packoff bushing 18,997' 1 4.5" Baker float shoe / 19,042' I DATE REV. BY COMMENTS Orilled & Completed Ooyon-14 06/29/05 MDO 4" Baker C27, Medium Excluder Screens & 4" Blank Joints 4" 9.5#, L-80, IBT. Drift ID = 3.423" Capacity = 0.01223 bpf 6,649' - S,997' MILNE POINT UNIT WELL MPE-31 API NO: 50-029-23263-00 BP EXPLORATION (AK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-31 MPE-31 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 6/8/2005 6/21/2005 Spud Date: 6/8/2005 End: 6/8/2005 10:00 - 10:30 0.50 MOB P PRE PJSM - Skid rig floor from drlg position to move position 10:30 - 11 :30 1.00 MOB P PRE Back rig off MPE-12 - Spot in center of Pad 11 :30 - 12:00 0.50 MOB P PRE Transfer matting boards around rig 12:00 - 13:00 1.00 MOB P PRE PJSM - Move rig and spot over well MPE-31 13:00 - 14:00 1.00 RIGU P PRE PJSM - Skid rig floor from move position to drlg position - Rig up - Spot rock washer - Berm same (Accept rig 14:00 hrs) 14:00 - 17:00 3.00 RIGU P PRE PJSM - Nipple up Divertor system - Riser - Flow line - Inspect derrick - Load pipe shed with 4" DP 17:00 - 22:00 5.00 DRILL P SURF PU 165 joints 4" drill pipe from pipe shed - Stand back in derrick - While mixing spud mud 22:00 - 23:00 1.00 DRILL P SURF CO handling equipment - PU / rack back 2 stands 5" HWDP and jars 23:00 - 23:30 0.50 EVAL P SURF Function test Divertor - Perform accumulator test - Witnessed by WSL - Chuck Scheve With AOGCC waived witness of Divertor function test 23:30 - 00:00 0.50 DRILL P SURF Con't PU / rack back 5" HWDP 6/9/2005 00:00 - 01 :00 1.00 DRILL P SURF Moblize BHA to rig floor 01 :00 - 03:00 2.00 DRILL P SURF MU BHA - Bit - motor - MWD - Orient UBHO - XO 03:00 - 03:30 0.50 DRILL P SURF PJSM - Hang Gyro Sheave 03:30 - 04:00 0.50 DRILL P SURF Pre Spud Meeting with all rig and contract personnel 04:00 - 04:30 0.50 DRILL P SURF Prime pumps - Fill riser - Check for surface leaks 04:30 - 05:00 0.50 DRILL P SURF Drill 13 1/2" surface hole from 114' to 167' 05:00 - 06:00 1.00 DRILL P SURF POH - Pick up Flex DC's 06:00 - 07:00 1.00 DRILL N SFAL SURF Wait on parts for Gyro E-line unit - Repair same 07:00 - 00:00 17.00 DRILL P SURF Directional Drill from 165' to 1370' - WOB 10 to 30 - RPM 80 - TO on 3 - off 2 - GPM 445 - PP on 1570 - off 1330 - PU 102- SO 93 - ROT 95 6/10/2005 00:00 - 07:00 7.00 DRILL P SURF Directional Drill from 1370' to 2053' - WOB 10 to 30 - RPM 80- TO on 5 - off 2 - GPM 502 - PP on 2130 - off 2000 - PU 105- SO 90 - ROT 99 07:00 - 08:00 1.00 DRILL P SURF CBU - GPM 500 - RPM 80 - PP 2000 08:00 - 09:00 1.00 DRILL P SURF Pump out to HWT - GPM 500 09:00 - 09:30 0.50 DRILL P SURF RIH - Precauctionary wash last stand to bottom 09:30 - 17:30 8.00 DRILL P SURF Directional Drill from 2053' to 3320' - TD 13 1/2" surface hole- WOB 10 to 15 - RPM - TO on 5 - off 4 - GPM 550 - PP on 2760 - off 2620 - PU 115 - SO 85 - ROT 100 17:30 - 19:00 1.50 CASE P SURF CBU 2 X - GPM 550 - PP 2480 19:00 - 21 :30 2.50 CASE P SURF Pump out from 3320' to HWT 711' - GPM 500 - PP 2200 21 :30 - 22:30 1.00 CASE P SURF RIH from 711' to 3225' - Precauctionary wash to bottom from 3225' to 3320' 22:30 - 00:00 1.50 CASE P SURF CBU 3 X - GPM 550 - PP 2400 6/11/2005 00:00 - 01 :00 1.00 CASE P SURF CBU 3 X - GPM 550 - PP 2370 - Flow check - Well static 01 :00 - 03:30 2.50 CASE P SURF Pump out from 3320' to HWT 711' - Pump at 500 GPM 03:30 - 04:00 0.50 CASE P SURF Stand back 5" HWT - Jars 04:00 - 06:00 2.00 CASE P SURF LD Flex DC's - MWD - BHA 06:00 - 06:30 0.50 CASE P SURF Clear rig floor 06:30 - 08:00 1.50 CASE P SURF RU casg tools to run 10 3/4" casg 08:00 - 11 :30 3.50 CASE P SURF PU I Run I Land - 103/4" L-80 45.5# BTC-M casg to 3310' -79 joints 11 :30 - 12:00 0.50 CASE P SURF RD frank's tool - RU Schlumberger cementing head I lines 12:00 - 14:00 2.00 CASE P SURF Circulate 2 casg volumes - Staging up pumps from 2 bpm to 6 bpm - ICP - FCP 14:00 - 16:30 2.50 CEMT P SURF Give to Schlumberger Printed: 6/27/2005 11:13:36AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-31 MPE-31 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/8/2005 Rig Release: 6/21/2005 Rig Number: Spud Date: 6/8/2005 End: 6/11/2005 14:00 - 16:30 2.50 CEMT P SURF Pump 5 bbls fresh water Test Lines to 2500 psi Pump 20 bbls CW 100 chemical wash 8.3 ppg - (one gallon dye in first 5 bbls slurry pumped) Pump 50 bbls of 10.3 ppg Mud Push Drop Bottom plug Mix and pump 470 sxs - Type 'ASL' - Yield 4.42 cf/sx - 370 bbls 10.7 ppg cement Mix and pump 475 sxs - Class 'G' - Yield 1.17 cf/sx - 99 bbls 15.8 ppg cement Drop top plug Kick out with 30 bbls water through tub Give to rig 16:30 - 17:30 1.00 CASE P SURF Displace with 280 bbls mud - Bump plug with 1000 over circulation pressure @ 1700 psi - Held 2 mins - Bleed pressure off - Floats holding - 240 bbls good cement back to surface 17:30 - 19:00 1.50 CASE P SURF RD cementing head I lines - Flush divertor system - Flow line - Lay down landing joint - Rig down casg tools 19:00 - 20:00 1.00 CASE N RREP SURF Change out # 2 Generator breaker 20:00 - 21 :00 1.00 CASE P SURF Con't RD casg equipment - tongs - Bales - Spiders - clear off floor 21 :00 - 22:00 1.00 CASE P SURF ND Divertor system 22:00 - 22:30 0.50 CASE P SURF Install FMC Casing head 12" M to M seal - Tubing head - Test to 1000 psi for 10 mins 22:30 - 00:00 1.50 CASE P SURF NU BOP's - Riser 6/12/2005 00:00 - 01 :30 1.50 CASE P SURF NU BOP's - Riser - Install Test plug - Open annulus valves 01 :30 - 02:00 0.50 CASE P SURF Rig up test equipment - Install Test plug - Open annulus valves 02:00 - 06:30 4.50 CASE P SURF Testing BOP's - Annular 250 low - 2500 high 5 mins each test - VBR rams - Choke manifold - HCR Kill/ Choke valves - Manual Kill I Choke valves - Upper / Lower IBOP - Floor Safety valves -(Dart valve failed) - 250 Low 3500 High 5 mins each test. Replaced dart valve and test successful. Right to witness test waived by AOGCC Inspector, Chuck Scheve. 06:30 - 07:00 0.50 CASE P SURF Rig down testing equip - Pull test plug - Install wear ring - Close annulus valves 07:00 - 09:30 2.50 CASE P SURF MU BHA - Surface test MWD - GPM 450 - PP 1040 09:30 - 10:00 0.50 CASE P SURF RIH from 715' to 3110' 10:00 - 11 :00 1.00 CASE P SURF Cut drlg line - Rig service - Top drive service 11 :00 - 11 :30 0.50 CASE P SURF CBU 1 X - GPM 425 - PP 1500 - RPM 35 - TQ 5K 11 :30 - 13:00 1.50 CASE P SURF RU testing equipment - Test casg to 1000 psi for 30 mins - Record on chart - RD testing equipment 13:00 - 14:30 1.50 DRILL P SURF Drill Float equipment - Clean out rat hole - Drill 20' new hole to 3340' - GPM 400 - PP 1340 - RPM 60 14:30 - 15:30 1.00 CASE P SURF CBU - Pump sweep - C/O mud to LSND - Level out mud weight to 9.1 ppg 15:30 - 16:30 1.00 EVAL P SURF RU test equipment - Preform FIT - Mud weight 9.1 - MD 3310- TVD 2669 - Surface pressure 264 = EMW 11.0 ppg 16:30 - 00:00 7.50 DRILL P INT1 Directional Drill from 3340' to 4468' - WOB 10 to 25 - RPM 80 - TQ on 5K - off 4K - GPM 500 - PP on 2580 - off 2500 - PU 135 - SO 90 - ROT 1 06 6/13/2005 00:00 - 03:30 3.50 DRILL P INn Directional Drill from 4468' to 4932' - WOB 10 to 20 - RPM 80 - Printed: 6/27/2005 11:13:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-31 MPE-31 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 6/8/2005 6/21/2005 Spud Date: 6/8/2005 End: 6/13/2005 00:00 - 03:30 3.50 DRILL P INT1 TO on 7.5 - off 5 - GPM 500 - PP on 2830 - off 2700 - PU 147- SO 91 - ROT 11 03:30 - 05:00 1.50 DRILL P INT1 CBU 2 X - GPM 500 - PP 2600 - RPM 80 - TO 6.5 05:00 - 06:30 1.50 DRILL P INT1 Pump to shoe from 4932' to 3300' - Pump at GPM 500 06:30 - 07:30 1.00 DRILL P INT1 CBU 2 X - GPM 340 to 500 - PP 1400 to 2320 07:30 - 08:00 0.50 DRILL P INT1 RIH - From 3300' to 4932' 08:00 - 00:00 16.00 DRILL P INT1 Directional Drill from 4932' to 6280' - WOB 15 to 20 - RPM 80 - TO on 9 - off 8 - GPM 500 - PP on 2800 - off 2720 - PU 172- SO 85 - ROT 117 6/14/2005 00:00 - 04:30 4.50 DRILL P INT1 Directional Drill from 6280' to 6512' - TD 9 7/8" Hole - WOB 15 to 25 - RPM - TO on 10 - off 9 - GPM 500 - PP on 2940 - off 2870 - PU 169 - SO 88 - ROT 118 04:30 - 06:00 1.50 CASE P INT1 CBU 2 X - GPM 500 - PP 2750 - RPM 80 - TO 8.5 06:00 - 07:30 1.50 CASE P INT1 Pump out from 6512' to 4900' - GPM 500 07:30 - 08:00 0.50 CASE P INT1 RIH to 6511 - Precauctionary wash last stand to botttom 08:00 - 10:30 2.50 CASE P INT1 CBU 3 X - GPM 500 - PP 3050 - RPM 80 - TO 9K 10:30 - 13:00 2.50 CASE P INT1 Pump out from 6512'. to 3300' - GPM 500 13:00 - 14:00 1.00 CASE P INT1 CBU 1 X - GPM 500 - PP 2000 - RPM 80 - TO 7 - Flow check - Well static - Pump dry job 14:00 - 16:30 2.50 CASE P INT1 POH from 3300' to 715' @ HWT - LD HWT - Flex DC's - MWD - Flush motor - Break bit - LD motor 16:30 - 17:30 1.00 CASE P INT1 Clear rig floor - PU casg tools - Pull wear ring - Install test plug 17:30 - 19:30 2.00 CASE P INT1 PJSM Change top VBR's to 7 5/8" casg rams - Test door seals to 1500 psi - RD test equipment - Pull test plug 19:30 - 21 :00 1.50 CASE P INT1 Rig up casg tools 21 :00 - 00:00 3.00 CASE P INT1 PJSM - PU / Run float shoe - Float collar - Check floats - Con't running 7 5/8" casg to 1927' 6/15/2005 00:00 - 01 :30 1.50 CASE P INT1 Con't Run 7 5/8" casg from 1927' to 3261' 01 :30 - 02:00 0.50 CASE P INT1 Circulate one casg vol- 150 bbls - 5.7 bpm - 400 psi 02:00 - 04:00 2.00 CASE P INT1 Con't Run 7 5/8" casg from 3261' to 6502' 04:00 - 05:00 1.00 CASE P INT1 Break circulation - Stage up pump to 5.7 bpm - PP 400- Circulate one casg vol 298 bbls - PU 250 - SO 115 05:00 - 05:30 0.50 CASE P INT1 LD Franks fill up tool - Make up Dowell Schlumberger cementing head /Iines 05:30 - 07:00 1.50 CASE P INT1 Circulate one casg vol - 298 bbbls - 5.7 bpm 350 psi - Condition mud for cementing 07:00 - 08:30 1.50 CEMT P INT1 Give to Dowell Schlumberger Pump 5 bbls water Test lines to 3500 psi Pump 15 bbls CW-100 Pump 50 bbls Mud Push @ 10.5 ppg Drop bottom plug Pump 94 bbls - 451 sxs Yield 1.17 cf/sx Class 'G' @ 15.8 ppg Drop top plug Displace with 295 bbls Oil Base mud Bump plug with 1000 psi over 1800 psi Held for 3 mins bleed off pressure - Floats holding - CIP 08:30 Hrs 08:30 - 09:00 0.50 CASE P INT1 Test casg to 1500 psi for 30 mins 09:00 - 10:00 1.00 CASE P INT1 Break out cementing head - Lay down same - Void 60' of oil base out of casg - Flush stack with water - Drain stack 10:00 - 10:30 0.50 CASE P INT1 Lay down landing joint 10:30 - 11 :30 1.00 CASE P INT1 Install 10 3/4" X 7 5/8" FMC pack-off - Test to 5000 psi for 10 Printed: 6/27/2005 11:13:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-31 MPE-31 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/8/2005 Rig Release: 6/21/2005 Rig Number: Spud Date: 6/8/2005 End: 6/15/2005 10:30 - 11 :30 1.00 CASE P INT1 mins 11 :30 - 13:00 1.50 CASE P INT1 Change out 7 5/8" casg rams to 2 7/8" x 5" VBR's 13:00 - 14:30 1.50 CASE P INT1 Rig up test equipment - Test rams - Door seals - 250 low - 3500 high - Record on chart - RD test equipment - Pull test plug - Install Wear ring - Close annulus valve 14:30 - 15:00 0.50 CASE P INT1 Moblize short BHA to rig floor 15:00 - 17:00 2.00 CASE P INT1 PJSM - MU BHA - Bit - Motor - Stab - MWD 17:00 - 18:00 1.00 CASE P INT1 Up load MWD - Pulse test 18:00 - 19:30 1.50 CASE P INT1 Load sources 19:30 - 22:00 2.50 CASE P INT1 RIH w 4" drill pipe to 6387' - Fill every 25 stands on trip in 22:00 - 23:00 1.00 CASE P INT1 RU test equipment - Test casg to 1500 psi - 30 mins - record on chart - RD test equipment 23:00 - 00:00 1.00 DRILL P INT1 Drlg float collar 6416' - Float shoe 6502' - Clean out rat hole to 6511' 6/16/2005 00:00 - 00:30 0.50 DRILL P INT1 Drill from 6511' to 6531 00:30 - 01 :00 0.50 CASE P INT1 CBU 1 X - GPM 254 - PP 2280 - RPM 40 - TO 5K 01 :00 - 02:00 1.00 EVAL P INT1 FIT - MD 6501 - TVD 4384 - Mud weight 9.1 - Surface pressure 661 = EMW 12 ppg - Clean hole ECD 9.8 02:00 - 00:00 22.00 DRILL P PROD1 Directional Drill from 6531' to 8160' - Faults @ 7400', 7805' - WOB 5 to 20 - RPM 80 - TO on 4 - off 3 - GPM 275 - PP on 2920 - off 2870 - PU 130 - So 80 - ROT 105 6/17/2005 00:00 - 07:00 7.00 DRILL P PROD1 Directional Drill from 8160' to 8810' - Fault 8335' - WOB 5 to 10 - RPM 80 - TO on 5 - off 4 - GPM 275 - PP on 3120 - off 3040- PU 135 - SO 73 - ROT 105 - ECD 10.99 - Prepare for open hole sidetrack 07:00 - 08:30 1.50 DRILL C PROD1 Pump out to 7980' for sidetrack 08:30 - 09:30 1.00 DRILL C PROD1 Start trough for open hole sidetrack @ 7980 - Start sidetrack @ 8002' 09:30 - 21 :30 12.00 DRILL C PROD1 Drill from 8002' to 9042' - TD 6 3/4" NC/ND Lateral - WOB 2 to 4 - RPM 80 - TO on 5 - off 4 - GPM 275 - PP on 3120 - off 3000 - PU 130 - SO 85 - ROT 110 - ECD 10.94 21 :30 - 00:00 2.50 CASE P PROD1 CBU 3 X - GPM 275 - PP 3100 - RPM 80 - TO 4 - ECD 10.7- Flow check - Well static 6/18/2005 00:00 - 03:00 3.00 CASE P PROD1 Pump out to shoe from 9034' to 6480' - Pump @ drlg rate - Tight hole 8010' - Pack off - Back ream @ 40 RPM -from 7990' to 7429' - Pack off - Con't Back ream from 7429' to shoe 03:00 - 04:00 1.00 CASE P PROD1 CBU - 2 X - GPM 275 - PP 2600 04:00 - 05:00 1.00 CASE P PROD1 Cut Drlg line - Top Drive Service - Rig service 05:00 - 06:00 1.00 CASE P PROD1 RIH to 7980' 06:00 - 07:00 1.00 CASE P PROD1 Orient low side - Work thru side track with pumps on - Orient high side pump back thru side rack - repeat serval times to clean up side track 07:00 - 07:30 0.50 CASE P PROD1 Con't RIH to 9042' 07:30 - 10:00 2.50 CASE P PROD1 CBU 3 X - GPM 275 - PP 3050 - After 2nd BU - screen up shakers from 200 to 230 mesh - RPM 80 - TO 4K 10:00 - 12:30 2.50 CASE P PROD1 Pump out from 9042' to 6500' - Pump @ drlg rate - GPM 280 - Flow check - Well Static 12:30 - 13:30 1.00 CASE P PROD1 CBU 1.5 X - RPM 80 - TO 4K - GPM 280 - PP 2630 - Monitor well 10 mins - Well Static - Pump dry job 13:30 - 16:00 2.50 CASE P PROD1 POH to BHA 16:00 - 18:30 2.50 CASE P PROD1 LD Jars - 4 3/4" Flex DC's - PJSM (handling nuclear sources) - Remove sources - Down load MWD - LD MWD / Stab - Motor 18:30 - 19:30 1.00 CASE P PROD1 Lay down Short BHA out beaver slide - Clear rig floor Printed: 6/27/2005 11:13:36AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-31 MPE-31 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/8/2005 Rig Release: 6/21/2005 Rig Number: Spud Date: 6/8/2005 End: 6/18/2005 19:30 - 20:00 0.50 CASE P PROD1 RU liner tools 4" - PJSM (running 4" screen liner) 20:00 - 23:00 3.00 CASE P PROD1 PU I Run 4" screen liner 23:00 - 23:30 0.50 CASE P PROD1 Change handling tools - PU 4 1/2" tubing - ECP packer 23:30 - 00:00 0.50 CASE P PROD1 Change handling tools - RU 2 7/8" Inner string - PU 2 7/8" Inner string 6/19/2005 00:00 - 01 :00 1.00 CASE P PROD1 Con't Run 2 7/8" Inner string - Change handling tools - PU Baker HMC Hanger - Baker ZXP Packer - Liner weight PU 80k - SO 75K - Block Wt 50K - (Inner string 7 joints 218.53' + Baker tools 15.19' = Totallenght of Inner string 233.72') 01 :00 - 03:00 2.00 CASE P PROD1 RIH with 4" Screen Liner on 4" DP to 5980' 03:00 - 03:30 0.50 CASE P PROD1 Circulate 1 DP volume - 2.8 bpm @ 460 psi - (Setting ECP, ZXP Packer - Setting HMC Hanger - Release off Hanger) 03:30 - 05:00 1.50 CASE P PROD1 Con't RIH with 4" Liner from 5980' to 9042' 05:00 - 05:30 0.50 CASE P PROD1 Break circulation - Circulate one DP vol - 66 bls - GPM 143 - PP 740 psi - Drop ball - Pump ball on seat - GPM 126 @ 620 psi 05:30 - 07:00 1.50 CASE P PROD1 Pressure up to 1500 psi set hanger - SO 50K on hanger to ensure set - PU to 100K - Pressure up to 2400 psi to inflate ECP - Bleed off - Pressure up to 3000 psi to set ZXP packer - Bleed off - Close Annular - Pressure up to 1500 psi on annulus for 15 mins to test packer - Bleed off - Turn DP 20 rounds to the right to release running tool PU 45' 07:00 - 08:00 1.00 CASE P PROD1 CBU - GPM 340 - PP 1530 - Flow check - Well static 08:00 - 10:30 2.50 CASE P PROD1 POH 10:30 - 12:00 1.50 CASE P PROD1 Lay down liner running tool - 2 7/8" Inner string 12:00 - 12:59 0.98 CASE P PROD1 Clear rig floor - Clean Baker Inner string pups before laying down - Lay down Inner string pups - Tools - Subs 12:59 - 13:00 0.02 CASE N SFAL PROD1 DIMS Scorecard 13:00 - 15:30 2.50 RUNCOIvP RUNCMP Make up mule shoe - RIH on 4" DP to 6360' 15:30 - 16:00 0.50 RUNCOM RUNCMP Break Circulation - CBU 1 X - RPM 120 - TQ 4K - GPM 305 - PP 1250- 16:00 - 18:30 2.50 RUNCOIvP RUNCMP Break circulation - Displace 9.3 ppg oil base mud with - spacers - Seawater - 9.2 ppg NACL till clean returns - Flush Kill I Choke lines - Choke manifold - Surface equipment Flow check - Well static 18:30 - 21 :30 3.00 RUNCOIvP RUNCMP POH - Laying down 4" DP from 6360' to 2500' - RIH from 2500' to 5185' with 4" DP from derrick 21 :30 - 00:00 2.50 RUNCOIvP RUNCMP CBU 1 DP vol- Con't POH Laying down 4" DP from 5185' to 1000' 6/20/2005 00:00 - 01 :00 1.00 RUNCOIvP RUNCMP Con't LD 4" Dp from 1000' to Mule shoe - Break and LD mule shoe 01 :00 - 01 :30 0.50 RUNCOIvP RUNCMP Pull wear ring - Clear floor of tools 01 :30 - 03:30 2.00 RUNCOIvP RUNCMP PJSM - Running 2 7/8" completion - RU to run ESP control line - 2 7/8" tubing 03:30 - 06:30 3.00 RUNCOIvP RUNCMP PJSM - PU 2 7/8" ESP pumps and service same - Hook up control to motor I pumps 06:30 - 10:00 3.50 RUNCOIvP RUNCMP PU I Run with 2 7/8" Tubing and ESP cable - 90 Joints - 2870' - + Test conductivity and break circulation @ 1000' /3000' - GPM 34 - PP 1840 psi 10:00 - 11 :00 1.00 RUNCOIvP RUNCMP PJSM - RU to run heat trace on tubing 11 :00 - 23:59 12.98 RUNCOIvP RUNCMP Con't PU I Run 2 718" tubing - ESP cable - Heat trace cable from joint 91 to 167 - Test ESP cable and heat trace continuity Printed: 6/27/2005 11:13:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPE-31 MPE-31 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 6/8/2005 Rig Release: 6/21/2005 Rig Number: Spud Date: 6/8/2005 End: 6/20/2005 11 :00 - 23:59 12.98 RUNCO~ RUNCMP every 1000' - Pump 10 bbl thru tubing every 1000' 23:59 - 00:00 0.02 RUNCOMN SFAL RUNOMP DIMS Scorecard , Con't PU / Run 2 7/8" tubing - ESP cable - Heat trace cable 6/21/2005 00:00 - 05:30 5.50 RUNCm..p RUNCMP ",. from joint 167 to 197 - Test ESP cable and heat trace continuity every 1000' - Pump 10 bbl thru tubing every 1000' 05:30 . 06:30 1.00 RUNCO~ RUNCMP PU Hanger - Make up tubing hanger, check conductivity, down hole gauges for BHT, BHP not reading, MP said land tubing anyway 06:30 . 13:00 6.50 RUNCO~ RUNCMP Splice ESP and heat trace cables to ESP tubing hanger penterator, test ESP and heat trace penetrators, Land tubing with TWO in place, @ 6256', total jts run 197 jts, P/U 93K, S/O 75K 13:00 - 14:30 1.50 BOPSUPP RUNCMP PJSM, Test TWC from top to 1000 psi, Nipple down BOPS 14:30 - 16:00 1.50 WHSUR P RUNCMP PJSM, Nipple up FMC 11" x 2 9/16 ESP tubing head adapter, CIW 2 9/16 5K Tree 16:00 - 17:00 1.00 WHSUR P RUNCMP PJSM, Test packoff to 5,000 for 10 min., body test tree to 5,000 for 10 min., pull TWC and install BPV, final test on continuity of ESP 17:00 - 18:00 1.00 WHSUR P RUNCMP PJSM, Secure well, install valve handles, gauges, clean out cellar, Rig release for rig move @ 1800 hrs, 6/21/2005 Printed: 6/27/2005 11:13:36 AM WELL SERVICE REPORT WELL MPE-31 DATE 6/22/2005 AFE MSD337442 . UNIT- LRS 64 DAY SUPV HULME NIGHT SUPV UNKNOWN TTL SIZE 0" JOB SCOPE RWO CAPITAL DAILY WORK FREEZE PROT KEY PERSON LRS-SCHREIBER MINID 0" DEPTH OFT DAILY SUMMARY (FP RWO Post) T/I/O=010/200. Freeze protect IA wI 65 bbls crude. Freeze protect tbg w/15 bbls crude. FWP=600/800/200. Init-> 0 0 200 TI~E BPM BBLs FLUID_TEMP TBG IA ~ OA COMMENTS 11 :30 Start ticket:---- 11:50 Load crude. 12:28 Arrive location. MIRU. 12:48 PT to 3000 psi. 12:51 1.5 sta rt crude 80 350 Down IA 12:58 1.5 10 1100 13:08 1.5 25 1200 13;34 1.5 65 1350 Shutdown. 13:35 RD off IA._ RU to tbg. 13:47 PT to 3000 psi. 13:51 1.2 start crude 80 1200 Down tbg - 14:04 1.2 15 " 1200 Shutdown. 14:06 Start RD. 14:29 End ticket. - ~~"............,~.~..~~ ~,' c _ ,~..-'-->~,n_^ ~. -. nO" -~~~~ Final-> 600 800 200 I FLUID SUMMARY 80 bbls crude SER~CECOMPANY-SER~CE BP LITTLE RED DAILY COST CUMUL TOTAL $0 $705 -$7Õ'S' $0 $705 $705 _','__^_ _______ __.^'_;_A TOTAL FIELD ESTIMATE: Legal Name: Common Name: MPE-31 MPE-31 6/12/2005 FIT 3,310.0 (ft) 2,669.0 (ft) 9.10 (ppg) 264 (psi) 1,526 (psi) 11.00 (ppg) . . Printed: 6/27/2005 11:13:30AM . Halliburton Global . Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Well: MPE-31 Slot Name: Well Position: +N/-S 2701.55 ft Northing: 6016497.19 ft Latitude: +E/-W -286.64 ft Easting: 569128.95 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: MPE-31 500292326300 Current Datum: MPE-31: Magnetic Data: 6/8/2005 Field Strength: 57576 nT Vertical Section: Depth From (TVD) ft 34.20 Height 56.30 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 +N/-S ft 0.00 Alaska, Zone 4 Well Centre bggm2005 70 27 19.552 N 149 26 9.075 W MPE-31PB1 7992.16 ft Mean Sea Level 24.58 deg 80.90 deg Direction deg 32.97 Survey Program for Definitive Wellpath Date: 7/13/2005 Validated: Yes Version: Actual From To Survey Toolcode Tool Name ft ft 79.00 719.60 MPE-31 Wellnav Gyro (79.00-719.60) (0) CB-GYRO-SS Camera based gyro single shots 749.86 7992.16 MPE-31 PB11IFR+CAZ+SAG (749.86-8738.~{OtIFR+MS MWD + IFR + Multi Station 8002.00 8971.88 MPE-31 (8002.00-8971.88) MWD+IFR+MS MWD + IFR + Multi Station Survey 34.20 0.00 0.00 34.20 -22.10 0.00 0.00 6016497.19 569128.95 TIE LINE 79.00 0.11 160.50 79.00 22.70 -0.04 0.01 6016497.15 569128.96 CB-GYRO-SS 172.00 1.10 51.20 171.99 115.69 0.43 0.74 6016497.63 569129.69 CB-GYRO-SS 259.60 3.20 60.74 259.53 203.23 2.16 3.53 6016499.38 569132.46 CB-GYRO-SS 348.60 5.20 61.87 348.28 291.98 5.27 9.25 6016502.55 569138.15 CB-GYRO-SS 440.60 6.60 64.79 439.80 383.50 9.49 17.71 6016506.84 569146.57 CB-GYRO-SS 530.60 8.80 62.00 528.98 472.68 14.93 28.47 6016512.38 569157.28 CB-GYRO-SS 629.60 9.35 58.67 626.74 570.44 22.66 42.03 6016520.24 569170.76 CB-GYRO-SS 719.60 10.20 49.66 715.44 659.14 31.62 54.35 6016529.31 569183.00 CB-GYRO-SS 749.86 10.55 52.04 745.20 688.90 35.06 58.58 6016532.79 569187.19 MWD+IFR+MS 846.86 12.16 57.34 840.30 784.00 46.04 74.18 6016543.91 569202.69 MWD+IFR+MS 940.70 13.41 53.87 931.82 875.52 57.79 91.29 6016555.82 569219.69 MWD+IFR+MS 1037.48 14.67 52.79 1025.70 969.40 71.82 110.11 6016570.02 569238.38 MWD+IFR+MS 1133.78 16.34 53.48 1118.50 1062.20 87.25 130.71 6016585.64 569258.84 MWD+IFR+MS 1229.70 22.41 51.66 1208.94 1152.64 106.64 155.92 6016605.27 569283.86 MWD+IFR+MS 1277.23 23.68 51.54 1252.68 1196.38 118.20 170.50 6016616.96 569298.33 MWD+IFR+MS 1326.39 25.91 52.17 1297.30 1241.00 130.93 186.72 6016629.83 569314.43 MWD+IFR+MS 1422.44 28.96 52.72 1382.54 1326.24 157.89 221.80 6016657.12 569349.26 MWD+IFR+MS 1518.30 34.25 53.94 1464.16 1407.86 187.85 262.11 6016687.45 569389.28 MWD+IFR+MS 1613.33 38.28 54.44 1540.76 1484.46 220.72 307.69 6016720.74 569434.55 MWD+IFR+MS 1709.80 37.86 54.25 1616.71 1560.41 255.40 356.02 6016755.85 569482.55 MWD+IFR+MS 1806.35 38.79 53.40 1692.45 1636.15 290.74 404.35 6016791.64 569530.55 MWD+IFR+MS 1901.07 39.83 53.03 1765.74 1709.44 326.67 452.41 6016828.02 569578.26 MWD+IFR+MS 1997.64 39.86 53.43 1839.88 1783.58 363.71 501.97 6016865.51 569627.48 MWD+IFR+MS 2093.15 40.87 53.40 1912.65 1856.35 400.58 551.64 6016902.83 569676.80 MWD+IFR+MS 2188.89 43.63 52.75 1983.52 1927.22 439.25 603.09 6016941.98 569727.88 MWD+IFR+MS 2284.49 47.41 53.98 2050.49 1994.19 479.93 657.83 6016983.16 569782.23 MWD+IFR+MS 2381.63 51.34 54.00 2113.72 2057.42 523.27 717.45 6017027.04 569841.45 MWD+IFR+MS . Halliburton Global . Survey 2477.60 52.21 54.52 2173.11 2116.81 567.30 778.65 6017071.64 569902.23 MWD+IFR+MS 2573.44 53.98 53.79 2230.66 2174.36 612.18 840.76 6017117.09 569963.92 MWD+IFR+MS 2666.42 53.14 53.30 2285.88 2229.58 656.63 900.93 6017162.08 570023.66 MWD+IFR+MS 2764.49 54.86 54.08 2343.53 2287.23 703.60 964.86 6017209.65 570087.15 MWD+IFR+MS 2860.51 54.20 54.46 2399.24 2342.94 749.27 1028.34 6017255.90 570150.20 MWD+IFR+MS 2957.38 53.16 54.03 2456.62 2400.32 794.87 1091.68 6017302.08 570213.11 MWD+IFR+MS 3052.78 52.60 53.58 2514.19 2457.89 839.79 1153.07 6017347.56 570274.07 MWD+IFR+MS 3149.20 51.84 53.59 2573.26 2516.96 885.03 1214.40 6017393.37 570334.97 MWD+IFR+MS 3244.82 53.83 55.12 2631.03 2574.73 929.42 1276.32 6017438.33 570396.47 MWD+IFR+MS 3264.09 54.34 55.08 2642.33 2586.03 938.35 1289.12 6017447.37 570409.19 MWD+IFR+MS 3335.10 54.10 54.69 2683.85 2627.55 971.49 1336.25 6017480.94 570456.00 MWD+IFR+MS 3430.72 52.91 53.67 2740.72 2684.42 1016.47 1398.58 6017526.49 570517.90 MWD+IFR+MS 3525.61 54.46 55.90 2796.92 2740.62 1060.54 1461.04 6017571.14 570579.95 MWD+IFR+MS 3622.90 53.68 55.55 2854.00 2797.70 1104.90 1526.14 6017616.10 570644.63 MWD+IFR+MS 3719.44 51.62 55.38 2912.57 2856.27 1148.41 1589.36 6017660.19 570707.44 MWD+IFR+MS 3815.49 54.00 55.72 2970.63 2914.33 1191.69 1652.45 6017704.04 570770.12 MWD+IFR+MS 3910.75 54.61 55.05 3026.21 2969.91 1235.63 1716.12 6017748.58 570833.37 MWD+IFR+MS 4007.39 54.38 54.57 3082.33 3026.03 1280.97 1780.42 6017794.50 570897.24 MWD+IFR+MS 4104.62 53.35 55.88 3139.67 3083.37 1325.76 1844.91 6017839.89 570961.31 MWD+IFR+MS 4198.68 53.07 56.06 3196.00 3139.70 1367.92 1907.34 6017882.61 571023.33 MWD+IFR+MS 4294.23 52.24 53.96 3253.97 3197.67 1411.46 1969.57 6017926.73 571085.15 MWD+IFR+MS 4390.69 52.04 54.52 3313.17 3256.87 1455.97 2031.36 6017971.81 571146.53 MWD+IFR+MS 4487.29 53.05 53.44 3371.91 3315.61 1501.07 2093.38 6018017.47 571208.12 MWD+IFR+MS 4583.27 52.73 52.71 3429.82 3373.52 1547.05 2154.57 6018064.02 571268.87 MWD+IFR+MS 4678.19 53.06 53.07 3487.09 3430.79 1592.72 2214.94 6018110.25 571328.81 MWD+IFR+MS 4775.34 52.03 52.29 3546.17 3489.87 1639.48 2276.27 6018157.56 571389.70 MWD+IFR+MS 4868.77 52.46 52.46 3603.37 3547.07 1684.57 2334.78 6018203.19 571447.78 MWD+IFR+MS 4965.16 54.26 53.07 3660.89 3604.59 1731.36 2396.36 6018250.55 571508.91 MWD+IFR+MS 5060.96 53.56 51.98 3717.33 3661.03 1778.46 2457.80 6018298.21 571569.91 MWD+IFR+MS 5157.22 53.03 52.03 3774.86 3718.56 1825.97 2518.61 6018346.28 571630.28 MWD+IFR+MS 5253.79 54.17 49.06 3832.17 3775.87 1875.36 2578.61 6018396.22 571689.80 MWD+IFR+MS 5349.65 56.05 48.69 3887.00 3830.70 1927.08 2637.83 6018448.48 571748.54 MWD+IFR+MS 5445.36 57.08 45.52 3939.75 3883.45 1981.44 2696.32 6018503.38 571806.52 MWD+IFR+MS 5541.87 57.15 43.64 3992.15 3935.85 2039.16 2753.21 6018561.62 571862.86 MWD+IFR+MS 5638.05 59.31 41.47 4042.79 3986.49 2099.40 2808.49 6018622.36 571917.57 MWD+IFR+MS 5734.31 60.96 37.81 4090.74 4034.44 2163.68 2861.71 6018687.12 571970.19 MWD+IFR+MS 5830.79 64.60 32.57 4134.89 4078.59 2233.79 2911.07 6018757.68 572018.89 MWD+IFR+MS 5927.16 67.64 28.42 4173.91 4117.61 2309.70 2955.73 6018834.00 572062.85 MWD+IFR+MS 6023.33 66.52 24.72 4211.37 4155.07 2388.90 2995.35 6018913.55 572101.73 MWD+IFR+MS 6059.66 67.21 23.38 4225.65 4169.35 2419.41 3008.97 6018944.18 572115.06 MWD+IFR+MS 6119.89 67.26 22.97 4248.95 4192.65 2470.47 3030.82 6018995.44 572136.44 MWD+IFR+MS 6216.96 67.66 23.35 4286.16 4229.86 2552.90 3066.09 6019078.18 572170.93 MWD+IFR+MS 6313.17 68.11 22.87 4322.38 4266.08 2634.87 3101.07 6019160.47 572205.15 MWD+IFR+MS 6360.34 68.31 22.06 4339.89 4283.59 2675.35 3117.80 6019201.10 572221.50 MWD+IFR+MS 6408.71 70.26 18.65 4357.00 4300.70 2717.76 3133.53 6019243.65 572236.83 MWD+IFR+MS 6447.40 73.16 16.55 4369.15 4312.85 2752.77 3144.63 6019278.76 572247.61 MWD+IFR+MS 6508.21 76.57 15.72 4385.02 4328.72 2809.15 3160.94 6019335.28 572263.39 MWD+IFR+MS 6541.72 78.91 15.27 4392.14 4335.84 2840.71 3169.68 6019366.91 572271.84 MWD+IFR+MS 6603.79 85.41 13.53 4400.60 4344.30 2900.23 3184.96 6019426.57 572286.56 MWD+IFR+MS 6651.80 85.16 13.37 4404.55 4348.25 2946.77 3196.09 6019473.21 572297.26 MWD+IFR+MS 6699.05 86.22 13.49 4408.10 4351.80 2992.59 3207.03 6019519.13 572307.78 MWD+IFR+MS 6743.22 89.21 12.90 4409.86 4353.56 3035.56 3217.11 6019562.18 572317.45 MWD+IFR+MS . Halliburton Global . Survey 6795.56 90.28 11.60 4410.09 4353.79 3086.71 3228.21 6019613.42 572328.08 MWD+IFR+MS 6845.39 91.93 11.13 4409.13 4352.83 3135.55 3238.03 6019662.35 572337.44 MWD+IFR+MS 6891.52 90.66 10.25 4408.09 4351.79 3180.86 3246.58 6019707.74 572345.57 MWD+IFR+MS 6937.40 90.41 8.21 4407.66 4351.36 3226.15 3253.94 6019753.08 572352.51 MWD+IFR+MS 6988.26 90.31 7.47 4407.34 4351.04 3276.53 3260.88 6019803.52 572358.98 MWD+IFR+MS 7032.65 88.94 6.42 4407.63 4351.33 3320.59 3266.25 6019847.63 572363.94 MWD+IFR+MS 7084.15 88.44 6.19 4408.81 4352.51 3371.77 3271.90 6019898.85 572369.12 MWD+IFR+MS 7130.29 87.82 5.80 4410.31 4354.01 3417.63 3276.72 6019944.75 572373.51 MWD+IFR+MS 7179.78 89.33 5.65 4411.54 4355.24 3466.85 3281.65 6019994.01 572377.98 MWD+IFR+MS 7225.95 90.01 6.45 4411.81 4355.51 3512.77 3286.52 6020039.96 572382.42 MWD+IFR+MS 7273.20 91.05 4.65 4411.37 4355.07 3559.79 3291.09 6020087.02 572386.56 MWD+IFR+MS 7322.13 91.83 4.20 4410.14 4353.84 3608.56 3294.86 6020135.82 572389.88 MWD+IFR+MS 7369.63 90.71 2.78 4409.09 4352.79 3655.96 3297.75 6020183.24 572392.33 MWD+IFR+MS 7419.57 91.34 1.31 4408.20 4351.90 3705.85 3299.53 6020233.15 572393.65 MWD+IFR+MS 7464.49 91.76 0.74 4406.98 4350.68 3750.75 3300.34 6020278.05 572394.03 MWD+IFR+MS 7512.86 92.20 1.31 4405.31 4349.01 3799.08 3301.20 6020326.38 572394.45 MWD+IFR+MS 7560.79 92.40 2.98 4403.39 4347.09 3846.94 3302.99 6020374.25 572395.80 MWD+IFR+MS 7608.42 91.27 4.10 4401.86 4345.56 3894.45 3305.93 6020421.78 572398.29 MWD+IFR+MS 7656.98 90.85 4.08 4400.96 4344.66 3942.88 3309.40 6020470.23 572401.31 MWD+IFR+MS 7705.60 89.90 4.39 4400.64 4344.34 3991.37 3312.99 6020518.75 572404.45 MWD+IFR+MS 7753.30 89.67 4.14 4400.82 4344.52 4038.93 3316.53 6020566.34 572407.55 MWD+IFR+MS 7802.28 89.67 4.21 4401.11 4344.81 4087.78 3320.10 6020615.22 572410.67 MWD+IFR+MS 7849.29 89.49 3.22 4401.45 4345.15 4134.69 3323.15 6020662.15 572413.28 MWD+IFR+MS 7896.84 90.61 2.90 4401.41 4345.11 4182.17 3325.68 6020709.64 572415.37 MWD+IFR+MS 7943.61 92.15 2.86 4400.28 4343.98 4228.87 3328.03 6020756.36 572417.29 MWD+IFR+MS 7992.16 93.26 3.62 4397.99 4341.69 4277.29 3330.77 6020804.79 572419.58 MWD+IFR+MS 8002.00 93.46 4.18 4397.41 4341.11 4287.09 3331.44 6020814.60 572420.16 MWD+IFR+MS 8040.89 90.73 6.09 4395.99 4339.69 4325.79 3334.92 6020853.33 572423.28 MWD+IFR+MS 8086.70 93.38 7.22 4394.35 4338.05 4371.26 3340.22 6020898.84 572428.16 MWD+IFR+MS 8137.11 95.73 8.86 4390.35 4334.05 4421.01 3347.25 6020948.65 572434.72 MWD+IFR+MS 8182.47 94.51 9.43 4386.30 4330.00 4465.61 3354.43 6020993.31 572441.49 MWD+IFR+MS 8233.85 94.43 8.90 4382.29 4325.99 4516.18 3362.59 6021043.95 572449.18 MWD+IFR+MS 8280.04 94.80 8.41 4378.58 4322.28 4561.70 3369.52 6021089.52 572455.68 MWD+IFR+MS 8329.80 92.44 8.71 4375.44 4319.14 4610.80 3376.91 6021138.69 572462.62 MWD+IFR+MS 8376.86 91.40 9.40 4373.86 4317.56 4657.25 3384.31 6021185.20 572469.59 MWD+IFR+MS 8425.69 89.96 8.93 4373.28 4316.98 4705.45 3392.09 6021233.47 572476.91 MWD+IFR+MS 8475.39 89.74 8.98 4373.41 4317.11 4754.54 3399.83 6021282.62 572484.19 MWD+IFR+MS 8522.39 89.74 8.74 4373.62 4317.32 4800.98 3407.06 6021329.12 572491.00 MWD+IFR+MS 8571.15 91.84 8.47 4372.95 4316.65 4849.19 3414.36 6021377 .39 572497.85 MWD+IFR+MS 8618.85 91.71 7.56 4371.47 4315.17 4896.40 3421.01 6021424.65 572504.06 MWD+IFR+MS 8668.29 93.49 6.75 4369.23 4312.93 4945.40 3427.16 6021473.71 572509.75 MWD+IFR+MS 8714.92 91.57 4.56 4367.17 4310.87 4991.75 3431.75 6021520.10 572513.91 MWD+IFR+MS 8759.44 91.04 3.83 4366.16 4309.86 5036.14 3435.00 6021564.51 572516.75 MWD+IFR+MS 8811.16 89.99 3.65 4365.69 4309.39 5087.75 3438.38 6021616.14 572519.65 MWD+IFR+MS 8852.49 89.01 3.75 4366.05 4309.75 5128.99 3441.04 6021657.40 572521.93 MWD+IFR+MS 8907.05 89.41 2.95 4366.81 4310.51 5183.45 3444.23 6021711.88 572524.61 MWD+IFR+MS 8971.88 89.43 2.37 4367.46 4311.16 5248.21 3447.24 6021776.66 572527.02 MWD+IFR+MS 9042.00 89.43 2.37 4368.16 ~ 4311.86 5318.26 3450.14 6021846.73 572529.27 PROJECTED to TD . Halliburton Global . Field: Milne Point North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Well: MPE-31 Map Zone: Coordinate System: Geomagnetic Model: Slot Name: Well Position: +N/-S 2701.55 ft Northing: 6016497.19 ft Latitude: +E/-W -286.64 ft Easting: 569128.95 ft Longitude: Position Uncertainty: 0.00 ft Wellpath: MPE-31PB1 500292326370 Current Datum: MPE-31: Magnetic Data: 6/8/2005 Field Strength: 57576 nT Vertical Section: Depth From (TVD) ft 34.20 Survey Program for Definitive Wellpath Date: 7/13/2005 Validated: Yes Actual From To Survey ft ft 79.00 719.60 749.86 8738.98 Survey Height 56.30 ft +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Version: Toolcode MPE-31 Wellnav Gyro (79.00-719.60) CB-GYRO-SS MPE-31 PB 1 IIFR+CAZ +SAG (749.86-8738.88JVD+IFR+MS Alaska, Zone 4 Well Centre bggm2005 70 27 19.552 N 149 26 9.075 W Well Ref. Point 34.20 ft Mean Sea Level 24.58 deg 80.90 deg Direction deg 34.05 4 Tool Name Camera based gyro single shots MWD + IFR + Multi Station 34.20 79.00 172.00 259.60 348.60 440.60 530.60 629.60 719.60 749.86 846.86 940.70 1037.48 1133.78 1229.70 1277.23 1326.39 1422.44 1518.30 1613.33 1709.80 1806.35 1901.07 1997.64 2093.15 2188.89 2284.49 2381.63 2477.60 / 0.00 0.11 1.10 3.20 5.20 6.60 8.80 9.35 10.20 10.55 12.16 13.41 14.67 16.34 22.41 23.68 25.91 28.96 34.25 38.28 37.86 38.79 39.83 39.86 40.87 43.63 47.41 51.34 52.21 0.00 160.50 51.20 60.74 61.87 64.79 62.00 58.67 49.66 52.04 57.34 53.87 52.79 53.48 51.66 51.54 52.17 52.72 53.94 54.44 54.25 53.40 53.03 53.43 53.40 52.75 53.98 54.00 54.52 34.20 79.00 171.99 259.53 348.28 439.80 528.98 626.74 715.44 745.20 840.30 931.82 1025.70 1118.50 1208.94 1252.68 1297.30 1382.54 1464.16 1540.76 1616.71 1692.45 1765.74 1839.88 1912.65 1983.52 2050.49 2113.72 2173.11 -22.10 22.70 115.69 203.23 291.98 383.50 472.68 570.44 659.14 688.90 784.00 875.52 969.40 1062.20 1152.64 1196.38 1241.00 1326.24 1407.86 1484.46 1560.41 1636.15 1709.44 1783.58 1856.35 1927.22 1994.19 2057.42 2116.81 0.00 -0.04 0.43 2.16 5.27 9.49 14.93 22.66 31.62 35.06 46.04 57.79 71.82 87.25 106.64 118.20 130.93 157.89 187.85 220.72 255.40 290.74 326.67 363.71 400.58 439.25 479.93 523.27 567.30 17.71 28.47 42.03 54.35 58.58 74.18 91.29 110.11 130.71 155.92 170.50 186.72 221.80 262.11 307.69 356.02 404.35 452.41 501.97 551.64 603.09 657.83 717.45 778.65 0.00 0.01 0.74 3.53 9.25 6016497.19 6016497.15 6016497.63 6016499.38 6016502.55 6016506.84 6016512.38 6016520.24 6016529.31 6016532.79 6016543.91 6016555.82 6016570.02 6016585.64 6016605.27 6016616.96 6016629.83 6016657.12 6016687.45 6016720.74 6016755.85 6016791.64 6016828.02 6016865.51 6016902.83 6016941.98 6016983.16 6017027.04 6017071.64 569128.95 TIE LINE 569128.96 CB-GYRO-SS 569129.69 CB-GYRO-SS 569132.46 CB-GYRO-SS 569138.15 CB-GYRO-SS 569146.57 CB-GYRO-SS 569157.28 CB-GYRO-SS 569170.76 CB-GYRO-SS 569183.00 CB-GYRO-SS 569187.19 MWD+IFR+MS 569202.69 MWD+IFR+MS 569219.69 MWD+IFR+MS 569238.38 MWD+IFR+MS 569258.84 MWD+IFR+MS 569283.86 MWD+IFR+MS 569298.33 MWD+IFR+MS 569314.43 MWD+IFR+MS 569349.26 MWD+IFR+MS 569389.28 MWD+IFR+MS 569434.55 MWD+IFR+MS 569482.55 MWD+IFR+MS 569530.55 MWD+IFR+MS 569578.26 MWD+IFR+MS 569627.48 MWD+IFR+MS 569676.80 MWD+IFR+MS 569727.88 MWD+IFR+MS 569782.23 MWD+IFR+MS 569841.45 MWD+IFR+MS 569902.23 MWD+IFR+MS . Halliburton Global . Survey 2573.44 53.98 53.79 2230.66 2174.36 612.18 840.76 6017117.09 569963.92 MWD+IFR+MS 2666.42 53.14 53.30 2285.88 2229.58 656.63 900.93 6017162.08 570023.66 MWD+IFR+MS 2764.49 54.86 54.08 2343.53 2287.23 703.60 964.86 6017209.65 570087.15 MWD+IFR+MS 2860.51 54.20 54.46 2399.24 2342.94 749.27 1028.34 6017255.90 570150.20 MWD+IFR+MS 2957.38 53.16 54.03 2456.62 2400.32 794.87 1091.68 6017302.08 570213.11 MWD+IFR+MS 3052.78 52.60 53.58 2514.19 2457.89 839.79 1153.07 6017347.56 570274.07 MWD+IFR+MS 3149.20 51.84 53.59 2573.26 2516.96 885.03 1214.40 6017393.37 570334.97 MWD+IFR+MS 3244.82 53.83 55.12 2631.03 2574.73 929.42 1276.32 6017438.33 570396.47 MWD+IFR+MS 3264.09 54.34 55.08 2642.33 2586.03 938.35 1289.12 6017447.37 570409.19 MWD+IFR+MS 3335.10 54.10 54.69 2683.85 2627.55 971.49 1336.25 6017480.94 570456.00 MWD+IFR+MS 3430.72 52.91 53.67 2740.72 2684.42 1016.47 1398.58 6017526.49 570517.90 MWD+IFR+MS 3525.61 54.46 55.90 2796.92 2740.62 1060.54 1461.04 6017571.14 570579.95 MWD+IFR+MS 3622.90 53.68 55.55 2854.00 2797.70 1104.90 1526.14 6017616.10 570644.63 MWD+IFR+MS 3719.44 51.62 55.38 2912.57 2856.27 1148.41 1589.36 6017660.19 570707.44 MWD+IFR+MS 3815.49 54.00 55.72 2970.63 2914.33 1191.69 1652.45 6017704.04 570770.12 MWD+IFR+MS 3910.75 54.61 55.05 3026.21 2969.91 1235.63 1716.12 6017748.58 570833.37 MWD+IFR+MS 4007.39 54.38 54.57 3082.33 3026.03 1280.97 1780.42 6017794.50 570897.24 MWD+IFR+MS 4104.62 53.35 55.88 3139.67 3083.37 1325.76 1844.91 6017839.89 570961.31 MWD+IFR+MS 4198.68 53.07 56.06 3196.00 3139.70 1367.92 1907.34 6017882.61 571023.33 MWD+IFR+MS 4294.23 52.24 53.96 3253.97 3197.67 1411.46 1969.57 6017926.73 571085.15 MWD+IFR+MS 4390.69 52.04 54.52 3313.17 3256.87 1455.97 2031.36 6017971.81 571146.53 MWD+IFR+MS 4487.29 53.05 53.44 3371.91 3315.61 1501.07 2093.38 6018017.47 571208.12 MWD+IFR+MS 4583.27 52.73 52.71 3429.82 3373.52 1547.05 2154.57 6018064.02 571268.87 MWD+IFR+MS 4678.19 53.06 53.07 3487.09 3430.79 1592.72 2214.94 6018110.25 571328.81 MWD+IFR+MS 4775.34 52.03 52.29 3546.17 3489.87 1639.48 2276.27 6018157.56 571389.70 MWD+IFR+MS 4868.77 52.46 52.46 3603.37 3547.07 1684.57 2334.78 6018203.19 571447.78 MWD+IFR+MS 4965.16 54.26 53.07 3660.89 3604.59 1731.36 2396.36 6018250.55 571508.91 MWD+IFR+MS 5060.96 53.56 51.98 3717.33 3661.03 1778.46 2457.80 6018298.21 571569.91 MWD+IFR+MS 5157.22 53.03 52.03 3774.86 3718.56 1825.97 2518.61 6018346.28 571630.28 MWD+IFR+MS 5253.79 54.17 49.06 3832.17 3775.87 1875.36 2578.61 6018396.22 571689.80 MWD+IFR+MS 5349.65 56.05 48.69 3887.00 3830.70 1927.08 2637.83 6018448.48 571748.54 MWD+IFR+MS 5445.36 57.08 45.52 3939.75 3883.45 1981.44 2696.32 6018503.38 571806.52 MWD+IFR+MS 5541.87 57.15 43.64 3992.15 3935.85 2039.16 2753.21 6018561.62 571862.86 MWD+IFR+MS 5638.05 59.31 41.47 4042.79 3986.49 2099.40 2808.49 6018622.36 571917.57 MWD+IFR+MS 5734.31 60.96 37.81 4090.74 4034.44 2163.68 2861.71 6018687.12 571970.19 MWD+IFR+MS 5830.79 64.60 32.57 4134.89 4078.59 2233.79 2911.07 6018757.68 572018.89 MWD+IFR+MS 5927.16 67.64 28.42 4173.91 4117.61 2309.70 2955.73 6018834.00 572062.85 MWD+IFR+MS 6023.33 66.52 24.72 4211.37 4155.07 2388.90 2995.35 6018913.55 572101.73 MWD+IFR+MS 6059.66 67.21 23.38 4225.65 4169.35 2419.41 3008.97 6018944.18 572115.06 MWD+IFR+MS 6119.89 67.26 22.97 4248.95 4192.65 2470.47 3030.82 6018995.44 572136.44 MWD+IFR+MS 6216.96 67.66 23.35 4286.16 4229.86 2552.90 3066.09 6019078.18 572170.93 MWD+IFR+MS 6313.17 68.11 22.87 4322.38 4266.08 2634.87 3101.07 6019160.47 572205.15 MWD+IFR+MS 6360.34 68.31 22.06 4339.89 4283.59 2675.35 3117.80 6019201.10 572221.50 MWD+IFR+MS 6408.71 70.26 18.65 4357.00 4300.70 2717.76 3133.53 6019243.65 572236.83 MWD+IFR+MS 6447.40 73.16 16.55 4369.15 4312.85 2752.77 3144.63 6019278.76 572247.61 MWD+IFR+MS 6508.21 76.57 15.72 4385.02 4328.72 2809.15 3160.94 6019335.28 572263.39 MWD+IFR+MS 6541.72 78.91 15.27 4392.14 4335.84 2840.71 3169.68 6019366.91 572271.84 MWD+IFR+MS 6603.79 85.41 13.53 4400.60 4344.30 2900.23 3184.96 6019426.57 572286.56 MWD+IFR+MS 6651.80 85.16 13.37 4404.55 4348.25 2946.77 3196.09 6019473.21 572297.26 MWD+IFR+MS 6699.05 86.22 13.49 4408.10 4351.80 2992.59 3207.03 6019519.13 572307.78 MWD+IFR+MS 6743.22 89.21 12.90 4409.86 4353.56 3035.56 3217.11 6019562.18 572317.45 MWD+IFR+MS 6795.56 90.28 11.60 4410.09 4353.79 3086.71 3228.21 6019613.42 572328.08 MWD+IFR+MS . Halliburton Global . Survey 6845.39 91.93 11.13 4409.13 4352.83 3135.55 3238.03 6019662.35 572337.44 MWD+IFR+MS 6891.52 90.66 10.25 4408.09 4351.79 3180.86 3246.58 6019707.74 572345.57 MWD+IFR+MS 6937.40 90.41 8.21 4407.66 4351.36 3226.15 3253.94 6019753.08 572352.51 MWD+IFR+MS 6988.26 90.31 7.47 4407.34 4351.04 3276.53 3260.88 6019803.52 572358.98 MWD+IFR+MS 7032.65 88.94 6.42 4407.63 4351.33 3320.59 3266.25 6019847.63 572363.94 MWD+IFR+MS 7084.15 88.44 6.19 4408.81 4352.51 3371.77 3271.90 6019898.85 572369.12 MWD+IFR+MS 7130.29 87.82 5.80 4410.31 4354.01 3417.63 3276.72 6019944.75 572373.51 MWD+IFR+MS 7179.78 89.33 5.65 4411.54 4355.24 3466.85 3281.65 6019994.01 572377.98 MWD+IFR+MS 7225.95 90.01 6.45 4411.81 4355.51 3512.77 3286.52 6020039.96 572382.42 MWD+IFR+MS 7273.20 91.05 4.65 4411.37 4355.07 3559.79 3291.09 6020087.02 572386.56 MWD+IFR+MS 7322.13 91.83 4.20 4410.14 4353.84 3608.56 3294.86 6020135.82 572389.88 MWD+IFR+MS 7369.63 90.71 2.78 4409.09 4352.79 3655.96 3297.75 6020183.24 572392.33 MWD+IFR+MS 7419.57 91.34 1.31 4408.20 4351.90 3705.85 3299.53 6020233.15 572393.65 MWD+IFR+MS 7464.49 91.76 0.74 4406.98 4350.68 3750.75 3300.34 6020278.05 572394.03 MWD+IFR+MS 7512.86 92.20 1.31 4405.31 4349.01 3799.08 3301.20 6020326.38 572394.45 MWD+IFR+MS 7560.79 92.40 2.98 4403.39 4347.09 3846.94 3302.99 6020374.25 572395.80 MWD+IFR+MS 7608.42 91.27 4.10 4401.86 4345.56 3894.45 3305.93 6020421.78 572398.29 MWD+IFR+MS 7656.98 90.85 4.08 4400.96 4344.66 3942.88 3309.40 6020470.23 572401.31 MWD+IFR+MS 7705.60 89.90 4.39 4400.64 4344.34 3991.37 3312.99 6020518.75 572404.45 MWD+IFR+MS 7753.30 89.67 4.14 4400.82 4344.52 4038.93 3316.53 6020566.34 572407.55 MWD+IFR+MS 7802.28 89.67 4.21 4401.11 4344.81 4087.78 3320.10 6020615.22 572410.67 MWD+IFR+MS 7849.29 89.49 3.22 4401.45 4345.15 4134.69 3323.15 6020662.15 572413.28 MWD+IFR+MS 7896.84 90.61 2.90 4401.41 4345.11 4182.17 3325.68 6020709.64 572415.37 MWD+IFR+MS 7943.61 92.15 2.86 4400.28 4343.98 4228.87 3328.03 6020756.36 572417.29 MWD+IFR+MS 7992.16 93.26 3.62 4397.99 4341.69 4277.29 3330.77 6020804.79 572419.58 MWD+IFR+MS 8039.46 94.20 6.32 4394.91 4338.61 4324.31 3334.86 6020851.84 572423.23 MWD+IFR+MS 8089.28 91.56 8.55 4392.41 4336.11 4373.64 3341.30 6020901.23 572429.21 MWD+IFR+MS 8137.62 88.12 9.45 4392.55 4336.25 4421.37 3348.86 6020949.03 572436.33 MWD+IFR+MS 8185.19 87.07 9.18 4394.54 4338.24 4468.27 3356.55 6020995.99 572443.59 MWD+IFR+MS 8233.94 87.32 8.72 4396.93 4340.63 4516.37 3364.13 6021044.15 572450.71 MWD+IFR+MS 8282.13 87.08 8.29 4399.28 4342.98 4563.98 3371.25 6021091.82 572457.39 MWD+IFR+MS 8329.92 87.00 7.95 4401.75 4345.45 4611.22 3377.99 6021139.12 572463.69 MWD+IFR+MS 8376.81 88.09 9.19 4403.76 4347.46 4657.55 3384.97 6021185.50 572470.24 MWD+IFR+MS 8425.60 88.77 9.26 4405.09 4348.79 4705.69 3392.79 6021233.71 572477.61 MWD+IFR+MS 8472.69 89.04 9.11 4405.99 4349.69 4752.16 3400.30 6021280.25 572484.69 MWD+IFR+MS 8522.22 93.14 7.44 4405.05 4348.75 4801.16 3407.43 6021329.30 572491.37 MWD+IFR+MS 8568.79 99.87 5.67 4399.78 4343.48 4847.10 3412.71 6021375.28 572496.22 MWD+IFR+MS 8618.65 101.37 5.77 4390.59 4334.29 4895.86 3417.60 6021424.08 572500.65 MWD+IFR+MS 8665.10 101.27 5.67 4381.47 4325.17 4941.18 3422.14 6021469.44 572504.77 MWD+IFR+MS 8712.83 100.77 5.34 4372.35 4316.05 4987.81 3426.63 6021516.11 572508.83 MWD+IFR+MS 8738.98 100.72 4.51 4367.47 4311.17 5013.41 3428.84 6021541.72 572510.80 MWD+IFR+MS 8810.00 100.72 4.51 4354.26 4297.96 5082.97 3434.32 6021611.32 572515.64 PROJECTED to TD . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPE-31 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,992.16' MD 8,002.00' MD 12,787.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Signed .1/J ()jLJ Date )/~J ~ì- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) 16-Jul-05 ). (j )- - ~ 1 ~ r=:1 . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPE-31 PB1 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 7,992.16' MD 8,039.46' MD 8,810.00' MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 1/_ J f) / { ~I Date J I/~ ~o- Signed (\N 1tn-vJ.- UfctiL.-1- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager AUachment(s) 16-Jul-05 ~ OS' -C;ì 2. F~ -- STATE OF ALASKA . OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Hm regQcq¿admín.state.ak.us ac,gCG prudhoe bay@adm¡n.state.ak.us bob f;ecke[1ste¡ncq¿admín.state.ak.us Rig No.: 14 DATE: 6/12/2005 Rig Phone: 670-3270 Rig Fax: 670-3269 Op. Phone: 670-3268 Op. Fax: 670-3269 1/28/04 Contractor: Doyon Rig Rep.: Egholm / Shones Operator: BP Rep.: Vaughn / Brown Field/Unit & Well No.: MP E-31 Location: Section: Operation: Drlg: Test: Initial: XXXXXXX Test Pressure: Rams: 250/3500 MISC. INSPECTIONS: Test Result Location Gen.: P Housekeeping: P PTD On Location P Standing Order Posted P BOP STACK: Quantity 1 1 1 1 1 2 1 o Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve MUD SYSTEM: Visual Test Trip Tank P Pit Level Indicators P Flow Indicator P Meth Gas Detector P H2S Gas Detector P 25 Well Sign Dr!. Rig Hazard Sec. Size 13 5/8 2-7/8 x 5 3-1/2 x 6 Blind 31/8 31/8 31/8 Alarm Test P P P P P PTD # 205-072 Township: 13N Workover: Weekly: Annular: 250/2500 TEST DATA UM 10E Meridian: Range: Explor. : Other: Valves: 250/3500 Test Result P P P FLOOR SAFETY VALVES: Quantity Test Result Upper Kelly 1 P Lower Kelly 1 P Ball Type 1 P Inside BOP 1 FP Test Result P P P P P P P NA CHOKE MANIFOLD: Quantity Test Result No. Valves 14 P Manual Chokes 1 P Hydraulic Chokes 1 P ACCUMULATOR SYSTEM: Time/Pressure Test Result System Pressure 2900 P Pressure After Closure 1800 P 200 psi Attained 32 P Full Pressure Attained 3 min 13 sec P Blind Switch Covers: All stations P Nitgn. Bottles (avg): 4 @ 2150 Test Results Number of Failures: 1 Test Time: 4.5 Hours Components tested Repair or replacement of equipment will be made within 1 days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: Hm reggcq¿admín.state.ak.us Remarks: Dart valve failed test - Will replace with new Dart valve today 6/12/2005. 24 HOUR NOTICE GIVEN YES x NO Waived By Chuck Scheve Date 06/10/05 Time 14:00 hrs Witness L Brown Test start 2:00 Finish 6:30 BOP Test (for rigs) BFL 1/28/04 BOP Doyon 14 6-12-05-1.xls \ . !ill . AI,ASIiA OIL AlQ) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Fred Johnson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPE-31 BP Exploration (Alaska) Inc. Permit No; 205-072 Surface Location: 3960' NSL, 2014' WEL, SEe. 25, T13N, RlOE, UM Bottomho1e Location: 3981' NSL, 3790' WEL, SEC. 19, T13N, RIlE, UM Dear Mr. Johnson: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was e oneous1y issued. Operations must be conducted in accordance with AS 31. 5 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifi ally authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Ti Ie 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms d conditions of this permit may result in the revocation or suspension of the permit. Pleas vide at least twenty-four (24) hours notice for a representative of the Corrunission to . es any required test. Contact the Commission's petroleum field inspector at 659-3 (p r). DATED this iL day of May, 2005 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. II Drill 0 Redrill 1a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 3960' NSL, 2014' WEL, SEC. 25, T13N, R10E, UM / Top of Productive Horizon: 1470' NSL, 4114' WEL, SEC. 19, T13N, R11 E, UM Total Depth: 3981' NSL, 3790'WEL, SEC. 19, T13N, R11E, UM I 4b. Location of Well (State Base Plane Coordinates): Surface: x- 569129 / y- 6016497 ./ Zone- ASP4 16. Deviated Wells: Kickoff Depth: 400 ./ feet Maximum Hole Angle: 95 degrees 1 .' STATE OF ALASKA . AlAS~ Oil AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 Cj Cons. Cornmission 11 b. Current Well Class 0 Exploratory II Development Oil 1Th~a~one o Stratigraphic Test 0 Service 0 Development Gas 1:1' Single Lone 5. Bond: a Blanket 0 Single Well 11. Well Name and Number: Bond No. 2S100302630-277 MPE-31 6. Proposed Depth: 12. Field I Pool(s): MD 9034 TVD 4393 Milne Point Unit / Schrader Bluff 7. Property Designation: ''I) f/.t)t;;,·..;;..,r"'ADL 047438 h -þÇ' _ t>v'::Þ""'''''' >. 8. Land Use Permit: RECEIVr::6qro MAY 0 3 2005 13. Approximate Spud Date: May 28,2005 9. Acres in Property: 2560 14. Distance to Nearest Property: 3600' 18. Casing Program: Size Casing 20" 10-3/4" 7-5/8" Hole 42" 13-1/2" 9-7/8" 6-3/4" Weight 92# 45.5# 29.7# 15.2# Specifications Grade Coupling H-40 Weld L-80 BTC-M L-80 BTC-M L-80 Length 114' 3289' 2547' 2697' 10. KB Elevation Planned = 15. Distance to Nearest Well Within Pool (Height above GL): 57.8 feet 200' from MPB-15 17. Maximum Anticipated Pressures in psig (see 20 MC 25.035) Downhole: 1882./ Surface: 1442./ Setting pepth .. . Quantity of9èm~nt Top Bottom (c.f.or sacks) MD TVD MD TVD (including stage data) Surface Surface 114' 114' 260 sx Arctic Set (Approx.) Surface Surface 3289' 2658' 540 sx Arcticset Lite, 473 sx 'G' Surface Surface 6487' 4368' 443 sx Class 'G' 6337' 4326' 9034' 4393' Sand Screen Liner 4" 19. PRESENT WELL CONDITION SUMMARY (To be completed forRedrill ANDR~entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD (ft): Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments 181 Filing Fee, $100 0 BOP Sketch 181 Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): a Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program o Shallow Hazard Analysis 18120 MC 25.050 Requirements Date: Perforation Depth MD (ft): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Title Senior Drilling Engineer Contact David Johnson, 564-4171 Signature Phone 564-5427 Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill Number: 20 Conditions of Approval: API Number: ~ ~ I Permit Approval 50- 02-1 - 2- v 2b ::.; ~ Date: Samples Required 0 Yes ~No Mud Log Required 0 Yes g(No S Ifide Measures 0 Yes 8No Directional Survey Required ~es 0 No ~. 50'~\~M<'\\"'~ o<..~~~\~ ~ð~~,-:>S-,(jSS\~Q~ lJ ~'çl G \ t\l A L APPROVED BY THE COMMISSION DaleØ!~ - bp· . I Well Name: I MPE-31 I Schrader NC/ND Horizontal Producer Drilling and Completion Plan Summary I Type of Well: I Schrader Bluff NC/NO Sand Horizontal Producer Distance to Property line Distance to nearest well 3,960' FSL and 2,014' FEL ,- Section 25, T13N, R10E UM E = 569, 129' ~ N = 6,016,497' ~. 1,470' FSL and 4,114' FEL Section 19, T13N, R11 E UM E = 572,230' N = 6,019,316' Z = 4,368' TVD 1,848' FSL and 3,999' FEL Section 19, T13N, R11E UM E = 572,340' N = 6,019,695' Z = 4,388' TVD 2,402' FSL and 3,922' FEL Section 19, T13N, R 11 E UM E = 572,409' N = 6,020,250' Z = 4,348' TVD 2,652' FSL and 3,898' FEL Section 19, T13N, R11 E UM E = 572,430' N = 6,020,500 Z = 4,348' TVD 3,236' FSL and 3,855' FEL Section 19, T13N, R11 E UM E = 572,465' N = 6,021,085 Z = 4,408TVD 3,981' FSL and 3790' FEL Section 19, T13N, R11 E UM E = 572,520' N = 6,021,830 Z = 4,393'TVD 3,600' 200' from MPB-15 Surface Location: (As Proposed) T1 - Base NB T2 - Base NO T3 -Mid NC T4 -Mid NC T5 -Lower NO T6 - Top NC (TO) AFE Number: I Estimated Start Date: 1 May 28, 2005 Rig: I Doyon 14 Rig days to complete: I 12 MD: I 9,034' I TVD: 14,393' 1/ I Max Inc:195° Well Design: Slimhole Objective: Schrader Bluff NC/NO I I KOP: 1400' I I KBE: 157.8' Page 1 . , . Mud Program: 13-1/2" Surface Hole 8.6-9.8 1 0 - 25 Spud API Filtrate· .. Chlorides (mQ/l) 30 - 50 8.5 - 9.5 NC-8 < 1000 /' LSND 9-7/8" Intermediate Hole Density (ppg 8.8 - 9.4 8 - 15 API Filtrate 26 - 32 9.0 - 9.5 6 - 8 < 25 MOBM - 9,034'): HTHP Fluid Loss . (m1l30 min) . 9.0 - 9.2 15 - 24 15 - 21 < 8 80:20 550 - 900 ./ Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to 08-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. - Casingrrubing Program Hole Csg WtlFt Grade Conn Burst Collapse Length Top Bottom Size Diam psi psi Feet MDI TVDrkb MDI TVDrkb 42 20 92 H-40 Weld 1530 520 114 0 114/114 13.5 10.75 45.5 L-80 BTC-M 5210 2480 3,289 0 3,289/ 2,658' 9.875 7.625 29.7 L-80 BTC-M 6890 4790 2,547 0 6,487/4,368 6.75 4 inch 15.2 L-80 2,697 6,337/4,326 9,034/ 4,393 Screens Cement Program: Casing Size Basis Total Cement Volume: 463 bbl Casinq Size Basis Total Cement Volume: 35 bbl 10-3/4",45.5#, L-80, BTC Surface Casing Tail cement = 1000' MD above shoe. 40% Excess over Gauge Hole Lead to surface. 40% Excess over Gauge Hole to PF, 150% Excess over Gauge Hole from PF to Surface 5 bbl water Wash 20 bbl CW 100 Spacer 50 bbl of .MudPush Lead 369 bbl, 540 sx of ArcticSet Lite: 11 ppg and 3.83 ft;j/sx Tail 98 bbl, 473 sx "G" mixed at 15.8lb/gal & 1.17 ft;j/sx 7-5/8",29.7#, L-80, BTC-M Intermediate Casing Tail cement = 500' MD above the TUZC. 40% Excess over Gauge Hole Wash Spacer Tail Temp 5-bbl water 10 bbl CW 100 20 bbl of MudPush 92 bbl, 443 sx "G" mixed at 15.8 Ib/gal & 1.17 ft;j/sx BHST =80°F from SOR Page 2 . Evaluation Program: 13-1/2" Section Open Hole: . · Gyro · MWD/GR/DIR · IFR/CASANDRA, · Sperry InSite 9-7/8" Section Open Hole: · MWD/GR/RES/DIR / · IFR/CASANDRA, · Sperry InSite Cased Hole: 6-3/4" Section Open Hole: · MWD/GR/RES/DIR ,/ · NEU/DEN/PWD / · IFR/CASANDRA, · Sperry InSite Cased Hole: Formation Markers: Formation Tops MD TVD Pore Pressure EMW (ft) (ft) (psi) (Ib/gal) BPRF 2131 1938 816 8.35 Top Ugnu (TUlC) 5330 3868 1,654 8.35 Ugnu-MA 5774 4103 1,756 8.35 Ugnu-MB 1 5806 4118 1,763 8.35 Ugnu-MB2 5955 4183 1,791 8.35 SBF2-NA 6327 4323 1,852 8.35 SBF1-NB 6409 4348 1,863 8.35 SBE4-NC 6488 4368 1,871 8.35 SBE2-ND 6534 4378 1,876 8.35 TD 9034 4393 1,882 8.35 Recommended Bit Program: BHA Hole Size Depth (MD) Footage Bit Type TFA GPM 1 13-1/2" o - 3289' 3289' Baker Hughes MX-1 2 9-7/8 3,289' - 6,487' 3,198' 3 6.75" 6,487' - 9,034' 2547' Hycalog DSX-146 Page 3 . Well Control: . Surface Hole: A diverter will be rigged up on E-31. The header layout on E-Pad does not allow room to run the required 75' length diverter line as there is not sufficient clearance to run the diverter line thru the header. This will require a shorter diverter length of 50' and the end of the diverter will be approximately 15' from the header. A variance is requested for the shorter diverter line length. A notification procedure will be posted on the rig for an emergency shut down of E-pad in the event it is necessary to divert the well. See attached procedure. Intermediate/Production hole: · Maximum anticipated BHP: · Maximum surface pressure: · Planned BOP test pressure: · Integrity tests: Kick tolerance: · Integrity tests: · Planned completion fluid: 1,882 psi at 4,393' TVD (ND Sand) ../ 1,442 psi at (Based on a full column of gas at 0.1 psi/ft) ..r 3,000 psi ,- FIT to 10.5 Ib/gal 20' below the 10-3/4" shoe. 50 Bbls with 9.4 Ib/gal mud at below the 10-3/4" shoe. FIT to 10.5Ib/gaI20' below the 7-5/8" shoe. Kill Weight Brine with diesel cap. Drilling Hazards & Contingencies: · Running Gravel/heavy clay problems have been encountered in some E-Pad wells. High Vis Mud should be utilized. · Hydrates have been reported on E-Pad. Expected Depth for hydrates 2000' SS to 2500' SS. ~ Keep the Mud as Cool as possible. Lost Circulation Lost Circulation is not reported as a major problem for E-Pad. Irregardless, of this good drilling practices need to be maintained. Expected Pressures · All Formation are expected to be normally pressured: 8.35 ppg or less. Pad Data Sheet · Please Read the E-Pad Data Sheet thoroughly. Hydrocarbons · Hydrocarbons are possible in the Ugn~ & Schrader Bluff interval. /" Faults · Four (4) faults are mapped in the well. Fault #1 in the Lower SV intermediate hole section at 4470' MD (3300' TVDss). Fault #2 is within the Lower Ugnu intermediate hole section at 5680' MD (4000' TVDss). Fault #3 is in the NC Lateral production hole interval at 7300' MD (4300' TVDss). Fault #4 is in the ND Lateral production hole interval at 8200' MD (4345' TVDss). Hydrogen Sulfide · MPE Pad is not designated as an H2S Pad, H2S detected from E-Pad wells on the pad: MPE-17 ~ 51 ppm 2/2001 MPE-22 46 ppm 2/2001 MPE-04 \¡... Q..W~\\~ 5 ppm 2/2001 MPE-10 >2 ppm 2/2/01 Page 4 A' t" II"" I · · n I-CO ISlon ssues · MPE-31 passes the Major Risk Criteria except for MPE-30. This passes the 1/200 minor risk. MPE-31 passes MPE-30 within 143' at 871' TMD and passes MPE-30A within 125' at 7573'. MPE-30 is a OA sand producer · The gyro surveys will be taken to confirm the BHL as soon as practical and to avoid proximitfTssues in the surface hole. Survey program will require IFR/CASANDRA - .... corrected MWD surveys " Distance to Nearest Property · MPE-31 is planned to be 3600 ft from the nearest Milne Point property line. ,/ Distance to Nearest Well Within Pool · MPE-31 is 200 ft from the nearest sand penetration in the MPB-15. Page 5 DRILL & COM~ETION PROCEDURE · Pre-Ria Operations 1. The 20" conductor will be installed pre-rig. Drillina: 1. MIRT and NU Diverter. 2. Function Test Diverter, PU 4" DP and BHA. 3. Drill 13-1 12" surface hole to the Schrader Bluff interval. 4. Run and cement 10-3/4" surface casing. 5. NO diverter, install wellhead and NUfTest BOPE. 6. Drill 9-7/8" hole to intermediate casing point. 7. Run and cement 7-5/8" intermediate casing. 8. Drill 6-3/4" Horizontal Interval. 9. Run and set 4" Screens. 10. Run a 2-7/8" ESP Completion 11. NO BOP/NU Tree. 12. Freeze Protect With Diesel 13. RD & MO Doyon 14. Page 6 Doyon 14"ontingenCy Plan for u!g Diverter line E-Pad · Doyon 14 rig will have a Mine Point radio and will have met with E~Pad operator(s) and informed them of the placement of their Divert Line, who in turn will inform ALL personnel who will be doing work on the pad. Nabors 4ES, contractors etc. · This Divert Line will have to be run under LIVE lines. Production, Test and Injection, due to space constraints on the pad. · In the event of using Divert Line, Doyon rig will call Milne Point control room board operator and request an ESD of E-Pad. · Doyon rig will then call Milne Point radio and inform them of action taken and why. Milne Point radio will make an announcement of restricted access to E-pad. · Control room board operator will notify E and S-Pad operators and then initiate ESD for the pad shutting down production from all wells and all injection as well. The control room operator will also cut off electrical power to the pad. · The control room will then shut in XV-5873A the perimeter gas injection valve for E- Pad. · The control room board operator will shut in water injection for Sand E-Pads with the corresponding perimeter valve XV-5310. To make up for the loss of injection, board operator may have to divert water to B~50 injection well. · Doyon rig will then correspond with E-Pad operator about situation who will then account for all personnel under their authority and direct them to safe area. S~Pad operator will make required adjustments for loss of water injection. · E-Pad operator will then verify pad is in ESD mode and all wells and corresponding equipment did in fact shut in and ALL ESP's shut down. · In the event that Nabors 4ES is also on the pad they will have to be notified of any such action. · Once situation has been rectified Doyon rig will the notify the E-Pad operator, the control room board operator and Milne Point radio so provisions can be made to bring the pad back on line. Page 7 ~o>.o ,?O'~'\ "',\..~<¿, (L ~+ . ------ MPU E-PAD I I o o d o o w N 1800.00 + 27 . 10. 28 . 22 . 29i . 13 . 26 . 9· 25 . 11 . 18. 20 . 24 . 14 . 15. 3. .8 .33 .2 .. E-32 .. E-31 . 4 . 1 .5 .30 .6 .21 .7 .16 .23 .19 .12 .17 ---- LEGEND -$- AS-BUILT CONDUCTOR . EXISTING WELL CONDUCTOR NOTES o o d o '" ¡:; + N 2600.00 I I I I I I I I I I ----1 + 1. ALASKA STATE PLANE COORDINATES ARE ZONE 4, ALASKA, NAD 27. 2. PAD SCALE FACTOR IS 0.9999054. 3. HORIZONTAL AND VERTICAL CONTROL IS BASED ON MONUMENTS CFP-3 AND E-1. 4. ELEVATIONS ARE BPX MILNE POINT DATUM M.S.L. 5. GEODETIC COORDINATES ARE ALASKA ZONE 4, NAD 27. 6. REFERENCE FIELD BOOK: MP05-01 PGS. 20-24. DATE OF SURVEY: APRIL 30, 2005. . o v 'r :<I' co ,." ~~ ~ fJ ~~'~ 2\;FP _,;.: Q . I \ E =>AD ~ ~ ~~~. ~ ~ tt:~ VICINITY MAP N.T.S. ,- III¡- I SURVEYOR'S CERTIFICATE I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF MAY 1, 2005. LOCATED WITHIN PROTRACTED SEC. 25, T. 13 N., R. 10 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC GEODETIC CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) ELEVATION OFFSETS Y= 6,016,497.19 /N 2300.03 70'27'19.552" 70.4554311' 3,960' FSL ./ MPE-31 X= 569,128.95'/ E 1445.83 149'26'09.075" 149.4358542" 22.1 2,014' FEL / Y=6,016,520.62 N 2,329,92 70'27'19.784" 70.4554956" 3,984' FSL MPE-32 x= 569,110.40 E 1,446.03 149'26'09,613" 149.4360036" 22.5 2,032' FEL o "/01/05 ISSUED FOR AS-BUILT INFORMAl1ON NO. DATE REVISION ~~b_' DRAv.N: HACKLEMAN ObP CHECKEC[O'H DATE' 5/01/05 DRA v.1NG: SHEET: FRB05 MPE 04-00 MPU E-PAD ¡ ffi~~œo JOB NO: SCALE: WELL CONDUCTOR AS-BUILT 1 OF 1 K'Mi LO'H EHGIMEERSANOL..ÞHDSlIR'Æ'I'tR; MPE-31 & MPE-32 110I 'lEST F1R£WŒO lANE: 1"-200' BY OiK MCtiOR~AI.ASKA 911I:103 Field: Milne Point Pad: E-Pad DIR I LWD MWD OH LOGS NONE NONE NONE Gyro MWD/GR IFRlCASANDRA InSite FORM Permafrost . BP EXPLORATION MPE-31 Horizonatl Scrader Bluff NCIND Producer DEPTH MD TVD 114' Base Permafrost 2,131' 1,936' Top of Tail Cement 2,289' MWD/GRlRES IFRlCASANDRA InSite Casing Point 3,289' 2,658' Top of Tail Cement 4,830' MWD/GRlRES NEUIDEN PWD IFRlCASANDRA InSite 4/28/2005 Top Of Ugnu Top of NA Top of NB Top of NC 5,330' 3,868' 6,327' 4,323' 6,409' 4,348' 6,488' 4,368' Ca8Ing PoInt 6.487" 4.368' Top of ND 6,534' 4,378' Ca8Ing PoInt 9.034' 4,393' ~\Iî . I~ '~f: ~" ~, ~ II ~ I ~ ~ I ;~ f. ,¡,~, Ii ,'.\' ~ ~; :'j 11 ,,7:~:: . ENG: D. Johnson RIG: Doyon 14 RKB: 68' HOLE CASING Cement Slurry SIZE SPECS INFO 20.000-in Wellhead 91.1-lbIft H-40 FMC Big Bore Welded, Insul Surface Caa Cement Slurrv 10-314' Lead Cement 100% Excess in PF 45.5 IbllI 369 Bbls, 540 sx 40% Excess L-80, BTC-M 10.7 ppg Below PF Int. Yield 5280 psi 3.83 ft3Isx Test Csg to CoIlaspse 2480 psi 1000 psi Drift - 9.950' Tail Cement 98 bbls, 473 sx 15.8 ppg 40% Excess 1.17 ft3Isx Inter. Casino 7-518' 29.7 Ibslft L-80, BTC-M Int. Yield 6890 psi CoIlaspse 4790 psi Drift - 6.875' Cement Slurrv IIi! 92 Bbls, 443 sx 15.8 ppg 1.17 ft3fsx Test Csg to 1500 psi Prod. Liner 4' Screened liner Cement Slurrv Test Csg to o psi 6-314' MPE-31 Well Plan Schematic.xls 9.2 PPG MOBM below Centrilift ESP Packer & 04126/2005 D.Johnson KB Cameo 2 7/S" x 1" GLM -150' 2-7/8" 6.5 ppf, {Drift tD ::::: 2.347", EUE ::::: 0.00579 Cameo 2 7/S" x 1" GLM -2000TVD' ..... MD 45.51 BYC ::::ameo 2 7/S" x 1" GLM 2 Jts above ESP 2 7/8" XN Nipple. 1 Jt above ESP 6-314'" IIIB Udeml Screens 6481 ~ WELL: E-31 " CO!\WANY DETAILS REfERENCE INfORlvtATION SURVCY PROGRAM BPAm\Jcü rru~'No!1h Ikpú¡ Fm Depth Tu Surv.:y!P!an 34-.30 9ûO.()() 9ÜO,OÜ 9034.04 CASING DETAILS FORMATfON TOP DETAILS No. TVDPath MDPath Formatìon I 1937.80 2 [31.30 BPRF 2 3867.80 5330.41 TUZC 3 4102.80 5774.24 Ugnu-MA 4 4117.80 Ugnu-MBI 5 4] 82.80 Ugnu-MB2 6 4322.80 SBF2-NA 7 4347.80 SBFI-NB 8 4367.80 SBE4-NC 9 4377.80 SBE2-ND No. TVD MD Name Size See MD ]ne 30{J' MD. i1()O'TVD I 34.30 2 300.00 3 4 5 6 7 8 9 ]0 68.00 ] I 68.00 12 76.89 13 76.89 14 89.80 15 89.80 16 91.00 17 95.23 18 95.23 19 91.00 20 89.80 21 89.80 22 91.00 23 79.42 24 79.42 25 90.00 26 9l.l7 27 91.17 3289.22 95/8" 6487.00 7" 4392.80 9034.00 5" 9.625 7.000 5.000 o : 500' MD. 499.91'TVD Stali Dir 3/100': 62{J' MD. 6 I 953'TVD 900 : 1820' MD. 1699.33' TVD : 2147.22' MD, 1950'TVD 1800 ]' '" "" "" 2, ..c: 15. 8 B "€ > " " ?: : 5258.15' MD, J825A'TVD 'hw¡ Azi 0.00 0.00 54.00 54.00 54.00 54.00 54.00 34.30 300.00 499.91 619.53 1595.72 1699.33 1950.00 2182.64 3825.40 4224.45 4300.47 4367.80 21.00 21.00 20.04 20.04 16.30 16.30 13.00 6.77 6.77 5.00 5.49 5.49 3.90 4.77 4392.80 Plan: MPE-31 wp09 (Plan MPE-3 UMPE~3!) CrcatçJ By Digital Business Client Usel Date: 4/5/2005 TVD SECTION DETAILS eN/-S 0.00 0.00 3.08 8.61 240.44 +E/-W 0.00 0.00 4.24 11.85 330.93 3127.00 3133.67 3440.54 Checked· Date" Dak: VSee Target 0.00 MPE-3I TI MPE-3] 1'2 MPE-31 T3 MPE-31 T4 MPE-3] T5 MPE-3] T6 Rcvíewt'J DLeg TEace 0.00 0.00 0.00 0.00 UO 54.00 2.50 0.00 3.00 0.00 UO 360.00 0.00 0.00 4.00 0.65 0.00 0.00 4.00 -72.66 0.00 0.00 4.00 -6.01 0.00 0.00 10.00 -16.32 0.00 0.00 4.00 4.00 0.00 4.00 -157.29 4.00 157.75 0.00 0.00 4.00 -53.05 4.00 179.62 0.00 0.00 5.00 -O.iO 5.00 34.6] 0.00 0.00 TARGET DETAILS Name TVD TN/-S ¡··E/-W Northing Easting Shape MPE-31 T3 4347.80 3315.00 6020249.8 ! Point MPE-3] T4 4347.80 3338.19 6020500.00 Point MPE-31 TI 4367.80 2790.00 3127.00 60]9315.93 Point MPE-31 T2 4387.80 3168.07 3240.72 6019695.00 Point MPE-3 I T6 4392.80 5301.51 3440.54 602]830.00 Poìnt MPE-31 T5 4407.80 4556.98 3378.62 6021085.00 Point WELL DETAiLS N,1Jnl;' Nonhing [astiug Lalj¡uJ~' L,mgiIUJ.: Sio! P!anMPL-31 27ÜLÔb -2XÚ,47 (;016497.30 569 1 29.!2 !49~26'09.OìOW N/A Start Dir4;iOO': 6264.15' MD. 4300.47'TVD 3600 Start Dir i O!!OO': 6507.62' MD. 4372.34'TVD EndDir : 664L9i'MD.438H7'TVD Start Dir 4/!OO' : 6796.48' MD. 438S.4l'TVD : 7072.37' MD. 4377.57' TVD 4500 I j ¡ ! ¡ ! ¡ ¡ ¡ ! ! ¡ ¡ , I ' 900 ! ! ¡ ¡ ! ! ! , I ' 1800 3600 4500 Vertical Section at 32.98" [900Jliin] 6300 34.04' MD. 4392.8' TVD , I ' 7200 ! ¡ ! I ! ! Plan: MPE-3! wp09 (Plan MPE~3l/]vîPE-3 Crcatçd By: Digita! Hus.ìness Client User Date: 4/5/2 Ch¡;:cked: Date: SURVEY PROGRAM Depth I'm D¡:pth To !'oo! 900.0n 9ü34.0, N;1 E/-W NOl1hjng L Long! 51; PI; " 2701.66 6O!Ú497,30 149"2Ú'Ü9.o?OW TARGET DETAilS Name TVD ¡-N/-S +E/-W Northing Basting Shape Faultl 385.50 1859.71 6016900.00 570985.00 Fault2 2158.77 2611.27 6018680.00 571720.00 FauJt3 3406.97 3362.95 6019935.00 572460.00 1'3 3722.26 3315.00 6020249.81 572409. J3 T4 3972.28 3338.19 6020500.00 572430.00 Fault4 4208.73 3 I 85.36 6020735.00 572275.00 TI 2790.00 3127.00 6019315.93 572229.80 Po .01 29 I 6.25 6019215.00 572020.00 T2 .07 3240.72 6019695.00 572340.00 T6 .51 3440.54 6021830.00 572520.00 Fa .48 3094.75 6020130.00 572 I 90.00 Fa .92 6020270.00 572790.00 T5 .98 602 I 085.00 572465.00 CASING DETAILS No, TVD MD Name Size I 2657.80 3289.22 95/8' 9.625 2 4367.66 7" 3 4392.80 5t1 FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1937.80 2131.30 BPRF 2 5330.41 rulC 3 5774.24 Ugnu-MA 4 41 5806.47 UgnucMB 5 4182.80 5955.36 Ugnu-MB: 6 4322.80 6327.20 SBF2-NA 7 4347.80 6408.68 SBFI-NB 8 4367.80 6487.62 SBE4-NC 9 4377.80 6534.28 SBE2-ND SECTION DETAilS Az TVD ¡--N/-S 'E/-W Dleg TFaee VSec Targei 0.00 34.30 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 54.00 3.08 4.24 1.50 4.89 54.00 11.85 2.50 0.00 54.00 330.93 3.00 0.00 3: 289.76 398.81 1.50 360.00 4, 4 J3.39 568.98 0.00 0.00 6. 558.70 769.77 4.00 0.65 8: 54.19 25ï8.67 0.00 0.00 291 21.00 2985.00 4.00 - 72.66 36 0.00 0,00 38 MPE-31 TI MPE-3IT2 MPE-3I1'3 T5 T6 0.00 4.00 lac 3.00 40.00 MD 34.30 300.00 1820.00 9034.04 Sec I 2 3 4 5 6 7 8 9 10 II 12 !3 14 15 16 17 18 19 20 21 22 COMJ.\ANY DETAILS Rl::FERENCE INFORfvlATJON un·',¡1 , , 900 3600 West(-)iEast(+) 5 ~ ~ ¥ ! '5 o (/) · Sperry-SUD . BP Planning Report Company: Field: Site: Well: Wellpath: BP Amoco Milne Point M PI E Pad Plan MPE-31 MPE-31 Date: 4/5/2005 Time: 15:29:44 Page: Co-ordinate(NE) Reference: Well: Plan MPE-31, True North Vertical (TVD) Reference: 34.3+23.557.8 Section (VS) Reference: Well (0.00N,O.00E,32;98Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Plan: MPE-31 wp09 Date Composed: Version: Tied-to: 3/31/2005 107 From Well Ref. Point Principal: Yes Field: Milne Point North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 ~ Goo Datum: NAD27 (Clarke 1866)~ Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 .-/ Well Centre bggm2004 Site: MPlEPad TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6013798.68 ft Latitude: 70 26 52.982 N From: Map Easting: 569440.72 ft Longitude: 149 26 0.655 W Position Uncertainty: 0.00 ft North Reference: True / Ground Level: 0.00 ft Grid Convergence: 0.53 deg Well: Plan MPE-31 Slot Name: old bruzer location Well Position: +N/-S 2701.66 ft Northing: 6016497.30 ft / Latitude: 70 27 19.553 N +E/-W -286.47 ft Easting : 569129.12 ft / Longitude: 149 26 9.070 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 3289.22 2657.80 9.625 12.250 95/8" 6487.00 4367.66 7.000 8.500 7" 9034.00 4392.80 5.000 6.750 5" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 2131.30 1937.80 BPRF 0.00 0.00 5330.41 3867.80 TUZC 0.00 0.00 5774.24 4102.80 Ugnu-MA 0.00 0.00 5806.47 4117.80 Ugnu-MB1 0.00 0.00 5955.36 4182.80 Ugnu-MB2 0.00 0.00 6327.20 4322.80 SBF2-NA 0.00 0.00 6408.68 4347.80 SBF1-NB 0.00 0.00 6487.62 4367.80 SBE4-NC 0.00 0.00 6534.28 4377.80 SBE2-ND 0.00 0.00 Targets Map Map <-- Latitude -> <-- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft MPE-31 Fault1 3357.80 385.50 1859.71 6016900.00 570985.00 70 27 23.342 N 149 25 14.437 W -Polygon 1 3357.80 385.50 1859.71 6016900.00 570985.00 70 27 23.342 N 149 25 14.437 W -Polygon 2 3357.80 1413.37 2104.28 6017930.00 571220.00 70 27 33.450 N 149 25 7.244 W -Polygon 3 3357.80 2043.45 2105.13 6018560.00 571215.00 70 27 39.647 N 149 25 7.214 W -Polygon 4 3357.80 1413.37 2104.28 6017930.00 571220.00 70 27 33.450 N 149 25 7.244 W MPE-31 Fault2 4057.80 2158.77 2611.27 6018680.00 571720.00 70 27 40.779 N 149 24 52.340 W -Polygon 1 4057.80 2158.77 2611.27 6018680.00 571720.00 70 27 40.779 N 149 24 52.340 W -Polygon 2 4057.80 2118.29 3200.97 6018645.00 572310.00 70 27 40.379 N 149 24 35.013 W MPE-31 Fault3 4057.80 3406.97 3362.95 6019935.00 572460.00 70 27 53.052 N 149 24 30.236 W -Polygon 1 4057.80 3406.97 3362.95 6019935.00 572460.00 70 27 53.052 N 149 24 30.236 W -Polygon 2 4057.80 3875.52 2987.25 6020400.00 572080.00 70 27 57.662 N 149 24 41.272 W MPE-31 T3 4347.80 3722.26 3315.00 6020249.81 572409.13 70 27 56.153 N 149 24 31.641 W Company: Field: Site: Well: Wellpath: Targets Name MPE-31 T4 BP Amoco Milne Point MPtEPad Plan MPE-31 MPE-31 MPE-31 Fault4 -Polygon 1 -Polygon 2 MPE-31 T1 MPE-31 Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 MPE-31 T2 MPE-31 T6 MPE-31 Fault5 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 MPE-31 Fault6 -Polygon 1 -Polygon 2 MPE-31 T5 Description Dip. Oir. Plan Section Information MD ft 34.30 300.00 500.00 620.00 1686.67 1820.00 2147.22 2487.96 5258.15 6061.23 6264.15 6487.62 6507.62 6641.91 6796.48 6884.31 7072.37 7330.82 7445.37 7477.65 7646.76 7696.4 7 7986.05 8075.13 8286.79 Inel deg 0.00 0.00 3.00 6.00 38.00 40.00 40.00 53.63 53.63 68.00 68.00 76.89 76.89 89.80 89.80 91.00 95.23 95.23 91.00 89.80 89.80 91.00 79.42 79.42 90.00 Azim deg 0.00 0.00 54.00 54.00 54.00 54.00 54.00 54.19 54.19 21.00 21.00 20.04 20.04 16.30 16.30 13.00 6.77 6.77 5.00 5.49 5.49 3.90 3.98 3.98 3.96 . 4347.80 4357.80 4357.80 4357.80 4367.80 4367.80 4367.80 4367.80 4367.80 4367.80 4367.80 4367.80 4387.80 4392.80 4402.80 4402.80 4402.80 4402.80 4402.80 4402.80 4402.80 4402.80 4407.80 TVD ft 34.30 300.00 499.91 619.53 1595.72 1699.33 1950.00 2182.64 3825.40 4224.45 4300.47 4367.80 4372.34 4387.87 4388.41 4387.80 4377.57 4354.02 4347.80 4347.57 4348.15 4347.80 4371.95 4388.31 4407.80 Sperry-SUD . BP Planning Report TVD ft 3972.28 4208.73 4208.73 4640.87 2790.00 2691.01 2691.01 3498.41 5372.39 5369.94 3356.13 2488.50 Date: 4/5/2005 Time: 15:29:44 Page: 2 Co-ordinate(NE) Reference: Well: Plan MPE-31, True North Vertical (TVD) Reference: 34.3+23.5 57.8 Section (VS) Reference: Well (0.00N,0.00E,32.98Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +N/-8 ft +E/-W ft Map Northing ft Map Easting ft 6020500.00 572430.00 6020735.00 572275.00 6020735.00 572275.00 6021170.00 572585.00 <- Latitude --> <-Longitude-> Deg Min Sec Deg Min See 70 27 58.612 N 70 28 0.938 N 70 28 0.938 N 70 28 5.186 N 70 27 46.985 N 70 27 46.012 N 70 27 46.012 N 70 27 53.952 N 70 28 12.381 N 70 28 12.356 N 70 27 52.551 N 70 27 44.020 N 149 24 30.957 W 149 24 35.445 W 149 24 35.445 W 149 24 26.209 W 149 24 37.178 W 149 24 43.373 W 149 24 43.373 W 149 24 34.766 W 149 24 30.703 W 149 24 22.913 W 149 24 27.606 W 149 24 35.495 W 3168.07 3240.72 6019695.00 572340.00 70 27 50.703 N 149 24 33.832 W 3338.19 3185.36 3185.36 3499.42 3127.00 2916.25 2916.25 3208.78 3346.18 3611.20 3452.49 3184.40 6019315.93 572229.80 6019215.00 572020.00 6019215.00 572020.00 6020025.00 572305.00 6021900.00 572425.00 6021900.00 572690.00 6019885.00 572550.00 6019015.00 572290.00 5301.51 3440.54 6021830.00 572520.00 70 28 11.684 N 149 24 27.930 W 3604.48 3604.48 4829.36 5427.69 4829.36 3738.92 3738.92 4483.31 4556.98 +N/-8 ft 0.00 0.00 3.08 8.61 240.44 289.76 413.39 558.70 1863.74 2415.00 2590.64 2790.00 2808.30 2934.76 3083.12 3168.07 3352.93 3608.51 3722.26 3754.41 3922.74 3972.28 4259.67 4347.03 4556.98 3094.75 3094.75 3126.12 2776.62 3126.12 3696.08 3696.08 3772.99 3378.62 +E/-W ft 0.00 0.00 4.24 11.85 330.93 398.81 568.98 769.77 2578.67 2985.00 3052.42 3127.00 3133.67 3175.12 3218.51 3240.72 3272.95 3303.28 3315.00 3317.95 3334.12 3338.19 3357.98 3364.06 3378.62 6020130.00 572190.00 6020130.00 572190.00 6021355.00 572210.00 6021950.00 571855.00 6021355.00 572210.00 6020270.00 572790.00 6020270.00 572790.00 6021015.00 572860.00 6021085.00 572465.00 70 27 54.996 N 70 27 54.996 N 70 28 7.042 N 70 28 12.928 N 70 28 7.042 N 70 27 56.315 N 70 27 56.315 N 70 28 3.636 N 70 28 4.362 N DLS Build Turn deg/100ft deg/1000 deg/100ft 0.00 0.00 1.50 2.50 3.00 1.50 0.00 4.00 0.00 4.00 0.00 4.00 0.00 10.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 4.00 4.00 0.00 5.00 0.00 0.00 1.50 2.50 3.00 1.50 0.00 4.00 0.00 1.79 1.79 3.98 0.00 9.61 0.00 1.37 2.25 0.00 -3.69 -3.70 0.00 2.40 -4.00 0.00 5.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.06 0.00 -4.13 -4.13 -0.43 0.00 -2.79 0.00 -3.76 -3.31 0.00 -1.54 1.51 0.00 -3.20 0.03 0.00 -0.01 TFO deg 0.00 0.00 54.00 0.00 0.00 360.00 0.00 0.65 0.00 -72.66 0.00 -6.01 0.00 -16.32 0.00 -70.00 -55.67 0.00 -157.29 157.75 0.00 -53.05 179.62 0.00 -0.10 MPE-31 T5 Target MPE-31 T1 MPE-31 T2 MPE-31 T3 MPE-31 T4 149 24 38.116 W 149 24 38.116 W 1492437.179W 149 24 47.446 W 149 24 37.179 W 149 24 20.441 W 149 24 20.441 W 149 24 18.170 W 149 24 29.760 W . Sperry-SUD . BP Planning Report Company: BP Amoco Date: 4/5/2005 Time: 15:29:44 Page: 3 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPE-31, True North Site: MPtEPad Vertical (TVD) Reference: 34.3+23.5 57.8 Well: Plan MPE-31 Section (VS) Reference: Well (0.00N,0.00E,32.98Azi) Wellpath: MpE-31 Survey Calculation Method: Minimum Curvature Db: Oracle Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8315.28 91.17 4.77 4407.51 4585.39 3380.79 5.00 4.12 2.84 34.61 9034.04 91.17 4.77 4392.80 5301.51 3440.54 0.00 0.00 0.00 0.00 MPE-31 T6 Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comment ft deg deg ft ft ft ft deg/100ft ft ft 34.30 0.00 0.00 34.30 -23.50 0.00 0.00 0.00 6016497.30 569129.12 CB-GYRO-SS 100.00 0.00 0.00 100.00 42.20 0.00 0.00 0.00 6016497.30 569129.12 CB-GYRO-SS 200.00 0.00 0.00 200.00 142.20 0.00 0.00 0.00 6016497.30 569129.12 CB-GYRO-SS 300.00 0.00 0.00 300.00 242.20 0.00 0.00 0.00 6016497.30 569129.12 Start Dir 1.5/1 400.00 1.50 54.00 399.99 342.19 0.77 1.06 1.50 6016498.08 569130.17 CB-GYRO-SS 500.00 3.00 54.00 499.91 442.11 3.08 4.24 1.50 6016500.42 569133.33 Start Dir 2.5/1 600.00 5.50 54.00 599.63 541.83 7.43 10.23 2.50 6016504.83 569139.28 CB-GYRO-SS 620.00 6.00 54.00 619.53 561.73 8.61 11.85 2.50 6016506.02 569140.89 Start Dir 3/100 700.00 8.40 54.00 698.89 641.09 14.50 19.96 3.00 6016511.99 569148.94 CB-GYRO-SS 800.00 11.40 54.00 797.39 739.59 24.61 33.87 3.00 6016522.22 569162.76 CB-GYRO-SS 900.00 14.40 54.00 894.85 837.05 37.73 51.93 3.00 6016535.51 569180.69 MWD+IFR+MS 1000.00 17.40 54.00 991.02 933.22 53.83 74.09 3.00 6016551.81 569202.70 MWD+IFR+MS 1100.00 20.40 54.00 1085.61 1027.81 72.87 100.29 3.00 6016571.09 569228.72 MWD+IFR+MS 1200.00 23.40 54.00 1178.39 1120.59 94.79 130.46 3.00 6016593.29 569258.69 MWD+IFR+MS 1300.00 26.40 54.00 1269.08 1211.28 119.53 164.52 3.00 6016618.34 569292.51 MWD+IFR+MS 1400.00 29.40 54.00 1357.45 1299.65 147.03 202.38 3.00 6016646.19 569330.10 MWD+IFR+MS 1500.00 32.40 54.00 1443.24 1385.44 177.22 243.92 3.00 6016676.75 569371.36 MWD+IFR+MS 1600.00 35.40 54.00 1526.24 1468.44 210.00 289.03 3.00 6016709.95 569416.17 MWD+IFR+MS 1686.67 38.00 54.00 1595.72 1537.92 240.44 330.93 3.00 6016740.77 569457.78 Start Dir 1.5/1 1700.00 38.20 54.00 1606.21 1548.41 245.27 337.59 1.50 6016745.67 569464.39 MWD+IFR+MS 1800.00 39.70 54.00 1683.98 1626.18 282.22 388.45 1.50 6016783.09 569514.89 MWD+IFR+MS 1820.00 40.00 54.00 1699.33 1641.53 289.76 398.81 1.50 6016790.72 569525.19 End Dir : 1820 1900.00 40.00 54.00 1760.61 1702.81 319.98 440.42 0.00 6016821.32 569566.51 MWD+IFR+MS 2000.00 40.00 54.00 1837.22 1779.42 357.76 492.42 0.00 6016859.58 569618.15 MWD+IFR+MS 2100.00 40.00 54.00 1913.82 1856.02 395.55 544.42 0.00 6016897.84 569669.80 MWD+IFR+MS 2131.30 40.00 54.00 1937.80 1880.00 407.37 560.70 0.00 6016909.82 569685.96 BPRF 2147.22 40.00 54.00 1950.00 1892.20 413.39 568.98 0.00 6016915.91 569694.19 Start Dir 4/1 00 2200.00 42.11 54.04 1989.79 1931.99 433.75 597.03 4.00 6016936.53 569722.04 MWD+IFR+MS 2300.00 46.11 54.10 2061.58 2003.78 474.59 653.37 4.00 6016977.89 569778.00 MWD+IFR+MS 2400.00 50.11 54.15 2128.34 2070.54 518.21 713.68 4.00 6017022.06 569837.90 MWD+IFR+MS 2487.96 53.63 54.19 2182.64 2124.84 558.70 769.77 4.00 6017063.07 569893.60 End Dir : 2487 2500.00 53.63 54.19 2189.78 2131.98 564.37 777.63 0.00 6017068.81 569901.41 MWD+IFR+MS 2600.00 53.63 54.19 2249.08 2191.28 611.48 842.93 0.00 6017116.52 569966.26 MWD+IFR+MS 2700.00 53.63 54.19 2308.38 2250.58 658.59 908.23 0.00 6017164.23 570031.12 MWD+IFR+MS 2800.00 53.63 54.19 2367.68 2309.88 705.70 973.53 0.00 6017211.94 570095.97 MWD+IFR+MS 2900.00 53.63 54.19 2426.98 2369.18 752.81 1038.83 0.00 6017259.65 570160.82 MWD+IFR+MS 3000.00 53.63 54.19 2486.29 2428.49 799.93 1104.13 0.00 6017307.36 570225.67 MWD+IFR+MS 3100.00 53.63 54.19 2545.59 2487.79 847.04 1169.43 0.00 6017355.07 570290.53 MWD+IFR+MS 3200.00 53.63 54.19 2604.89 2547.09 894.15 1234.73 0.00 6017402.78 570355.38 MWD+IFR+MS 3289.22 53.63 54.19 2657.80 2600.00 936.18 1292.99 0.00 6017445.35 570413.24 95/8" 3300.00 53.63 54.19 2664.19 2606.39 941.26 1300.03 0.00 6017450.49 570420.23 MWD+IFR+MS 3400.00 53.63 54.19 2723.49 2665.69 988.37 1365.32 0.00 6017498.20 570485.09 MWD+IFR+MS 3500.00 53.63 54.19 2782.79 2724.99 1 035.48 1430.62 0.00 6017545.91 570549.94 MWD+IFR+MS 3600.00 53.63 54.19 2842.10 2784.30 1082.59 1495.92 0.00 6017593.62 570614.79 MWD+IFR+MS 3700.00 53.63 54.19 2901.40 2843.60 1129.70 1561.22 0.00 6017641.33 570679.64 MWD+IFR+MS 3800.00 53.63 54.19 2960.70 2902.90 1176.81 1626.52 0.00 6017689.03 570744.50 MWD+IFR+MS 3900.00 53.63 54.19 3020.00 2962.20 1223.92 1691.82 0.00 6017736.74 570809.35 MWD+IFR+MS . Sperry-Sun . BP Planning Report Company: BP Amoco Date: 4/5/2005 Time: 15:29:44 Page: 4 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPE-31,TrueNorth Site: MPtEPad Vertical (TVD) Reference: 34.3+23.5 57.8 Well: Plan MPE-31 Section (VS) Reference: Well (0.00N,0.00E,32.98Azi) Wellpatb: MPE-31 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Inel Azim TVD Sys TVD N/S EIW DLS MapN MapE Tool/Comme..t ft deg deg ft ft ft ft deg/100ft ft ft 4000.00 53.63 54.19 3079.30 3021.50 1271.03 1757.12 0.00 6017784.45 570874.20 MWD+IFR+MS 4100.00 53.63 54.19 3138.60 3080.80 1318.14 1822.42 0.00 6017832.16 570939.06 MWD+IFR+MS 4200.00 53.63 54.19 3197.90 3140.10 1365.25 1887.72 0.00 6017879.87 571003.91 MWD+IFR+MS 4300.00 53.63 54.19 3257.21 3199.41 1412.36 1953.02 0.00 6017927.58 571068.76 MWD+IFR+MS 4400.00 53.63 54.19 3316.51 3258.71 1459.47 2018.31 0.00 6017975.29 571133.62 MWD+IFR+MS 4469.63 53.63 54.19 3357.80 3300.00 1492.27 2063.78 0.00 6018008.51 571178.77 MPE-31 Fault1 4500.00 53.63 54.19 3375.81 3318.01 1506.58 2083.61 0.00 6018023.00 571198.47 MWD+IFR+MS 4600.00 53.63 54.19 3435.11 3377.31 1553.69 2148.91 0.00 6018070.71 571263.32 MWD+IFR+MS 4700.00 53.63 54.19 3494.41 3436.61 1600.80 2214.21 0.00 6018118.42 571328.17 MWD+IFR+MS 4800.00 53.63 54.19 3553.71 3495.91 1647.91 2279.51 0.00 6018166.13 571393.03 MWD+IFR+MS 4900.00 53.63 54.19 3613.02 3555.22 1695.02 2344.81 0.00 6018213.84 571457.88 MWD+IFR+MS 5000.00 53.63 54.19 3672.32 3614.52 1742.13 2410.11 0.00 6018261.55 571522.73 MWD+IFR+MS 5100.00 53.63 54.19 3731.62 3673.82 1789.24 2475.41 0.00 6018309.26 571587.59 MWD+IFR+MS 5200.00 53.63 54.19 3790.92 3733.12 1836.35 2540.71 0.00 6018356.97 571652.44 MWD+IFR+MS 5258.15 53.63 54.19 3825.40 3767.60 1863.74 2578.67 0.00 6018384.71 571690.15 Start Dir 4/1 00 5300.00 54.14 52.22 3850.07 3792.27 1883.99 2605.75 4.00 6018405.21 571717.03 MWD+IFR+MS 5330.41 54.54 50.80 3867.80 3810.00 1899.37 2625.09 4.00 6018420.76 571736.22 TUZC 5400.00 55.50 47.62 3907.70 3849.90 1936.62 2668.24 4.00 6018458.41 571779.02 MWD+IFR+MS 5500.00 57.03 43.17 3963.26 3905.46 1995.01 2727.40 4.00 6018517.34 571837.63 MWD+IFR+MS 5600.00 58.70 38.88 4016.46 3958.66 2058.89 2782.93 4.00 6018581.73 571892.57 MWD+IFR+MS 5681.27 60.17 35.51 4057.80 4000.00 2114.63 2825.22 4.00 6018637.86 571934.33 MPE-31 Fault2 5700.00 60.52 34.75 4067.07 4009.27 2127.94 2834.58 4.00 6018651.25 571943.57 MWD+IFR+MS 5774.24 61.94 31.77 4102.80 4045.00 2182.35 2870.25 4.00 6018705.98 571978.73 Ugnu-MA 5800.00 62.45 30.76 4114.82 4057.02 2201.83 2882.08 4.00 6018725.57 571990.37 MWD+IFR+MS 5806.47 62.58 30.51 4117.80 4060.00 2206.77 2885.00 4.00 6018730.53 571993.25 Ugnu-MB1 5900.00 64.50 26.92 4159.48 4101.68 2280.20 2925.21 4.00 6018804.32 572032.77 MWD+IFR+MS 5955.36 65.68 24.85 4182.80 4125.00 2325.37 2947.12 4.00 6018849.69 572054.26 Ugnu-MB2 6000.00 66.65 23.21 4200.84 4143.04 2362.66 2963.75 4.00 6018887.13 572070.54 MWD+IFR+MS 6061.23 68.00 21.00 4224.45 4166.65 2415.00 2985.00 4.00 6018939.66 572091.30 End Dir : 6061 6100.00 68.00 21.00 4238.98 4181.18 2448.56 2997.88 0.00 6018973.34 572103.87 MWD+IFR+MS 6200.00 68.00 21.00 4276.44 4218.64 2535.12 3031.11 0.00 6019060.19 572136.29 MWD+IFR+MS 6264.15 68.00 21.00 4300.47 4242.67 2590.64 3052.42 0.00 6019115.91 572157.09 Start Dir 4/100 6300.00 69.43 20.84 4313.48 4255.68 2621.85 3064.35 4.00 6019147.22 572168.72 MWD+IFR+MS 6327.20 70.51 20.72 4322.80 4265.00 2645.74 3073.42 4.00 6019171.19 572177.57 SBF2-NA 6400.00 73.41 20.41 4345.35 4287.55 2710.54 3097.73 4.00 6019236.21 572201.27 MWD+IFR+MS 6408.68 73.75 20.37 4347.80 4290.00 2718.35 3100.63 4.00 6019244.04 572204.10 SBF1-NB 6446.09 75.24 20.21 4357.80 4300.00 2752.16 3113.13 4.00 6019277.96 572216.29 MPE-31 Fault4 6487.00 76.87 20.05 4367.66 4309.86 2789.43 3126.79 4.00 6019315.36 572229.60 T' 6487.62 76.89 20.04 4367.80 4310.00 2790.00 3127.00 4.00 6019315.93 572229.80 MPE-31 T1 6500.00 76.89 20.04 4370.61 4312.81 2801.33 3131.13 0.00 6019327.29 572233.83 MWD+IFR+MS 6507.62 76.89 20.04 4372.34 4314.54 2808.30 3133.67 0.00 6019334.29 572236.31 Start Dir 10/10 6534.28 79.45 19.28 4377.80 4320.00 2832.87 3142.45 10.00 6019358.94 572244.86 SBE2-ND 6600.00 85.77 17 .45 4386.25 4328.45 2894.69 3162.97 10.00 6019420.94 572264.80 MWD+IFR+MS 6641.91 89.80 16.30 4387.87 4330.07 2934.76 3175.12 10.00 6019461.11 572276.58 End Dir : 6641 6700.00 89.80 16.30 4388.07 4330.27 2990.51 3191.43 0.00 6019517.01 572292.36 MWD+IFR+MS 6796.48 89.80 16.30 4388.41 4330.61 3083.12 3218.51 0.00 6019609.86 572318.58 Start Dir 4/1 00 6800.00 89.85 16.17 4388.42 4330.62 3086.50 3219.49 4.00 6019613.24 572319.53 MWD+IFR+MS 6884.31 91.00 13.00 4387.80 4330.00 3168.07 3240.72 4.00 6019695.00 572340.00 MPE-31 T2 6900.00 91.35 12.48 4387.48 4329.68 3183.38 3244.18 4.00 6019710.34 572343.32 MWD+IFR+MS 7000.00 93.61 9.17 4383.15 4325.35 3281.48 3262.94 4.00 6019808.60 572361.17 MWD+IFR+MS 7072.37 95.23 6.77 4377.57 4319.77 3352.93 3272.95 4.00 6019880.14 572370.51 End Dir : 7072 7100.00 95.23 6.77 4375.06 4317.26 3380.26 3276.19 0.00 6019907.49 572373.50 MWD+IFR+MS 7200.00 95.23 6.77 4365.94 4308.14 3479.15 3287.93 0.00 6020006.47 572384.31 MWD+IFR+MS . Sperry-Sun . BP Planning Report Company: BP Amoco Date: 4/5/2005 Time: 15:29:44 Page: 5 Field: Milne Point Co-ordinate(NE) Reference: Well: Plan MPEc31,True North Site: MPtEPad Vertical (TVD) Reference: 34.3+23.557.8 Well: Plan MPE-31 Section (VS) Reference: Well (0.00N,0.00E,32.98AZi) WeUpath: MPE-31 Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S EIW DLS MapN MapE ToolICommeat ft deg deg ft ft ft ft deg/100ft ft ft 7300.00 95.23 6.77 4356.83 4299.03 3578.04 3299.66 0.00 6020105.46 572395.13 MWD+IFR+MS 7330.82 95.23 6.77 4354.02 4296.22 3608.51 3303.28 0.00 6020135.96 572398.46 Start Dir 4/1 00 7400.00 92.68 5.70 4349.25 4291.45 3677. 11 3310.77 4.00 6020204.63 572405.32 MWD+IFR+MS 7445.37 91.00 5.00 4347.80 4290.00 3722.26 3315.00 4.00 6020249.81 572409.13 MPE-31 T3 7477.65 89.80 5.49 4347.57 4289.77 3754.41 3317.95 4.00 6020281.98 572411.78 End Dir : 7477 7500.00 89.80 5.49 4347.65 4289.85 3776.65 3320.09 0.00 6020304.24 572413.71 MWD+IFR+MS 7600.00 89.80 5.49 4347.99 4290.19 3876.19 3329.65 0.00 6020403.85 572422.35 MWD+IFR+MS 7646.76 89.80 5.49 4348.15 4290.35 3922.74 3334.12 0.00 6020450.44 572426.39 Start Dir 4/1 00 7696.47 91.00 3.90 4347.80 4290.00 3972.28 3338.19 4.00 6020500.00 572430.00 MPE-31 T4 7700.00 90.86 3.90 4347.74 4289.94 3975.80 3338.43 4.00 6020503.53 572430.20 MWD+IFR+MS 7800.00 86.86 3.93 4349.73 4291.93 4075.53 3345.26 4.00 6020603.30 572436.10 MWD+IFR+MS 7900.00 82.86 3.95 4358.69 4300.89 4174.87 3352.10 4.00 6020702.70 572442.02 MWD+IFR+MS 7986.05 79.42 3.98 4371.95 4314.15 4259.67 3357.98 4.00 6020787.54 572447.12 End Dir : 7986 8000.00 79.42 3.98 4374.51 4316.71 4273.35 3358.93 0.00 6020801.23 572447.94 MWD+IFR+MS 8075.13 79.42 3.98 4388.31 4330.51 4347.03 3364.06 0.00 6020874.94 572452.38 Start Dir 5/100 8100.00 80.66 3.98 4392.61 4334.81 4371.46 3365.75 5.00 6020899.39 572453.85 MWD+IFR+MS 8101.17 80.72 3.98 4392.80 4335.00 4372.62 3365.83 5.00 6020900.55 572453.92 8200.00 85.66 3.97 4404.51 4346.71 4470.48 3372.63 5.00 6020998.46 572459.81 MWD+IFR+MS 8286.79 90.00 3.96 4407.80 4350.00 4556.98 3378.62 5.00 6021085.00 572465.00 MPE-31 T5 8300.00 90.54 4.34 4407.74 4349.94 4570.16 3379.58 5.00 6021098.18 572465.83 MWD+IFR+MS 8315.28 91.17 4.77 4407.51 4349.71 4585.39 3380.79 5.00 6021113.43 572466.90 End Dir : 8315 8400.00 91.17 4.77 4405.77 4347.97 4669.80 3387.83 0.00 6021197.89 572473.16 MWD+IFR+MS 8500.00 91.17 4.77 4403.73 4345.93 4769.43 3396.15 0.00 6021297.58 572480.55 MWD+IFR+MS 8600.00 91.17 4.77 4401.68 4343.88 4869.06 3404.46 0.00 6021397.28 572487.93 MWD+IFR+MS 8700.00 91.17 4.77 4399.64 4341.84 4968.70 3412.77 0.00 6021496.98 572495.32 MWD+IFR+MS 8800.00 91.17 4.77 4397.59 4339.79 5068.33 3421.08 0.00 6021596.67 572502.71 MWD+IFR+MS 8900.00 91.17 4.77 4395.54 4337.74 5167.96 3429.40 0.00 6021696.37 572510.09 MWD+IFR+MS 9000.00 91.17 4.77 4393.50 4335.70 5267.59 3437.71 0.00 6021796.06 572517.48 MWD+IFR+MS 9034.00 91.17 4.77 4392.80 4335.00 5301.47 3440.53 0.00 6021829.96 572519.99 5" 9034.04 91.17 4.77 4392.80 4335.00 5301.51 3440.54 0.00 6021830.00 572520.00 MPE-31 T6 I 000 Vi < 1 28 ,:10 149 \1 I MPU 1 Proposed 1-011 Schrader uNC/NCu 2050720 t';) o N \ SONORA D STEWMAN BP EXPLORATION AKINC PO BOX 196612 MB 7-5 ANCHORAGE, AK 99519-6612 89-6/1252 128 "Mastèrcard Check" 6~6;:?6FHE _ACxSCi'~~ ~ Ot")ð\l_'-.Y'I(\r~A~~ First Nation~ank Alaska :::o°1;;~9~~~ I ~~J~-_ DATEN) -0 j {J)' I $ tCO.CD~ . - .......-~ DOLLARS .:. 25 2000 bO.: t1 t1 . ....., b 2 2 711' ~ 5 b ...u- O. 28 . . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME m;:/a F-~I 2D~ ~07Z-- CHECK WHAT APPLIES Rev: 04/01105 C\jody\transm ittal_ checklist PTD# ADD-ONS (OPTIONS) MULTI LATERAL "CLUE" The permit is for a new wellbore segment of existing well_, Permit No, API No. Production should continue to be reported as a function of the original API number stated above. (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). SPACING EXCEPTION The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce/inject is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing exception that may occur. DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Field & Pool MILNE POINT, SCHRADER BLFF OIL - 525140 Well Name: MILNE PT UNIT SB MPU E-31 Program DEV Well bore seg D PTD#: 2050720 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV I PEND GeoArea 890 Unit 11328 On/Off Shore On Annular Disposal D Administration 1 P~rmiUee aUaçhe_d_ _ _ _ _ - - - - -- - - - - _Y~s - - - - - - - - - - - - - - - - - - - - - ~ - 2 _Leas~ _nlJmberappropriate _ _ - - - - - - - -- - - - - - Y~s _ _ _ _ _ ,A.ddjtioo to 10-4D7 form: Surface location InAD_L_25518, tpp prpd inteNal andTDin .t\DL 47.4313-- _ _ _ _ _ _ _ 3 _U_niqlJewelln_arn~_aoc! ou.mb_er _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - Y~s - - - - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 4 WeIUoc¡;tt~d in a_ d_efinedpool - - - - - - - - - _Y~s _ _ _ _ _ MiJnePoint Schrader Bluff Oil F'ool (5251<40), governed by_ CO 4"l7, amendec! by CO 417.Q5, _ _ _ _ _ _ _ _ _ _ 5 WelUoc¡;tled prpper _distance_ from driJling IJnilb_olJnd_al"Y_ _ - - - - - - - - _ _ _ _ _ _ _Y~s _ _ CO >477:.05_ specifje.sno restriçtjons ¡;ts to well spacing except _that 00 pay _sbaILb~opened _ - - - - - - - - - 6 WeIUoc¡;tt~d proper_distance_ from otber welJs_ _ _ _ _ _ _ _ _ _ _ - - _Y~s _ _ _ _ _ in _a well closer th¡;tn 5QO feet !o_ from the exterior bo_uodary: of !he_affected_ area_. _ _ _ _ _ _ _ _ _ _ _ _ 7 S_ufficientacreage_ayail¡;tble in_dJilliog unjt - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - 8 Jfdeviated, js_ weJlbore pl¡;tUncJudec! _ - - Y~s - - - - - - - - - - - - - - - - - - -- - - - - - - - - 9 Operator onl}' a~çted party _ _ _ - - - - - - - - - - - - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 10 _Oper_ator bas_apprppriate_bond inJorce _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - Y~s - - - -. - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - -- 11 P~rmil cao be issued wjtbout co_nserva_tion order _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 P~rmil c_ao be issued wjtbout administratÍ\le_approvaJ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . SFD 5/9/2005 13 Can permit be approved before 15-day wait Yes 14 Well Jocaled within area and s!r¡;tt¡;t alJthorized by_lojectioo Ord~r # (plJlIO# in_ cOOlmeots) (For .NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 15 AJI WeUsJ,yithiflJI4J1JiLe_area_of reyiew jd~olifjec! (For servjc~JN.ell onlYL _ _ _ _ _ _ _ _ _ _ _ _ _ _ _NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 16 Pre-produ_ced injector; dur¡;ttionof pre-prodlJction I~ss_ than_:3 months_ (For_service well on!y) _ NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 17 ACMPFïndingof Consi.stencyh_as bee_nJ$.slJed_ forJbis pr_oiect_ _ _ _ . _ _ _NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- Engineering 18 _C90ductor stringpJovided _ _ - - - - - - - - - - - - - - - - _Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 19 _S_urfaœ _c¡;t$.ing_pJotect$. all_kIlown USDWs . - - - - - - -- NA .t\IL aq_uifers ex_ernpedAO cm :147J 1021b)(3L _ . . _ _ _ _ _ _ _ _ _ _ _ _ _ _ . 20 _CMT v_oL adeQu_ate_ to çi rc_u Late_o_n _cOnd_uctor & SUJfc.sg . - Y~s - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - - - - - 21 _CMT v_ol adeQu_ate_ to tie-in Jong string to_surf csg_ - - - - - - -- . No_ _ _ . _ .811 hYdr_oçarbon_zooes-Pfopose_d_to b~ coyered._ - - - - - - - - - - - - - - 22 _CMTwill coyeraJl known-Pfo_dlJctiye bori¡!:on_s_ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ _ _ Scree_ned compJetion planned.. _ _ _ . _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - 23 _C_asiog designs adequate for C,T" B&Rermafrost - - - - -- _ . .Y~s - - - - - - - - - - - - - - - - - - - - - - - -- 24 Adequ¡;ttetankage_oJ reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _Y~s _ _ _ _ _ Rig js_e_qlJippe_dw.itb .st~elpits. No reseJ'le_pjtpLanne_d, AJI w¡;tste to_approveddispos_al w~lIs._ _ _ _ _ 25 JfaJe-drilL bas_a_ 10:403 for <lbandonme_nt be~o ¡;tPPJoved . _ _ _ _NA - - - -- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 26 Adequ¡;ttew.eJlboreseparatjofl_proposed_ _ _ _ _ _ _ . _ _ _ _ _ _ _ _ _ _ _ - - - Y~s _ _ _ _ _ I?rOJ5:imit}' an¡;tlysis pertorme_d, C!o.se approaçlJe_sJd_entjfj~d._ Gyros plan_ned. _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Jtdjverter Jeq_uired, does jt meet reguJations_ _ _ _ _ Y_es - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - - - Appr Date 28 DJilliog flujd Rrogram schematic_& ectuip Jistadequ¡;tle _ _ _ _ _ Xes _ _ _ _ _ Maximum ex-pectJortJ1¡;ttion pre.sSUJe 8.3 EMW. J~lan_ned MW 9.0 - 9.2 PRgin S8._ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . TEM 5/10/2005 29 _BOPEs,_d_othey meelreguJation . - Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- ~?yV 30 BOPEpr~ss ratiog appropriate;_test loJput psig In_comments)_ _ - Y~s _ _ _ _ M.t\SF' çalcu!a!e.dat 1442 psi. 30QOp.s1 BOP testplanoed, _ _ _ _ _ _ _ _ . - - - - - - 31 _Chokemanjfold complies w/AI?IRF'-5:3 (May 84>- _ - - - - - - - - - - - . . . _Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work will oCCjJr withoutoperatio_nsbutdown . _ _ _ _ . . . _ _ _ . Y~s - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 33 Js pre$.ence_ of H2S gas_ probable. _ _ _ No_ _ _ _ _ . H2S has _not been reported jn_ 5B produ_ction, _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - 34 Meçba_nic¡;tlcondJlion of wells within .t\OR yerified (for_s_ervice welJ only) . .NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - Geology 35 P~rmit cao be issued wfo hydrogen_ sulfide Oleas_ures _ _ _ _ _ _ _ _ _ - Y~s . . W¡;tI!eJ Qua}'., BPA-26_-05; 00 H2S measlJred inSB at MP_U_E-I?ad_. _SFD_ _ _ _ _ . 36 _D_ata_pJesented onpote_ntial oveJQres_sure_zone.s_ _ _ _ _ _ _ _ _ . - Y~s _ _ _ _ _ Expected r~s~rvojr preSSUJe i.s8.35 ppg EMW; wi)l be drjlled with_ 9.0 ~ 9.2 ppgmud, . _ Appr Date 37 _S~isOlic_aIlalysjs_ of .sbaJlow gaszooes _ _ _ _NA . . H}'dJateshave be_en encountered In/-P¡;td wens Þetween 2000 & 2500' TVD. Noted jn_ Drilling H<lzaJds_s~ctioo. SFD 5/9/2005 .- 38 _S~abedcondjtioo survey (if off-shore) . - - - - - - - - - - - - - - . .NA _t:. 39 Conta_ct nam_elphoneJor_weekly progress_reports [explor¡;ttol"Y _only] _NA - - - - - - Geologic Date: Engineering Date Da510~ Commissioner Commissioner: .... S-jtJ-¿}S . . Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, infonnation 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 Dr~ng Services LIS Scan Utility 80~- 01-9 c l3'i~ . $Revision: 3 $ LisLib $Revision: 4 $ Tue May 16 15:39:19 2006 Reel Header Service name........ '" ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name.... ...UNKNOWN Comments........... .... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-31 PB1 500292326370 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 16-MAY-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003753911 C.A. DEMOSKI E. VAUGHN MWD RUN 2 MW0003753911 R. FRENCH E. VAUGHN MWD RUN 3 MW0003753911 C. ZAWADZKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 l3N 10E 3960 2014 56.30 22.10 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 13.500 9.875 6.750 CASING SIZE (IN) 20.000 10.750 7.625 DRILLERS DEPTH (FT) 114.0 3310.0 6502.0 # REMARKS: . . 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1-3 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 2,3 INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUN 3 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN), STABILIZED LITHO-DENSITY (SLD), AND AT-BIT INCLINATION (ABI). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL DATED 5/10/2006 FROM DOUG DORTCH (SAIC/BP) TO BUSTER BRYANT (SDS), QUOTING AUTHORIZATION FROM MICAELA WEEKS (BP GEOSCIENTIST). MWD DATA ARE CONSIDERED PDC. 5. MWD RUNS 1-3 REPRESENT WELL MPE-31 PB1 WITH API#: 50-029-23263-70. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8810'MD/4354'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 SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: MUD SALINITY: FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ 6.75" BIT 9.1-9.2 PPG 220,000 PPM CHLORIDES 21,000 PPM CHLORIDES 1.0 G/CC 2.65 G/CC SANDSTONE File Header Service name............ .STSLIB.001 Service Sub Level Name... · version Number......... .~o.o Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type....... ........ .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPM FET RPX RPS RPD FCNT PEF DRHO RHOB NCNT NPHI $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 72.5 114.5 3278.0 3278.0 3278.0 3278.0 3278.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 STOP DEPTH 8753.5 8810.0 8760.5 8760.5 8760.5 8760.5 8760.5 8717.0 8732.0 8732.0 8732.0 8717.0 8717.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------ BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 MERGED MAIN PASS. $ MERGE TOP 72.5 3320.0 6511.0 MERGE BASE 3320.0 6511.0 8810.0 # Data Format Specification Record Data Record Type......... .........0 Data Specification Block Type.....O Logging Direction... ... .......... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing..... ........... .....60 .1IN Max frames per record.......... ...Undefined Absent value.............. ....... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR . 1 68 36 10 . GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 72.5 8810 4441. 25 17476 72.5 8810 FCNT MWD CNTS 102.14 881. 65 243.643 4499 6468 8717 NCNT MWD CNTS 13547.6 31975.7 19415.6 4499 6468 8717 RHOB MWD G/CM 1.656 3.023 2.23609 4529 6468 8732 DRHO MWD G/CM -0.588 0.709 0.0780572 4529 6468 8732 RPD MWD OHMM 1. 05 2000 40.1106 10966 3278 8760.5 RPM MWD OHMM 0.99 2000 31.4945 10966 3278 8760.5 RPS MWD OHMM 0.33 2000 13.0851 10966 3278 8760.5 RPX MWD OHMM 0.61 1803.82 11.3786 10966 3278 8760.5 FET MWD HOUR 0.12 47.29 1.30698 10966 3278 8760.5 GR MWD API 10.15 122.81 63.4981 17363 72 .5 8753.5 PEF MWD BARN 1. 31 10.13 2.46174 4529 6468 8732 ROP MWD FT/H 1.56 1273.25 196.071 17392 114.5 8810 NPHI MWD PU-S 14.6 58.41 33.1854 4499 6468 8717 First Reading For Entire File......... .72.5 Last Reading For Entire File.......... .8810 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..06/05/16 Maximum Physical Record. .65535 File Type.............. ..LO Next File Name........ ...STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type.. . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 72.5 114.5 STOP DEPTH 3277.5 3320.0 # LOG HEADER DATA DATE LOGGED: 10-JUN-05 . SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............ .... ..0 Data Specification Block Type.....O Logging Direction....... ......... . Down Optical log depth units...... .....Feet Data Reference Point..... ........ .Undefined Frame Spacing...... ............. ..60 .1IN Max frames per record.......... ...Undefined Absent value...................... -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT GR ROP Service Order Units FT API FT/H Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code MWD010 MWD010 Name Service Unit DEPT FT GR MWD010 API Min 72 .5 21.31 Max 3320 118.71 Insite 66.37 Memory 3320.0 114.0 3320.0 .1 54.9 TOOL NUMBER 175785 13.500 .0 SPUD 9.40 144.0 8.5 600 10.8 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 Mean 1696.25 62.9163 Nsam 6496 6411 . .0 68.0 .0 .0 First Reading 72.5 72.5 Last Reading 3320 3277.5 ROP MWD010 FT/H 1.5. 426.46 . 114 . 5 3320 195.217 6412 First Reading For Entire File......... .72.5 Last Reading For Entire File...... .... .3320 File Trailer Service name......... ....STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type..... ...... ... ..LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPX FET GR RPD RPS RPM ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3278.0 3278.0 3278.0 3278.0 3278.0 3278.0 3320.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 6467.5 6467.5 6475.0 6467.5 6467.5 6467.5 6511.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # 14-JUN-05 Insite 66.37 Memory 6511.0 3320.0 6511.0 51.6 73.2 TOOL NUMBER 132477 66259 BOREHOLE AND OPEN HOLE DRILLER'S CASING DATA- BIT SIZE (IN): CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type............. ... ..0 Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.................... .60 .1IN Max frames per record.. .......... .Undefined Absent value.................... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 9.875 3310.0 LSND 9.10 54.0 8.3 500 8.0 5.000 75.0 4.240 89.6 5.500 75.0 4.500 75.0 Name Service Order units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 Name DEPT RPD RPM RPS RPX FET GR ROP Service Unit FT MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 OHMM MWD020 HOUR MWD020 API MWD020 FT/H Min 3278 1. 05 0.99 0.33 0.61 0.12 10.15 2.56 Max 6511 2000 2000 68.91 73.22 47.29 122.81 1224.99 First Reading For Entire File......... .3278 Last Reading For Entire File.......... .6511 Mean 4894.5 22.7162 10.6706 7.49996 7.48696 1. 14428 64.5582 233.499 Nsam 6467 6380 6380 6380 6380 6380 6395 6382 First Reading 3278 3278 3278 3278 3278 3278 3278 3320.5 Last Reading 6511 6467.5 6467.5 6467.5 6467.5 6467.5 6475 6511 . File Trailer Service name........... ..STSLIB.003 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record..65535 File Type... .......... ...LO Next File Name......... ..STSLIB.004 Physical EOF File Header Service name........... ..STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name. .... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE DRHO NPHI RPX RPM FET RPD RPS PEF RHOB NCNT FCNT GR ROP $ 4 . header data for each bit run in separate files. 3 .5000 START DEPTH 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6475.5 6511.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ STOP DEPTH 8732.0 8717.0 8760.5 8760.5 8760.5 8760.5 8760.5 8732.0 8732.0 8717.0 8717.0 8753.5 8810.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 17-JUN-05 Insite 66.37 Memory 8810.0 6511.0 8810.0 76.6 101. 4 TOOL NUMBER 184054 112439 110041 156401 # . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type................ ..0 Data Specification Block Type.. ...0 Logging Direction............... ..Down Optical log depth units.. ........ .Feet Data Reference Point... .......... . Undefined Frame Spacing................... ..60 .1IN Max frames per record....... .... ..Undefined Absent value... ............. .... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . 6.750 6502.0 VERSA PRO 9.20 82.0 .0 224164 .0 .000 111.200 .000 .000 .0 .0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6468 8810 7639 4685 6468 8810 FCNT MWD030 CNTS 102.14 881. 65 243.643 4499 6468 8717 NCNT MWD030 CNTS 13547.6 31975.7 19415.6 4499 6468 8717 RHOB MWD030 G/CM 1. 656 3.023 2.23609 4529 6468 8732 DRHO MWD030 G/CM -0.588 0.709 0.0780572 4529 6468 8732 RPD MWD030 OHMM 3.39 2000 64.3095 4586 6468 8760.5 RPM MWD030 OHMM 2.17 2000 60.4646 4586 6468 8760.5 RPS MWD030 OHMM 3.7. 2000 20.8551 4586 . 6468 8760.5 RPX MWD030 OHMM 3.74 1803.82 16.7926 4586 6468 8760.5 FET MWD030 HOUR 0.33 46.39 1.53332 4586 6468 8760.5 GR MWD030 API 21.34 111.52 62.8291 4557 6475.5 8753.5 PEF MWD030 BARN 1.31 10.13 2.46174 4529 6468 8732 ROP MWD030 FT/H 7.12 1273.25 145.312 4598 6511.5 8810 NPHI MWD030 PU-S 14.6 58.41 33.1854 4499 6468 8717 First Reading For Entire File.... ..... .6468 Last Reading For Entire File.......... .8810 File Trailer Service name.......... ...STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..06/05/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name. ......... .STSLIB.005 Physical EOF Tape Trailer Service name.... ....... ..LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name.............. ..UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin.................. .STS Reel Name.............. ..UNKNOWN Continuation Number.... ..01 Next Reel Name......... ..UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun Dr~ng Services LIS Scan Utility f)OS--O¡ $Revision: 3 $ LisLib $Revision: 4 $ Tue May 16 16:22:59 2006 tt'1'1lC» Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments............... ..STS LIS Writing Library. Scientific Technical Services Tape Header Service name...... ...... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... ... ..UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments.... .......... ...STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Milne Point MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA MPE-31 500292326300 B.P. Exploration (Alaska) Inc. Sperry Drilling Services 16-MAY-06 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003753911 C.A. DEMOSKI E. VAUGHN MWD RUN 2 MW0003753911 R. FRENCH E. VAUGHN MWD RUN 3 MW0003753911 C. ZAWADZKI D. GREEN JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0003753911 C. ZAWADZKI D. GREEN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 25 13N 10E 3960 2014 56.30 22.10 # WELL CASING RECORD OPEN HOLE CASING DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING BIT S. (IN) 13.500 9.875 6.750 SIZE (IN) 20.000 10.750 7.625 DEPTH (FT) 114.0 3310.0 6502.0 . # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL EXITS THE MPE-31 PB1 WELLBORE BY MEANS OF AN OPEN-HOLE SIDETRACK, THE EXIT POINT BEING 8002'MD/4397'TVD. 4. MWD RUNS 1-4 COMPRISED DIRECTIONAL AND DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. MWD RUNS 2-4 INCLUDED ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MWD RUNS 3,4 ALSO INCLUDED COMPENSATED THERMAL NEUTRON (CTN), STABILIZED LITHO-DENSITY (SLD), AND AT-BIT INCLINATION (ABI). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL DATED 5/10/2006 FROM DOUG DORTCH (SAIC/BP) TO BUSTER BRYANT (SDS), QUOTING AUTHORIZATION FROM MICAELA WEEKS (BP GEOSCIENTIST). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1-4 REPRESENT WELL MPE-31 WITH API#: 50-029-23263-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9042'MD/4368'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 SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). TNPS = SMOOTHED THERMAL NEUTRON POROSITY (FIXED HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: MUD WEIGHT: 6.75" BIT 9.1-9.2 PPG MUD SALINITY: tIÞ FORMATION WATER SALINITY: FLUID DENSITY: MATRIX DENSITY: LITHOLOGY: $ File Header Service name............ .STSLIB.001 Service Sub Level Name. . . Version Number......... ..1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type..... .......... .LO Previous File Name.... ...STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP RPX RPS RPD FET RPM DRHO PEF RHOB NCNT NPHI FCNT $ 1 220,000 PPM CHLOJlltS 21,000 PPM CHLORIDES 1. 0 GICC 2.65 GICC SANDSTONE and clipped curves; all bit runs merged. .5000 START DEPTH 72 .5 114.5 3278.0 3278.0 3278.0 3278.0 3278.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 STOP DEPTH 8985.5 9042.0 8992.5 8992.5 8992.5 8992.5 8992.5 8964.0 8964.0 8964.0 8949.0 8949.0 8717.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH -------. BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ # REMARKS: BIT RUN NO 1 2 3 4 MERGED MAIN PASS. $ MERGE TOP 72.5 3320.0 6511.0 8002.5 MERGE BASE 3320.0 6511.0 8002.0 9042.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction................ . Down Optical log depth units. . . . . . . . . . .Feet Data Reference Point......... '" ..Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value.... ........... ..... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units S. Nsam Rep Code Offset Channel . DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 68 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 72.5 9042 4557.25 17940 72.5 9042 FCNT MWD CNTS 102.14 881.65 243.643 4499 6468 8717 NCNT MWD CNTS 13547.6 36180.7 19249.3 4963 6468 8949 RHOB MWD G/CM 1.656 3.023 2.21035 4993 6468 8964 DRHO MWD G/CM -0.588 0.709 0.0720194 4993 6468 8964 RPD MWD OHMM 1. 05 2000 41.1637 11430 3278 8992.5 RPM MWD OHMM 0.99 2000 32.7129 11430 3278 8992.5 RPS MWD OHMM 0.33 2000 14.6038 11430 3278 8992.5 RPX MWD OHMM 0.61 1803.82 12.9671 11430 3278 8992.5 FET MWD HOUR 0.12 47.29 1. 30963 11430 3278 8992.5 GR MWD API 10.15 122.81 62.3401 17827 72 .5 8985.5 PEF MWD BARN 1.31 10.13 2.36297 4993 6468 8964 ROP MWD FT/H 1. 56 1224.99 193.25 17856 114.5 9042 NPHI MWD PU-S 9.78 58.41 33.4036 4963 6468 8949 First Reading For Entire File... ... ....72.5 Last Reading For Entire File.......... .9042 File Trailer Service name........... ..STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .06/05/16 Maximum Physical Record..65535 File Type............... .LO Next File Name....... ... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type.......... .... ..LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 2 header data for each bit run in separate files. 1 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ .5000. START DEPTH 72.5 114.5 STOP DEPTH 3277.5 3320.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units... ....... .Feet Data Reference Point............. . Undefined Frame Spacing................... ..60 .1IN Max frames per record.. .......... . Undefined Absent value................. .....-999 Depth Units. . . . . . . . . . . . . . . . . . : . . . . Datum Specification Block sub-type...O . 10-JUN-05 Insite 66.37 Memory 3320.0 114.0 3320.0 .1 54.9 TOOL NUMBER 175785 13.500 .0 SPUD 9.40 144.0 8.5 600 10.8 .000 .000 .000 .000 .0 68.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT GR MWDOI0 ROP MWDOI0 . FT API FT/H 4 4 1 68 1 68 1 68 1. 2 3 o 4 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 72.5 3320 1696.25 6496 72.5 3320 GR MWDOI0 API 21.31 118.71 62.9163 6411 72.5 3277.5 ROP MWDOI0 FT/H 1. 56 426.46 195.217 6412 114.5 3320 First Reading For Entire File......... .72.5 Last Reading For Entire File.......... .3320 File Trailer Service name........ ... ..STSLIB.002 Service Sub Level Name... Version Number.... ...... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record..65535 File Type.. .......... ....LO Next File Name.... ...... .STSLIB.003 Physical EOF File Header Service name......... ....STSLIB.003 Service Sub Level Name... version Number.. ........ .1.0.0 Date of Generation..... ..06/05/16 Maximum Physical Record..65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD . Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPS RPM RPX FET RPD ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 3278.0 3278.0 3278.0 3278.0 3278.0 3278.0 3320.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): STOP DEPTH 6475.0 6467.5 6467.5 6467.5 6467.5 6467.5 6511.0 14-JUN-05 Insite 66.37 Memory 6511.0 3320.0 6511.0 HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: . . 51.6 73.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 TOOL NUMBER 132477 66259 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 9.875 3310.0 # 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: LSND 9.10 54.0 8.3 500 8.0 5.000 4.240 5.500 4.500 75.0 89.6 75.0 75.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type... ..0 Logging Direction..... .......... ..Down Optical log depth units.......... .Feet Data Reference Point... .......... .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value................ .... ..-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 3278 6511 4894.5 6467 3278 6511 RPD MWD020 OHMM 1. 05 2000 22.7162 6380 3278 6467.5 RPM MWD020 OHMM 0.99 2000 10.6706 6380 3278 6467.5 RPS MWD020 OHMM 0.33 68.91 7.49996 6380 3278 6467.5 RPX MWD020 OHMM 0.6_ 73.22 7.48696 6380 . 3278 6467.5 FET MWD020 HOUR 0.12 47.29 1.14428 6380 3278 6467.5 GR MWD020 API 10.15 122.81 64.5582 6395 3278 6475 ROP MWD020 FT/H 2.56 1224.99 233.499 6382 3320.5 6511 First Reading For Entire File......... .3278 Last Reading For Entire File. ......... .6511 File Trailer Service name...... ...... .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..06/05/16 Maximum Physical Record..65535 File Type........... '" ..LO Next File Name..... ..... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number....... ....1.0.0 Date of Generation..... ..06/05/16 Maximum Physical Record. .65535 File Type............... .LO Previous File Name..... ..STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF FET RPX NPHI RPS FCNT RPM NCNT RPD RHOB DRHO GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6468.0 6475.5 6511. 5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG STOP DEPTH 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 8002.0 17-JUN-05 Insite 66.37 Memory 8002.0 6511.0 8002.0 MINIMUM ANGLE: MAXIMUM ANGLE: . # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type... ...............0 Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................. ...60 .1IN Max frames per record.......... ...Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 76.6 101.4 . TOOL NUMBER 184054 112439 110041 156401 6.750 6502.0 VERSA PRO 9.20 82.0 .0 224164 .0 .000 .000 .000 .000 .0 111.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 FCNT MWD030 CNTS 4 1 68 4 2 NCNT MWD030 CNTS 4 1 68 8 3 RHOB MWD030 G/CM 4 1 68 12 4 DRHO MWD030 G/CM 4 1 68 16 5 RPD MWD030 OHMM 4 1 68 20 6 RPM MWD030 OHMM 4 1 68 24 7 RPS MWD030 OHMM 4 1 68 28 8 RPX MWD030 OHMM 4 1 68 32 9 FET MWD030 HOUR 4 1 68 36 10 GR MWD030 API 4 1 68 40 11 PEF MWD030 BARN 4 1 68 44 12 ROP MWD030 FT/H 4 1 68 48 13 NPHI MWD030 PU-S 4 1 68 52 14 . . First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 6468 8002 7235 3069 6468 8002 FCNT MWD030 CNTS 102.14 881.65 242.557 3069 6468 8002 NCNT MWD030 CNTS 13547.6 31975.7 19281.1 3069 6468 8002 RHOB MWD030 G/CM 1.656 3.023 2.2177 3069 6468 8002 DRHO MWD030 G/CM -0.588 0.709 0.0806468 3069 6468 8002 RPD MWD030 OHMM 3.39 2000 91 . 1911 3069 6468 8002 RPM MWD030 OHMM 2.17 2000 85.4306 3069 6468 8002 RPS MWD030 OHMM 4.12 2000 26.3037 3069 6468 8002 RPX MWD030 OHMM 3.9 1803.82 20.0415 3069 6468 8002 FET MWD030 HOUR 0.39 46.39 1.99372 3069 6468 8002 GR MWD030 API 21.34 111. 52 59.1185 3054 6475.5 8002 PEF MWD030 BARN 1. 31 10.13 2.44717 3069 6468 8002 ROP MWD030 FT/H 7.12 810.15 141. 415 2982 6511. 5 8002 NPHI MWD030 PU-S 14.6 58.41 33.2573 3069 6468 8002 First Reading For Entire File......... .6468 Last Reading For Entire File.......... .8002 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..06/05/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type.............. ..LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RHOB NPHI RPD RPX FET DRHO RPM GR RPS PEF NCNT ROP FCNT 5 header data for each bit run in separate files. 4 .5000 START DEPTH 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 8002.5 STOP DEPTH 8964.0 8949.0 8992.5 8992 .5 8992.5 8964.0 8992.5 8985.5 8992.5 8964.0 8949.0 9042.0 8717.0 $ . # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type....... ...........0 Data Specification Block Type.....O Logging Direction.............. ...Down Optical log depth units........ ...Feet Data Reference Point...... ....... .Undefined Frame Spacing.................... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name DEPT FCNT NCNT Service Order Units FT CNTS CNTS Rep 68 68 68 Code Size 4 4 4 Nsam 1 1 1 MWD040 MWD040 . 17-JUN-05 Insite 66.37 Memory 9042.0 8002.0 9042.0 89.0 95.7 TOOL NUMBER 184054 112439 110041 156401 6.750 6502.0 Versa Pro 9.20 82.0 .0 224164 .0 .000 .000 .000 .000 .0 111.0 .0 .0 Offset o 4 8 Channel 1 2 3 RHOB MWD040 G/CM . 1 68 12 4 . DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MWD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8002.5 9042 8522.25 2080 8002.5 9042 FCNT MWD040 CNTS 177 . 67 438.74 245.976 1430 8002.5 8717 NCNT MWD040 CNTS 16134.7 36180.7 19197.9 1894 8002.5 8949 RHOB MWD040 G/CM 1.931 2.685 2.19863 1924 8002.5 8964 DRHO MWD040 G/CM -0.237 0.452 0.0582578 1924 8002.5 8964 RPD MWD040 OHMM 3.89 155.26 23.0722 1981 8002.5 8992 .5 RPM MWD040 OHMM 3.41 456.39 22.0313 1981 8002.5 8992.5 RPS MWD040 OHMM 3.44 68.31 19.3567 1981 8002.5 8992.5 RPX MWD040 OHMM 3.48 97.97 19.6567 1981 8002.5 8992.5 FET MWD040 HOUR 0.34 12.75 0.782383 1981 8002.5 8992.5 GR MWD040 API 33.92 102.05 58.2529 1967 8002.5 8985.5 PEF MWD040 BARN 1. 51 4.67 2.22865 1924 8002.5 8964 ROP MWD040 FT/H 6.89 419.18 138.002 2080 8002.5 9042 NPHI MWD040 PU-S 9.78 42.68 33.6406 1894 8002.5 8949 First Reading For Entire File......... .8002.5 Last Reading For Entire File...... .... .9042 File Trailer Service name........... ..STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .06/05/16 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .06/05/16 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... .UNKNOWN Continuation Number..... .01 Next Tape Name......... ..UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name........ .....LISTPE Date. . . . . . . . . . . . . . . . . . . . .06/05/16 Origin.................. .STS Reel Name.......... ......UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments.............. ...STS LIS Writing Library. Scientific Technical Services . . Physical EOF Physical EOF End Of LIS File