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Home My WebLink About204-039 e e 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. :;¿ Q lJ- - 03 f/ Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: ß Lf- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES ~ Date:h/ß/oiP If NO in stage 1, page(s) discrepancies were found: Organizing (done) o Two-sided III II 11111111111111 RES CAN I rZ'or Items: ~ ~~eYSCale Items: DIGITAL DATA ~iskettes, No. Q.. o Other, NofType: o Poor Quality Originals: o Other: NOTES: BY: (Mãriã) Date(p / rg /O(p Project Proofing BY: ~ r Date to/ fó / ok _!l:- x 30 = ft?ó Date: Þ / r¿ /0 (p Scanning Preparation BY: ~ BY: Stage 1 BY: Maria Date: Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: Comments about this file: o Rescan Needed II I II 1111111111111I OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: 151 VY1r 11111111111111 "III 151 vy\p + ~3 = TOTAL PAGES ß'3 (Count does not include cover sheet) '^^ P· 151 I Y\ 111111111I1 III "III NO YES 151 mp NO 151 1111111111111111111 '" II 111111111 "III 151 Quality Checked 11111111111I 111111I 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA AKA OIL AND GAS CONSERVATION CO•SSION . REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ❑ Repair Well ❑ Plug Perforations ❑ Perforate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Stimulate - Frac ❑ Waiver IN Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Stimulate - Other ❑ Time Extension Change out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory - 204 - 039 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 23200 - 00 - 00 7. Property Designation (Lease Number): 4 8. Well Name and Number: ADL 047434 & 355017 MPC 9. Logs (list logs and submit electronic and printed data per 20AAC25.071): 10. Field / Pool(s): .. Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 13817' feet Plugs (measured) None feet true vertical 7547' feet Junk (measured) Yes, Unknown Depth feet Effective depth: measured 13727' feet Packer: (measured) feet true vertical 4736' feet Packer: (true vertical) feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 9328' 10 -3/4" 9363' 4736' 5210 2480 Intermediate Production 12850' 7 -5/8" 12883' 6641' 6890 4790 Liner 1080' 4 -1/2" 12735' - 13815 6503' - 7545' 8430 7500 5tioANNED JUN 2 r ala Perforation Depth: Measured Depth: 13566' - 13628' True Vertical Depth: 7298' - 7359' Tubing (size, grade, measured and true vertical depth): 2 - 7/8 ", 6.5# L - 12724' 6493' Packers and SSSV (type, measured and true vertical depth): None RECEIVED 12. Stimulation or cement squeeze summary: JUN 2 0 2012 Intervals treated (measured): Q Treatment description including volumes used and final pressure: ` ®GCC 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 324 306 478 340 220 Subsequent to operation: 309 275 618 390 188 14. Attac ❑ 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: b CO 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 Sean M T L..• hlin, 564 -4387 N/A Printed Na - oe L- IM Title Drilling Technologist , /^ _ /A ^ Prepared By Name/Number: Signature Phone 564 - 4091 Date IiQ 1!/ Joe Lastufka, 564 -4091 Form 10-404 Revi . 11/2011 ` ® M J S UN 2 U Zo14414Y f /� � b iit tO Original Only .—/' f �Li l • • North America - ALASKA - BP Page i of 13 Operation Summary Report Common Well Name: MPC -43 — — AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point 1 Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM ' Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ' Phase Description of Operations 1 (hr) 1 (ft) 5/17/2012 - 18:00 r MOB P 1 ! PRE WAIT ON SCHLUMBERGER WELL WORK CHANGE OUT AT REQUEST OF MPU 06:00 - 07:30 1.50 MOB P PRE ,PJSM, PREPARE TO MOVE OFF OF WELL �- BRIDLE UP DERRICK - RIG DOWN RIG FLOOR _ - PREP RIG FOR MOVE , 07:30 - 09:00 1.50 ± MOB P PRE INSPECT ACCUMULATOR EQUIPMENT - INSPECTION TEAM INVESTIGATION 09:00 - 11:00 2.00 MOB + P I PRE ■ PJSM TO MOVE OFF WELL 1- MOVE OFF MPL -06 _ _ - POSITION RIG ON PAD 11:00 - 12:00 1.00 MOB P T PRE PJSM, LAY DERRICK OVER, DISCUSSED DROPPED OBJECTS, POSITIONS OF PEOPLE AND ENSURING GOOD COMMUNICATIONS - LAY DERRICK OVER AND SECURE 12:00 - 16:30 1 4.50 MOB ' P PRE PJSM, REMOVE BOP FROM CELLAR - PLACE BOP STACK ON STAND AND REMOVE FROM CELLAR - INSTALL REAR BOOSTER WHEELS AND FUNCTION TEST - REMOVE PIT ROOM STAIRS ON ODS 1 16:30 - 18:00 1.50 MOB P 1 PRE WAIT ON SCHLUMBERGER CHANGE OUT _ FROM F PAD AT MPU REQUEST 18:00 - 22:30 4.50 MOB P PRE I PJSM, RIG MOVE, DISCUSSED HAZARDS AND 1 ENSURING GOOD COMMUNICATIONS AT ALL TIMES, PERFORM SPCC CHECKS - NOTIFY SECURITY BEGIN RIG MOVE, LEAVE MPL PAD - MOVE RIG DOWN L PAD ACCESS ROAD - NEGOTIATE CORNER AND MOVE DOWN MP SPINE ROAD TO MPC PAD 22:30 - 23:00 0.50 , - MOB P PRE ARRIVE OSITION RIG ON PAD - SPOT SIGN IN TRAILER AT MPC PAD ENTRANCE 23:00 - 00:00 ' 1.00 MOB P PRE PJSM, REMOVE REAR BOOSTER WHEELS - R/D AND REMOVE BOOSTERS FROM 1 10 - -- 5/18/2012 00:00 - 03:00 3.00 MOB P PRE 1 PJSM, RAISE DERRICK, DISCUSS DROPPED OBJECTS, MAINTAIN GOOD 1 COMMUNICATIONS, POSITIONS OF PEOPLE 1- RAISE DERRICK - REMOVE AND HANG BRIDLE LINES 1 - RIG UP FLOOR EQUIPMENT - REMOVE BOP FROM STAND AND INSTALL IN 1 CELLAR - SPOT AND R/U WELL SITE LEADER OFFICE_ 03:00 - 10:00 7.00 MOB P PRE PJSM, WORK ON BOP IN CELLAR AND SETTING RIG MATS - BREAK DOWN BOP STACK IN CELLAR - N/D DOUBLE GATE ON BOP STACK N/U SINGLE GATE - SET RIG MATS AROUND MPC-43 1 10:00 - 10:30 0.50 MOB 1 P PRE 7 1 CONDUCT AAR ON CHANGING BOPE j CONFIGURATION. - Printed 6/18/2012 2:52:25PM • North America - ALASKA - BP Page 2 of 4s Operation Summary Report Common Well Name: MPC-43 AFE No Event Type: WORKOVER (WO) I Start Date: 5/18/2012 I End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM I Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 10:30 - 12:00 I 1.50 MOB P (ft) PRE I CONTINUE TO SET RIG MATS. - TABLE TOP RIG EVACUTATION DRILL WITH "D" CREW 12:00 - 16:00 4.00 MOB P PRE P,ISM SPOT RIG OVER WELL. - DRILL SITE OPERATOR WAIVED WITNESSING. - SPOT RIG AND RIG UP ON WELL - RIG ACCEPTED @ 16:00 HRS, 05/18/2012 16:00 - 00:00 8.00 MOB P PRE R/U WELL KILL MANIFOLD AND MANUAL CHOKE IN CELLAR - ALL TREE VALVES REMAIN CLOSED R/U REMOTE SSV PANEL ON RIG FLOOR - INSTALL BALES AND ELEVATORS ON TOP DRIVE - SPOT CUTTINGS TANK - SPOT AND R/U CREW CHANGE TRAILER - TAKE ON 200 BBLS OF 120 DEGREE SEA -WATER '- FUNCTION TEST HIGH LEVEL ALARM ON FLOW TANK - VERIFY THAT TANK BAFFLE IS IN PLACE - HOLD RIG EVACUATION DRILL AND AAR WITH "A" CREW I I - BOB NOBLE WAIVED STATES RIGHT TO 'WITNESS BOP TEST @ 17:00 5/19/2012 00:00 - 06:00 6.00 MOB P DECOMP RIG UP LINES IN CELLAR - RIG UP LINES TO KILL MANIFOLD AND MANUAL CHOKE 1- RIG UP HARD LINE TO BLEED TANK BY 1 HARD LINE CREW - TEST HARDLINE TO 4600 PSI, GOOD TEST RIG UP LINES TO TREE - ALL TREE VALVES REMAIN CLOSED - TAKE ON 290 BBLS OF 120 DEGREE 8.5 SEA WATER i- PERFORM WORK ORDERS AND RIG MAINTENANCE 06:00 - 12:00 6.00 MOB P DECOMP RIG EVACUATION DRILL "LEL ". - ALL HANDS AT SAFE AREA 2 MIN 30 I SECONDS. - TRAINING ON WELL KILL WITH ALL HANDS ON THE CREW. - CHECK 6 FACILITATED POWER POINT, PRE JOB MTG. - HANDS ON TRAINING IN CELLAR W/ SQUEEZE / KILL MANIFOLD. - ALL SCENARIOS COVERED AS PER DOYON WELL KILL PROCEDURE. - O /A =OPSI, UA =620 PSI STATE AOGCC REP BOB NOBLE WAIVED WITNESSING BOPE TEST. Printed 6/18/2012 2:52:25PM • North America - ALASKA - BP 410 Page 3 of 13 . Operation Summary Report Common Well Name: MPC -43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM 1 Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT j NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 18:00 6.00 MOB P DECOMP - TRAINING ON WELL KILL WITH ALL HANDS ON THE CREW. - CHECK 6 FACILITATED POWER POINT, PRE JOB MTG. - HANDS ON TRAINING IN CELLAR W/ SQUEEZE / KILL MANIFOLD. - ALL SCENARIOS COVERED AS PER DOYON WELL KILL PROCEDURE. - WTL GAVE PERMISSION TO PROCEED TO WELL KILL. 18:00 - 00:00 6.00 MOB P ! DECOMP PERFORM DOYON WORK ORDERS, RIG MAINTENANCE INSTALL SECONDARY VALVE ON OA - TUBOSCOPE PERFORMED "MPI" CAT 3 INSPECTION ON DEAD -MAN - TOTCO REP PERFORMED PRE WELL -WORK CHECKS T -- I ' 5/20/2012 00:00 - 02:30 2.50 WHSUR 1 P DECOMP 1 PJSM, REVIEW 1502 AND LINE PRESSURE TEST PROCEDURE - FILL LINES WITH SEAWATER FROM PUMP TO FLOW -BACK TANK - CHECK FOR LEAKS CLOSE MANUAL CHOKE IN CELLAR L- TEST MANUAL CHOKE, 250 PSI LOW AND ,Q 3500 PSI HIGH, 5 MINUTES, CHARTED �` - MANUAL CHOKE HELD 250 PSI LOW, BLED OFF 1200 PSI DURING 5 MIN HIGH TEST - CLOSE "H -4" VALVE AT FLOW -BACK TANK AND OPEN MANUAL CHOKE - TEST ALL LINES AND HAMMER UNIONS FROM PUMP TO FLOW -BACK TANK - 250 PSI LOW, 3500 PSI HIGH, 5 MINUTES 1 CHARTED = GOOD TEST - CHECK CV -1 AND CV -2 CHECK VALVES PER PROCEDURE = GOOD TEST - BLOW DOWN ALL LINES - CLOSE ALL VALVES 1 1 -IA = 640 PSI, TUBING = 0 PSI AT 01:00 HRS 02:30 - 06:00 3.50 MOB P DECOMP PERFORM DOYON WORK ORDERS - MOBILIZE DSM TOOLS TO RIG FLOOR AND STAND BY 06:00 09:00 3.00 MOB P DECOMP LINE UP TRUCKS TO OFF LOAD SEA WATER RIG SERVICE, WAIT ON NECESSARY PERSONEL. - KNOCK ICE FROM DERRICK. - RIG UP AND FUNCTION TEST SSV REMOTE PANEL. 09:00 - 09:30 I 0.50 WHSUR P DECOMP ! PRE JOB SAFETY MEETING ON PRESSURE TESTING LUBRICATOR. - ALSO ON PULLING BPV. EMPHASIZE SKILLFUL COMMUNICATION. - ALSO ON HIGH PRESSURE AWARENESS AND FALL PROTECTION. 09:30 - 11:30 2.00 WHSUR P DECOMP PRESSURE TEST LUBRICATOR, 250 LOW, 3500 PSI HIGH. - CHARTED TEST. OPEN SWAB VALVE, SSV AND MASTER VALVE - EQUALIZE PRESSURE, PULL BPV, SITP = 620 PSI. 11:30 12:00 0.50 T WHSUR P DECOMP RIG DOWN LUBRICATOR, UD TOOLS. Printed 6/18/2012 2:52:25PM North America - ALASKA - BP Page 4 of 13 Operation Summary Report Common Well Name: MPC-43 1 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations - (hr) O� 12:00 - 12:30 0.50 WHSUR P DECOMP !SERVICE RIG AND INSPECT EQUIPMENT. 12:30 - 13:00 0.50 KILLW P DECOMP PJSM WITH ALL HANDS. - DISCUSS WELL KILL PROCEDURE. - EMPHASIS ON COMMUNICATION & PROPER VALVE ALIGNMENT. 13:00 - 18:00 5.00 KILLW P DECOMP LINE UP AND BLEED GAS OFF OF VA. - INITIAL SHUT IN PRESSURE = 650 PSI. - BLEED THRU CHOKE TO TIGER TANK. - KEEP PRESSURE DOWN STREAM OF CHOKE UNDER 150 PSI. - BLEED FOR 20 MINUTES, PRESSURE 75 PSI. - LINE UP AND PUMP DOWN TBG, TAKING RETURNS UP VA THRU CHOKE TO TIGER TANK. - SITP = 620 PSI. EQUALIZE PRESSURE W/ MUD PUMP AND OPEN UP TO TBG. - PUMP 4 BPM, ICP = 560 PSI & DROPPING RAPIDLY. - W/ 75 BBLS PUMPED & VA GOING THRU HALF OPEN CHOKE TO TIGER TANK, FCP = 25 PSI. - BULLHEAD 40 BBLS DOWN TBG @ 4 BPM / 0 PSI. - OPEN VA BACK UP AND TAKE RETURNS THRU CHOKE TO TIGER TANK. - PUMP 5 BPM, PRESSURE INITIALLY ZERO, � I THEN CLIMBS TO 420 PSI WITH 30 BBLS AWAY AND CHOKE FULLY OPEN. SMALL AMOUNT OF GAS RETURNS TO TIGER TANK. PUMP 100 BBLS AND NOTE GAS RETURNS DWINDLING DOWN TO ALMOST NOTHING. NO SIGN OF FLUID WITH CHOKE WIDE OPEN AND PUMPING 5 BPM FCP = 550 PSI. - LINE UP AND BULLHEAD DOWN THE VA. ICP = 100 PSI @ 5 BPM. - WITH 300 BBLS AWAY, BRING UP RATE TO 6 BPM / 20 PSI. SITP = 0 PSI. MONITOR WELL 30 MINUTES = ON A VAC = DEAD - LINE UP TO VA AND FILL ANNULUS AT 30 BBLS PER HOUR - BLOW DOWN ALL OTHER CIRCULATING LINES 18:00 - 21:30 3.50 WHSUR P DECOMP PJSM WITH DRILL SITE MAINT PERSONAL - R/U DSM LUBRICATOR AND M/U TO TREE TEST LUBRICATOR TO 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - INSTALL TWC - ATTEMPT ROLLING TEST FROM BELOW TWC F /10 MIN - PUMP 30 BBLS PUMPED AWAY AT 3 BPM = 30 PSI - TEST TWC FROM ABOVE, 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - R/D LUBRICATOR Printed 6/18/2012 2:52:25PM • North America ALASKA - BP Page 5 of 13 Operation Summary Report Common Well Name: MPC-43 l AFE No Event Type: WORKOVER (WO) 1 Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point 1 Site: M Pt C Pad Rig Name /No.: DOYON 16 1 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) I (ft) 21:30 - 00:00 2.50 { WHSUR P DECOMP PJSM, BLOW DOWN ALL CELLAR LINES AND KILL MANIFOLD R/D WELL KILL MANIFOLD AND ALL RELATED HOSES I- REMOVE ALL VALVES AND HOSES FROM I CELLAR I- INSALL SILLS AROUND CELLAR BOX j - CONTINUE FILLING VA @ 30 BPH I � � - 24 HR TOTAL LOSSES TO WELL = 1201 BBLS 5/21/2012 00:00 - 03:30 3.50 WHSUR P DECOMP ■ P.ISM NIPPI F DOWN TRFE INSTALL PLATFORM BOARDS AROUND CELLAR BOX I- VAC DIESEL OUT OF TREE 1- FMC HAND PRESENT TO BLEED OFF PACK -OFF VOID j- N/D REMOVE TREE - FMC HAND INSTALLED FMC "FUNNEL" - INSPECT WELL HEAD, HANGER THREADS, LOCK DOWN SCREWS - DRY RUN WITH 2 7/8" PUP JOINT, 7 3/4 RH 'TURNS 03:30 - 05:30 2.00 BOPSUR P DECOMP 1 PJSM, NIPPLE UP BOP STACK AND INSTALL RAMS, DISCUSSED DROPPED OBJECTS, WORKING OVERHEAD AND WORKING AT HEIGHTS - NIPPLE UP BOPE AND RISER 05 :30 - 10:00 4.50 BOPSUR P DECOMP INSPECT 2 7/8" X 5" VBRS. - INSTALL BLIND SHEAR RAMS. - FUNCTION TEST BOPE, RIG UP TO TEST . 10:00 - 12:00 2.00 BOPSUR P DECOMP TEST BOPE AS PER AOGCC AND BP REQUIREMENTS. - TEST LOWER PIPE RAMS, 250 / 3500 PSI / 5 MIN EACH TEST / CHARTED. !- LOSSES TO THE WELL IN LAST 12 HOURS = 356 BBLS. AOGCC INSPECTOR BOB NOBLE WAIVED WITNESSING TEST. - 24+ HOUR NOTIFICATION GIVEN .., (BOB NOBLE). 12:00 - 17:00 5.00 BOPSUR P DECOMP CONTINUE TO TEST BOPE USING 2 7/8" TEST I JOINT. - ALL TESTS 250 LOW, 3500 PSI HIGH / 5 MIN 'EACH. - I/A BEING CONTINUOUSLY FILLED @ 30 BPH. - ANNULAR PREVENTOR NOT HOLDING, TRY TESTING SEVERAL TIMES. - EMPTY FLOW NIPPLE OF ALL FLUID, NO VISIBLE LEAKAGE. - LEAK RATE = 150 PSI / 5 MINUTES. 1 - SUSPECT 2 WAY CHECK, NOTIFY VALVE 'CREW. Printed 6/18/2012 2:52:25PM 0 North America - ALASKA - BP 0 Page 6 of 13 Operation Summary Report Common Well Name: MPC-43 AFE No Event Type: WORKOVER (WO) I Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point I Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code j NPT NPT Depth I Phase I Description of Operations _ (hr) (ft) 17:00 - 18:30 1.50 BOPSUR N WSEQ ! } DECOMP PJSM, R/U DUTCH RISER - L/D27 /8TESTJOINT 1 I- INSTALL DUTCH RISER OBSERVED TWC NOT HOLDING FROM 1 BELOW I I - AIR AND A SMALL AMOUNT OF FLUID ' EXHALING FROM BELOW TWC - VAC FLUID OFF TOP OF TWC 1 1 - OBSERVE SAME AIR AND FLUID COMING UP FROM TWC I - TWC NOT HOLDING FROM BELOW 1 I - I/A BEING CONTINUOUSLY FILLED @ 30 BPH. 18:30 - 00:00 5.50 BOPSUR N WSEQ DECOMP ! PJSM, R/U DSM / VALVE CREW LUBRICATOR - TEST LUBRICATOR 250 PSI LOW, 3500 PSI HIGH, 5 MIN, CHARTED - PULL LEAKING TWC ' ' I I- AFTER AIR BROKE OUT, FLUID IN STACK I j AND TUBING SUCKED DOWN HOLE ON VAC - CALLED TOWN ENGINEER AND WTL TO I 'DISCUSS PLAN FORWARD - ATTEMPT TO INSTALL NEW TWC WITH LUBRICATOR WAS UNSUCCESSFUL I- PULLED SAME TWC BACK OUT OF THE HOLE ■ - FOUND THAT PARTS OF THE TWC WERE LEFT IN HOLE I- OBSERVED THAT THE MISSING PIECES I I WERE LAYING ON TOP OF HANGER - ALSO OBSERVED THAT THE "FMC FUNNEL" WAS OUT OF ALIGNMENT AND UN- USEABLE , I I- CALLED TOWN ENGINEER TO DISCUSS PLAN FORWARD - DRY ROD IN TWC = GOOD - 24 HR TOTAL FLUID LOSS = 583 BBLS j 5/22/2012 00:00 - 01:00 ' 1.00 BOPSUR WSEQ N DECOMP I PJSM, RIG DOWN DSM LUBRICATOR AND ' DUTCH RISER ASSY !- R/D DSM LUBRICATOR - R/D DUTCH RISER - I/A BEING CONTINUOUSLY FILLED @ 20 BPH — j PER TOWN ENGINEER 01:00 02:00 1.00 BOPSUR N WSEQ' DECOMP PJSM, TESTING - R/U TO TEST TWC - ATTEMPT ROLLING TEST FROM BELOW TWC THROUGH VA - PUMP 3.5 BPM = 100 PSI, 10 MIN, CHARTED, I I j I TOTAL 30 BBLS PUMPED - TEST TWC FROM ABOVE 250 PSI LOW, 3500 02:30 0.50 BOPSUR N WSEQ DECOMP PSI HIGH, 5 MIN, CHARTED = GOOD TEST 02:00 RIG DOWN TEST EQUIPMENT I - BLOW DOWN CHOKE AND KILL LINES - SUCK OUT REMAINDER OF FLUID IN S TACK 02:30 - 05:00 2.50 BOPSUR N 1WSEQ ' DECOMP PJSM ON N/D & N/U BOPS - SPLIT STACK AT WELL HEAD - REMOVE "FMC FUNNEL" - RECOVER ALL TWC PARTS PREVIOUSLY LEFT IN HOLE BY DSM CREW I I - N/U BOP STACK Printed 6/18/2012 2:52:25PM 1 North America - ALASKA - BP Page 7 13 Operation Summary Report • Common Well Name: MPC -43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 r End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.1 Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations h r ) 05:00 - 12:00 7.00 BOPSUR P l '� DECOMP PJSM -TEST 13 -5/8" BOPE AND CHOKE MANIFOLD - TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS /� - TEST 3 PREVENTER BOP STACK, CHOKE t2(1 VALVES, AND FLOOR VALVES tY�j - TEST, 250 PSI LOW, 3500 PSI HIGH, 5 CHARTED MINUTES - TEST ANNULAR PREVENTER, 250 PSI LOW AND 3500 PSI HIGH - TEST USING 2 7/8" TEST JOINT - ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT AK -10 -45 - PERFORM ACCUMULATOR TEST - TEST GAS ALARMS AND PIT VOLUME TOTALIZERS - BOB NOBLE OF AOGCC WAIVED STATES RIGHT OF WITNESS 12:00 - 13:00 1.00 BOPSUR P DECOMP CEASE BOP TESTING TO CLEAR ICE FROM DERRICK PJSM TO CONTINUE BOP TESTING 13:00 - 14:30 1.50 BOPSUR 14:30 - 15:30 1.00 i BOPSUR P I � DECOMP CONTINUE BOP TEST DECOMP BLOW DOWN SURFACE LINES AND CHOKE - RIG DOW TEST EQUIPMENT - CLEAR RIG FLOOR 15:30 - 16:30 1.00 BOPSUR P DECOMP RIG UP OPSO -LOPSO LUBRICATOR WITH PUMP AND SUB PJSM WITH WELLS SUPPORT M/U LUBRICATOR - TEST 250 LOW, 3500 HIGH FIVE MINUTES CHARTED - PULL 21/2" TYPE 'H' TWC - TUBING ON SLIGHT VAC - R/D WELLS SUPPORT LUBRICATOR 16:30 - 17:00 0.50 BOPSUR P - - -- - - - - -- - - -- DECOMP CLEAN AND CLEAR RIG FLOOR 17:00 - 19:30 2.50 BOPSUR P DECOMP PJSM - R/U ESP DOUBLE STACK TONGS AND SLIPS READY RIG FLOOR TO PULL TUBING i HANGER AND LAY DOWN 2 7/8" 8 ROUND EUE TUBING 19:30 - 21:00 1.50 PULL P DECOMP PJSM - PULL HANGER TO RIG FLOOR - P/U LANDING JT AND SCREW INTO HANGER - BACK OUT LOCK DOWN SCREWS - WSL ENSURE NO PRESSURE BELOW HANGER, WELL IS ON A VAC - PULL HANGER AND ESP COMPLETION TO RIG FLOOR - PULL OFF SEAT AT 125K UP WT - PUWT = 121K, SOWT = 74K (WEIGHTS INCLUDE BLOCKS AND TOP DRIVE = 40K) I- CUT ESP CABLE ABOVE CLAMP BELOW ,HANGER UD HANGER - M/U 2 7/8 SAFETY JOINT W/TIW AND LOWER STRING BACK IN HOLE - ENSURE SLICK PIPE IS ACROSS BOP STACK Printed 6/18/2012 2:52:25PM North America - ALASKA - BP Page 8 of 13 Operation Summary Report Common Well Name: MPC -43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs Task Code NPT , NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 22:00 1.00 PULL P DECOMP R/U CIRCULATION LINES - PUMP 100 BBLS 8.5 PPG SEA WATER DOWN TUBING (TUBING VOLUME + EXCESS) - 3 BPM = 50 PSI, NO RETURNS - TUBING ON A VAC 22:00 - 23:00 1.00 PULL P DECOMP 'PJSM, CONTINUE R/U ESP EQUIPMENT AND !TONGS H. HANG ESP SHEAVE AND "ELEPHANT TRUCK R/D CIRCULATING LINES 23:00 - 00:00 1.00 PULL P DECOMP POOH WITH 6.5# 2 7/8" EUE 8RD TUBING AND ESP CABLE STAND BACK IN DERRICK I- POOH F/12711' T/12487' - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH WITH NO RETURNS WITH 8.5 PPG SEA WATER - 24 HR TOTAL FLUID LOSS = 539 BBLS 5/23/2012 00:00 01:00 1.00 PULL P IDECOMP INSPECT AND SERVICE RIG 1- DOUBLE CHECK RIG UP OF ALL HANDLING EQUIPMENT - CENTRILIFT REP. TRAINED HANDS ON ! ! , SPOOLING UNIT OPERATION 1 ,- PERFORM SPCC WALK AROUND 01:00 - 06:00 5.00 PULL P DECOMP PJSM - PULL ESP COMPLETION 1 - CONTINUE TO PULL 2 7/8" ESP COMPLETION F/12487' T/8100' - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH 06:00 - 06:15 0.25 PULL P DECOMP HELD KICK WHILE TRIPPING ESP DRILL. SIMULATE CUT ESP CABLE AT THE NEXT CABLE CLAMP. - 2 MINUTES 45 SECONDS TO SECURE WELL. - AAR: DISCUSSED INSTALLING A CABLE CLAMP, VERSA TIE WRAPS TO SECURE ESP CABLE TO TBG. - IF FLOW IS THROUGH THE TBG, STAB THE SAFETY VALVE FIRST. 06:15 - 12:00 5.75 PULL P j DECOMP PULL ESP COMPLETION T / 3217' MD - WITH CONTINUOUS HOLE FEED —20 BPH - 8.5 PPG SEAWATER - WITH NO RETURNS. - REPLACED TBG JOINT # 191 - NO OTHER BAD JOINTS NOTED. - PUW = 68K, SOW= 60K. 12:00 - 12:30 0.50 PULL P DECOMP PJSM AT TOUR CHANGE. - CREW PERFORM PRE -TOUR CH ECKS. 12:30 - 16:30 4.00 PULL P DECOMP 1 PJSM - PULL ESP COMPLETION - CONTINUE TO PULL 2 7/8" ESP COMPLETION - F/ 3217' MD T / ESP ASSEMBLY. - REPLACE JT #378. - LD 2 PUP JTS, 'XN' AND 1 JT 2 7/8" TBG, 1 GLM Printed 6/18/2012 2:52:25PM il l North America - ALASKA - BP 4 Page 9 of 13 Operation Summary Report Common Well Name: MPC -43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:O0AM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51. Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:30 - 18:30 ! 2.00 PULL P DECOMP PJSM, UD ESP PUMP AND MOTOR, R/D CENTRILIFT - UD CENTRILIFT MOTOR AND PUMP ASSY - PUMP, MOTOR, EQUIPMENT, CLAMPS, AND ESP CABLE WERE NORM = NO IMPACT - LASALLE CLAMPS = 208 RECOVERED 1- SS BAND -2 , 18:30 - 20:30 2.00 DECOMP RIG DOWN FLOOR EQUIPMENT � PULL P ' UD ESP SHEAVE, DRAIN HOSE AND ELEPHANT TRUNK CLEAR RIG FLOOR OF CLAMPS AND CENTRILIFT EQUIPMENT 20:30 - 21:30 1.00 BOPSUR P DECOMP INSTALL TEST PLUG - R/U TO FEED VA AT 20 BPH THROUGH ANNULUS VALVE 21:30 - 00:00 2.50 EVAL P DECOMP j PJSM, R/U SCHLUMBERGER AND DUTCH 'RISER - INSTALL DUTCH RISER AND CLOSE ANNULAR - R/U SWS WITH FULL PRESSURE CONTROL LUBRICATOR - 24 HR TOTAL FLUID LOSS = 539 BBLS 5/24/2012 00:00 - 03:30 3.50 EVAL P DECOMP PJSM, CONTINUE TO R/U SWS LUBRICATOR R/U TO DUTCH RISER IN STACK R/U SWS FULL PRESSURE CONTROL (FPC) LUBRICATOR AND SLICK LINE ASSY - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH 03:30 - 04:30 1.00 BOPSUR P DECOMP TEST LUBRICATOR - R/U TEST EQUIPMENT - TEST SWS LUBRICATOR, TEST PLUG, AND ANNULAR - 250 PSI LOW, 2500 PSI HIGH, 5 MIN, CHARTED = GOOD TEST R/D TEST EQUIPMENT 04:30 - 05:00 0.50 EVAL P DECOMP PULL LUBRICATOR AND DUTCH RISER ASSY REMOVE TEST PLUG FROM TUBING SPOOL 1 05:00 - 06:30 1.50 EVAL P DECOMP M/U SWS PDS -MTT, 5,8,10, AND 12 Hz M/U LUBRICATOR BACK UP AND CLOSE ;ANNULAR 06:30 12:30 6.00 EVAL P DECOMP MAKE LOGGING RUN WITH PDS MTT TOOL 7 _ 5, 8, 10 AND 12 HZ (MEMORY) -FROM 1000' MD TO SURFACE. - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH WITH NO RETURNS - WITH 8.6 PPG SEAWATER. 12:30 - 13:00 0.50 EVAL r P DECOMP PJSM, CHANGE OUT WIRE LINE TOOL STRING. - BRAKE LUBRICATOR AT QUICK- CONNECT - UD PDS - MTT TOOL. M/U PDS - CALIPER (MEMORY) TOOL. - M/U AND RETEST LUBRICATOR _ _ I (QUICK- CONNECT. 13:00 - 14:00 1.00 EVAL P DECOMP MAKE LOGGING RUN WITH PDS - CALIPER TOOL - LOGGING RUN FROM 1000' MD TO SURFACE j - GOOD DATA RECOVERED. Printed 6/18/2012 2:52:25PM North America - ALASKA - BP Page 10 of 13 Operation Summary Report Common Well Name: MPC -43 v AFE No Event Type: WORKOVER (WO) I Start Date: 5/18/2012 I End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point I Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To Hrs I Task Code I NPT NPT Depth Phase Description of Operations 15:00 1 00 EVAL P DECOMP S E IS (hr) (ft) 14:00 - ;SAFETY DISCUSSION WITH WTL, RWO ISUPERINTENDENT, WSL, TOOLPUSHER AND CREW. - SWS DOWNLOADING TOOLS 15:00 16:30 1.50 EVAL P DECOMP I PJSM, R/D SWS FPC LUBRICATOR - R/D ALL SWS EQUIPMENT R/D DUTCH RISER ASSY - 2.50 RUNCOM P � RUNCMP - CLEAR / CLEAN RIG FLOOR - 16:30 19:00 PJSM, R/U TO RUN COMPLETION R/U DOUBLE STACK POWER TONGS - HANG ESP CABLE SHEAVE IN DERRICK AND I SECURE P/U ALL CENTRILIFT EQUIPMENT P/U CANNON CLAMPS TO RIG FLOOR AND ISTACK 19:00 - 23:00 4.00 j RUNCOM P RUNCMP M/U CENTRILIFT ESP MOTOR AND PUMP ASSY PER RUNNING ORDER - PREP. MOTOR - CONNECT TECH WIRE AND ESP CABLE - TEST FOR C ONTINUITY = GOOD TEST 23:00 - 00:00 1.00 RUNCOM P RUNCMP TERMINATE TECH WIRE I I I - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH - 24 HR TOTAL FLUID LOSS = 524 BBLS 5/25/2012 00:00 - 00:30 0.50 RUNCOM P RUNCMP PJSM WITH NEW CREW ON RINNING ESP COMPLETION CONTINUE TERMINATION OF TECH WIRE it I, III - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH WITH NO RETURNS 00:30 - 07:30 7.00 RUNCOM P RUNCMP RIH W/2 7/8" 6.5# EUE ESP COMPLETION PER RUNNING ORDER - CHECK CONDUCTIVITY EVERY 1000' 07:30 - 08:00 0.50 RUNCOM P RUNCMP CENTRILIFT REP PERFORM CONDUCTIVITY TEST AT 2897' MD - READING FAILED - FILL AND FLUSH TBG WITH 20 BBLS SEAWATER - 1 BPM / 20 PSI. 08:00 - 09:00 1.00 RUNCOM P RUNCMP EVALUATE POSSIBLE WELL LIFT GAUGE FAILURE - DISCUSS OPTIONS WITH MPU OPS AND RWO ENGINEER. - WELL SUPPORT TECK SHOT FLUID LEVEL 12:00 3.00 RUNCOM R U N ES ' MD. 09:00 - I P I RUNCMP ;RUN ESP COMPLETION ON 2 7/8" 6.5# EUE FROM DERRICK. FROM 2897' MD TO 4650' MD. - CHECK CONDUCTIVITY EVERY 1000' RUNCOM 12:00 - 12:30 0.50 P RUNCMP I CENTRILIFT REP PERFORM CONDUCTIVITY TEST AT 4650' MD - FILL AND FLUSH TBG WITH 40 BBLS SEAWATER - 1 BPM / 20 PSI. I - PUW = 76K, SOW = 67K Printed 6/18/2012 2:52:25PM 0 North America - ALASKA - BP al , Page 11 of 13 Operation Summary Report Common Well Name: MPC-43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) I Project: Milne Point I Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date ■ From - To Hrs Task 1 Code 1 NPT NPT Depth 1 Phase Description of Operations (hr) ft ;12:30 - 16:30 4.00 RUNCOM P 1 RUNCMP ; RUN ESP COMPLETION ON 2 7/8" 6.5# EUE FROM DERRICK. 1 - FROM 4650' MD TO 6720' MD. - CHECK CONDUCTIVITY EVERY 1000' j CENTRILIFT REP PERFORM CONDUCTIVITY I TEST AT 6720' MD 1 - RIH FROM 6720' TO 7506' T 16:30 - 20:00 3.50 RUNCOM P RUNCMP CENTRILIFT MADE SPLICE TO ESP CABLE AT 7506' - FILL AND FLUSH TBG WITH 20 BBLS SEAWATER - 1 BPM / 20 PSI. - PUW = 76K, SOW = 67K - CHECK BOTTOM HOLE TEMP, PRESSURE, 1 RESISTANCE, AND PHASE TO PHASE - ALL CHECKS GOOD 1 20:00 - 00:00 4.00 RUNCOM P I RUNCMP CONT. RUN ESP COMPLETION ON 2 7/8" 6.5# i EUE FROM DERRICK. - RIH FROM 7506' TO 10588' - PUWT = 112K, SOWT = 70K - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH WITH NO RETURNS `: - 24 HR TOTAL FLUID LOSS = 626 BBLS 5/26/2012 00:00 03:30 3.50 RUNCOM P RUNCMP CONT. RUN ESP COMPLETION ON 2 7/8" 6.5# EUE FROM DERRICK. - RIH F/ 10588' T/ 12700' 1- PUWT = 133K, SOWT = 75K - PUMP 5 BBLS DOWN PIPE, 1 BPM = 20 PSI -MA INTAIN CONTINUOUS HOLEFEEDAT20 BPH 1 03:30 - 06:30 3.00 RUNCOM P RUNCMP M/U AND ORIENT HANGER PER FMC REP. i INSTALL ESP PENETRATOR - CONNECT AND TERMINATE ESP CABLE, fi TEST FOR CONTINUITY 06:30 08:00 1.50 RUNCOM P RUNCMP PJSM, R/D ESP SHEAVE IN DERRICK. 4 '- REMOVE CENTRILIFT EQUIPMENT FROM RIG FLOOR. RUNCMP 08:00 - 08:30 0.50 RUNCOM P M/U 2 7/8" LANDING JT WITH FOSV TO . 1 HANGER. - STOP HOLE FEED. LAND TBG HANGER WITH FMC WELL HEAD REP. 1 - PUW = 135K, SOW = 76K - SET AT 12724' MD. 1 I- FMC WELL HEAD REP RILDS. - RAN 400 CANNON CLAMPS I 2 HALF CANNON CLAMPS. 3ARMSTERGUARDS - 5 PUMP PROTECTORS - 1 MOTOR PROTECTOR I - 401 JTS 2 7/8" 6.5 #, EUE 8 RD, L -80 TBG. 1 - XN - 2 GLM. Printed 6/18/2012 2:52:25PM 0 North America - ALASKA - BP > page 12 of 13 . . Operation Summary Report Common Well Name: MPC-43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. `UWI: Active Datum: ORIG KELLY BUSHING @51.1 Oft (above Mean Sea Level) Date From - To Hrs Task Code NPT I NPT Depth Phase ! Description of Operations (hr) (ft) 08:30 - 09:30 1.00 RUNCOM P RUNCMP ATTEMPT TO TEST TWC FROM BELOW. I - PUMPED 7 BPM 40 BBLS / 350 PSI LINE i IPRESSURE !- NO RETURNS NO PRESSURE INCREASE. , I- TEST TWC FROM ABOVE , AGAINST THE 1 BLIND RAMS. - 250 LOW / 3500 PSI FOR 5 CHARTED MINIJTFS ROOD TFST. 09:30 - 12:00 2.50 BOPSUR P RUNCMP PJSM, TO CHANGE OUT 13 5/8" T -3 ANNULAR !ELEMENT. DOYON TOOL PUSHER / HSE REP AND WSL I PRESENT. - REMOVE DUTCH RISER FLANGE AND SEND I I I ! IN FOR INSPECTION ! - REMOVE ANNULAR ELEMENT 1 !- MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH, 8.5 PPG SEAWATER 12:00 - 15:30 3.50 BOPSUR T P ± OTHCMP I PJSM, CONT. C/O ANNULAR ELEMENT I - INSTALL NEW ANNULAR ELEMENT - M/U ANNULAR CAP - DO NOT RE- INSTALL DUTCH RISER FLANGE - WSL HELD HANDOVER MEETING WITH MPU OPS COOR ON MPF -94 15:30 - 18:00 2.50 BOPSUR P OTHCMP N/U AIR BOOT RISER - FUNCTION ANNULAR - FUNCTION ANNULAR ELEMENT ON 2 7/8" TEST JOINT 18:00 - 22:00 ! 4.00 BOPSUR P OTHCMP PJSM, REMOVE BLIND RAMS AND N/D BOP ISTACK BLOW DOWN ALL SURFACE LINES ' r - DRAIN STACK ;- OPEN DOORS AND REMOVE BLIND RAMS N/D BOP AND STAND BACK CLEAN OFF TOP OF TUBING HANGER AND PREP FOR TREE INSTALL - PREP RIG FLOOR FOR RIG MOVE 22:00 - 00:00 2.00 WHSUR P RUNCMP 'CENTRILIFT CHECKED CONTINUITY OF ESP PENITRATORS = GOOD - SEE CENTRILIFT INSTALLATION REPORT ATTACHMENT. - PHASE TO PHASE RESISTANCE: 4.0 OHMS, BALLANCED, PHASE TO GROUND RESISTANCE: 796 MEG OHMS. - MAINTAIN CONTINUOUS HOLE FEED AT 20 BPH WITH NO RETURNS t I- 24 HR TOTAL FLUID LOSS = 661 BBLS 5/27/2012 00:00 - 02:30 ! 2.50 WHSUR P RUNCMP !PJSM. N/U TREE N/U ADAPTER FLANGE AND 2 9/16" PRODUCTION TREE TREE MAINTAIN CONTINUOUS HOLE FEED AT 20 — .50 WHSUR P RUNCMP BPH 02:30 - 03:00 0.50 I ! FMC REP. TEST ADAPTER FLANGE SEAL - 250 PSI LOW, 5 MIN, 5000 PSI HIGH 15 MIN, } FMC DIGITAL CHART Printed 6/18/2012 2:52:25PM , . North America - ALASKA - BP Page 13 of 13 Operation Summary Report . Common Well Name: MPC -43 AFE No Event Type: WORKOVER (WO) Start Date: 5/18/2012 1 End Date: 5/27/2012 X4- 00W6N -E: (1,500,000.00 ) Project: Milne Point Site: M Pt C Pad Rig Name /No.: DOYON 16 Spud Date/Time: 3/19/2004 12:00:OOAM 1 Rig Release: 5/27/2012 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: ORIG KELLY BUSHING @51.10ft (above Mean Sea Level) Date From - To ! Hrs Task 1 Code NPT NPT Depth Phase Description of Operations (hr) ft 03:00 - 04:00 1.00 WHSUR I P (ft) RUNCMP 'TEST TREE 1- R/U TEST EQUIPMENT - TEST TREE, 250 PSI LOW, 5000 PSI HIGH, 5 MIN, CHARTED R/D TEST EQUIPMENT 04:00 - 06:30 2.50 WHSUR P RUNCMP 1PJSM, WELL SUPPORT TO LUBRICATE OUT TWC R/U FULL PRESSURE CONTROL 1 LUBRICATOR I - TEST 250 PSI LOW, 3500 PSI HIGH, 5 MIN, , CHARTED - PULL TWC I- BOTH TBG AND IA ON A VACUUM. 06:30 07:00 0.50 WHSUR P RUNCMP SET 2 TYPE 'T' BPV. - !ATTEMPT TO TEST BPV FROM BELOW - PUMPED 100 BBLS 8.5 PPG SEAWATER I- DOWN THE IA 1- 8 BPM / 450 PSI LINE PRESSURE 1 1 - DID NOT CATCH FLUID. - NO TEST. 07:00 - 10:00 3.00 ' WHSUR I r P RUNCMP 1SECURE 2 9/16" PRODUCTION TREE - PJSM CLEAN PITS LOWER PIPE SHOOT. PREP RIG TO LOWER DERRICK. 1 H 10:00 10:30 0.50 WHSUR P RUNCMP !H2S ALARM SOUNDED ON THE RIG WITH '0' 1 READING ON #3 SENSOR I - CREW EVACUATED THE RIG TO THE I MUSTER AREA I- TOTAL HEAD COUNT = 14 1- ALL NOTIFICATIONS MADE AND THE PAD WAS BLOCKED BY SCS. ' - TOOLPUSHER ENTERED THE RIG WITH 1 HAND HELD H2S MONITOR. ' - ALL CLEAR WAS CALLED BY TOOLPUSHER. 10:30 12:00 1.50 RIGD P OTHCMP PJSM LOWER DERRICK. COVER LAY DOWN DERRICK CHECK LIST. - TOOLPUSHER PRESENT WHILE LOWERING I DERRICK. - MOVE CUTTING BOX TO MPL -PAD - MOVE FUEL TRAILER AROUND MPC -PAD. 1- "A" CREW AND SUPPORT CREW, CHECK -6, 1 SCS AND WSL - ATTENDED WEEKLY SAFETY MEETING, DISCUSSED SITUATIONAL AWARENESS RIG RELEASED FROM MPC-43 FOR MOVE TO LMPF -94 AT 12:00 HRS 5 -27 -2012. Printed 6/18/2012 2:52:24PM Tree: 2-9/16" - FM • M P C -43 Wellhead: :11" 11 " x 11" 5M . Gen 5, w 2 -7/8" FMC Tbg. Hgr., 2 -7/8" EUE Top & Btm, 2.5" CIW BPV Profile j $ Ti. Orig. DF Elev. = 51.10' (Doyon 14) Orig. GL Elev. = 16.40' (Doyon 14) 20" 91.1# ppf, H -40 BTC 1 112' , r Camco 2 -7/8" x1' KBMM 1 140' 1 J 0 10 3/4 ", 45.5 ppf, L -80 BTC. 9,363' , 1 f 1 /' 0 Camco 2 -7/8" x 1' KBMM 1 12,455' I 0 IF o • • XN Nipple (2.313" packing ID) I 12,608' 2 -7/8" 6.5 #, L -80, EUE 8rd • U2 (2.250" no -go ID) (2.347" = Drift ID Cap = .0058) 0 WeIILift Discharge Gauge Unit ( 12,649' 7-5/8" 29.7 ppf, L-80, BTC Mod 0 0= Centrilift Tandem ESP (drift ID = 6.875 ", cap. = 0.0459 bpf) 0 1 00 -P31 SXD 12,654' (Cap. w/ 2 7/8" Tbg inside = 0.0379 bpf) /_ 18 -P75 SXD MVP painagaie � M Gas Separator GRSFTX AR 12,679' 4.5" 12.6 # /ft, IBT, mod. ( drift id = 3.958" , cap = .0152 bpf) 0 " Tandem Seal Assembly 12,684' /_ Centrilift Motor 12,698' 266 HP, 2345 v/ 69 amp masa- mum ISIBLST WeIILift MGU Sensor 12,721' 43 co. Baker Tie back sleeve '✓ 1 12,735' 1 Baker 7 - 5/8" x 5 - 1/2" "ZXP" liner pkr{ 12,746' 7-5/8", 29.7# L -80 BTC. shoe 1 12,883' II CTD Window - 13460 - 13480 Perforation Summary / 2 -7/8" L -80 Slotted Liner 13482 - 15123 Ref log: Tied Jewelry log into MWD 4107104 — _ Size SPF Interval (TVD) J 3 -3/8" 12 13,566' - 13,576' 7,297' - 7,307' 3 -3/8" 12 13,580' - 13,600' 7,311' - 7,331' 2 -7/8" 6 13,619' - 13,628' 7,350' - 7,359' n 2 - 7/8" Slot/Perf Liner 13696 - 15501 PF -3412 HMX Charges / 12 SPF 3.3/8" / . 69" hole .� 2 HES RTTS slip segments 4.5" Landing collar (PBTD) 13,727' 4.5" 12.6 #, L -80 float shoe 13,815' DATE REV. BY COMMENTS MILNE POINT UNIT ■ 04/09/04 MUO Drilled and completed Doyon 14 WELL MPC -43 L1 & L1 -01 04/26/04 MDO Add Frac perfs 05/25/05 MDO Converted to ESP Nabors 4ES 01/14/09 Nordic 2 CTD Laterals API NO: 50- 029 - 23200 -00 2/10/09 REH Re- complete w/ ESP - Nabors 3S BP EXPLORATION (AM , • i bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 a, o `4 _ 23q ' 3 _, �.� \:k7 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission s.= ` zonitsvoll 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPC -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPC -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely Mehreen Vazir BPXA, Well Integrity Coordinator r .--v - ,-- _�,. „,,,•,.,...r,r _ _ - 'ate°'" wt n . _ " ' T- 4- 7 "" °"" -", " n '.',,f' G3 '''' 3v"* 7, "�'a' 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) MPC -Pad 10/9/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal MPC-01 1811430 50029206630000 Sealed conductor NA NA NA NA NA MPC-02 1821940 50029208660000 Sealed conductor NA NA NA NA NA MPC-03 1820500 50029207860000 Sealed conductor NA NA NA NA NA MPC-04 1821260 50029208010000 Sealed conductor NA NA NA NA NA MPC-05A 1842430 50029212440100 Tanko conductor NA NA NA NA NA MPC-06 1842410 50029212570000 Tanko conductor NA NA NA NA NA MPC -07 1850020 50029212660000 Tanko conductor NA NA NA NA NA MPC -08 1850140 50029212770000 Tanko w/o top NA NA NA 3.4 10/9/2011 MPC -09 1850360 50029212990000 Tanko conductor NA NA NA NA NA MPC-10 1850150 50029212780000 Tanko conductor NA NA NA NA NA MPC -11 1850590 50029213210000 Tanko conductor NA NA NA NA NA MPC -12A 1990910 50029213730100 Tanko conductor NA NA NA NA NA MPC -13 1850670 50029213280000 Tanko conductor NA NA NA NA NA MPC -14 1850880 50029213440000 1.8 NA 1.8 NA 5.1 8/31/2011 MPC-15 1851030 50029213580000 Sealed conductor NA NA NA NA NA MPC-16 1851100 50029213640000 Sealed conductor NA NA NA NA NA MPC-17 1852630 50029214730000 Tanko conductor NA NA NA NA NA MPC-18 1852690 50029214790000 Abandoned NA NA NA NA NA MPC-19 1852960 50029215040000 Tanko conductor NA NA NA NA NA MPC-20 1890150 50029219140000 Tanko conductor NA NA NA NA NA MPC -21 1940800 50029224860000 4.6 NA 4.6 NA 8.5 8/29/2011 MPC -22A 1951980 50029224890100 38 NA Need top job MPC -23 1960160 50029226430000 1.9 NA 1.9 NA 17.0 8/28/2011 MPC -24 2010940 50029230200000 1.6 NA 1.6 NA 20.4 8/28/2011 MPC -25A 1960210 50029226380100 1.7 NA 1.7 NA 17.0 8/28/2011 MPC-26 1952060 50029226340000 1.8 NA 1.8 NA 17.0 8/28/2011 MPC -28A 2051630 50029226480100 1.6 NA 1.6 NA 102 8/29/2011 MPC-36 1980010 50029228530000 4.5 NA 4.5 NA 45.9 8/29/2011 MPC-39 1972480 50029228490000 5.5 NA 5.5 NA 49.3 8/29/2011 MPC-40 2002130 50029228710000 0.75 NA 0.75 NA 5.1 8/29/2011 MPC-41 2010780 50029230140000 0.5 NA 0.5 NA 8.5 8/31/2011 MPC-42 2040280 50029231960000 1.5 NA 1.5 NA 13.6 8/30/2011 •-•-* MPC-43 2040390 50029232000000 3.3 NA 3.3 NA 30.6 8/30/2011 STATE OF ALASKA RECEIVED • , �� 1 ,0 ALA• OIL AND GAS CONSERVATION COM ION , /;r1 (t � �� -� 1 2 REPORT OF SUNDRY WELL OPE IONS ;,.:,.;:it its ,x N Cons. - ommission 1. Operations Performed: nchhoirage ❑ 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 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development- ❑ Exploratory 204 -039 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 -029- 23200 -00 -00 - 7. KB Elevation (ft): 51 1, 9. Well Name and Number: MPC - 8. Property Designation: 10. Field / Pool(s): - ADL 047434 & 355017 - Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 13817' - feet true vertical 7547 - feet Plugs (measured) None Effective depth: measured 13727' feet Junk (measured) Yes, Unknown Depth true vertical 4736' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 112' 112' 1490 470 Surface 9328' 10 -3/4" 9363' 4736' 5210 2480 Intermediate Production 12850' 7 -5/8" 12883' 6641' 6890 4790 Liner 1080' 4 -1/2" 12735' - 13815' 6503' - 7545' 8430 7500 *MAU JUL 1 2 tail Perforation Depth MD (ft): 13566' - 13628' Perforation Depth TVD (ft): 7298' - 7359' 2 -7/8 ", 6.5# L -80 12715' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): None 12. Stimulation or cement squeeze summary: CC \\ C V \O( = 0$ Intervals treated (measured): Treatment description including volumes used and final pressure: 12/10/08 - 12/24/08: Pull ESP, Clean out wellbore and run Work String for CTD work (Added two multilateral legs: MPC -43L1 & MPC- 43L1 -01); 02/03/09 - 02/10/09: Pull workstring, run ESP Completion (Post CTD work) 13. _ Representative Daily Average Production or Injection Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 180 45 403 240 221 Subsequent to operation: 995 478 1,437 360 215 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 Mackie Derrick, 564 - 5891 N/A Printed Name T,errie Hubble Title Drilling Technologist M Prepared By Name/Number: �� 1 Phone 564 - 4628 D ate 03 I� 0 T Terrie Hubble, 564 -4628 Form 10-404 Revised 04 /2006 Submit Original Only . , ' $F ',!1, , s 2000--5 ( c4 _____A • • MPC -43, Well History (Pre & Post CTD Sidetrack) Date Summary 10/12/08 T /I /0= 200/300/0 Freeze Protect - Pump tbg w/5 bbls neat methanol & 15 bbls diesel. Freeze protect flow line w/4 bbls 60/40 methanol, 6 bbls diesel & 4 bbls 60/40 methanol. Shut laterals & bleed to 0 psi. IA/OA & master open. Wing, swab & ssv closed. Tag well & notify operator. Final WHP's= 200/280/0 10/17/08 T /I /0= 100/330/0. MIT OA to 2000 psi. Failed. Lost 400 psi in 15 minutes. Establish LLRT .9 bpm @ 1600 psi for 5 bbls. Monitor OA pressure. Bleed OA pressure down to 0 psi. FWHP = 100/330/0. 11/02/08 T /I /O =SSV /400/120, Temp =Sl. PPPOT-T-T (PASS), pre CTD. PPPOT -T: Stung into test port (200 psi), bled to 0 psi. Functioned LDS (ET style), all moved freely (1"). Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi 11/20/08 MADE 15 MIN GRADIENT STOP @ 12,148' SLM (12,145' MD). MADE 3 HR SBHP STOP @ 12,607' SLM (12,648' MD). PULLED 1" DGLV FROM ST #1 @ 12,482' MD. LEFT POCKET EMPTY PULLED 1" DPSOV FROM ST #2 @ 139' MD. SET 1" DGLV IN ST #2 @ 139' MD. WELL SUPPORT SET BPV. WELL LEFT S /I. PAD OP NOTIFIED. JOB COMPLETED. ,..s. . _ �"'.� °:Yss., i ",• e '3 �. �'Sht..r.. .'�,:;r ,r. taw „.;:4 ,$.. s.- s. Ama,r. � , ,.. k. ` ";�.o� ak ?4, .. .. re 4" a 5 o , 'x.3- 7 ". " € s .- , . ,v_ ., ^ d�"�,� �eza..r � dtt 01/14/09 T /I /O= 0/0/0 (Freeze Protect Post RWO). Pumped 15 bbls Diesel down tubing. FWHP = 0/0/0 Master, SSV, IA, OA, Wing , and Swab closed. 01/15/09 SPOT UP EQUIPMENT R/U SURFACE EQUIPMENT TEST WIRE REPACK STUFFING BOX. 01/16/09 MADE FRIST @ 12,737' SLM FOR ONE HR TIME 06:10 TO 07:10. MADE SECOND STOP @ 13,300 SLM FOR 3 HRS TIME 07:20 TO 10:20. RAN 2.5" MAGNET DOWN TO 3500 SLM SEVERAL TIMES, AND 3.5" MAGNET TO 7500'. RECOVERED TOTAL OF 3 CUPS METAL SHAVINGS. LAY DOWN EQUIPMENT FOR HIGH WIND 40+ MPH. 01/17/09 RAN 3.50" MAGNET TO 12730' SLM MULTIPLE TIMES. RECOVERED TOTAL OF 2.5 CUPS. RAN 3.80" MAGNET TO 12730' SLM SAT DOWN @ 2110 MD. RECOVERED 1/4 OF CUP. RUNNING 4.5 BRUSH W/ KJ, 3.5 MAGNET. 01/18/09 RAN 4.5 BRUSH, 3.5 MAGNET TO 12,705 SLM. WORK BRUSH FOR 15 MIN. RECOVERED TOTAL OF 1/2 CUP OF SHAVINGS IN 3 RUNS. RAN 4.5" BLB W/ 3.80" G. RING TO 12705' MD. WORK BRUSH. SET 3.813" X -LOCK, PX -PLUG BODY (3.805" OD), (4) 3/16" EQ PORTS. LIH = 26" SET @ 12705 MD. SET PRONG @ 12711 SLM. 01/19/09 T /I /0= 150/0/0 ( Assist Slickline. MIT- Tubing to 2000 psi.) PASSED. Pumped 3.7 bbls Diesel down tubing to bring pressure up to 2000 psi. Lost 60 psi in first 15 minutes. Lost 20 psi in second 15 minutes. Performed 2nd test with additional 0.1 bbls diesel to bring pressure from 1920 psi. to 2000 psi. Lost 0 psi in thirty minutes. FWHP = 150/0/0 Swab, SSV, and Wing closed. Master, IA, and OA open. 01/19/09 SET PX PLUG @ 12705 MD. PERFORMED MIT -T TO 2000 PSI - GOOD TEST. R /D. 01/20/09 T /I /O =0/0/0 (CMIT T x IA to 2000 psi.). Pumped .6 bbls Diesel down tubing to bring pressure up to 1400 psi. No change on IA. Bleed tubing down to 0 psi. Pumped 2.2 bbls into IA to bring pressure up to 2000 psi. Tubing pressure came up to 280 psi. Bleed pressure down to 0 psi on IA and tubing. FWHP = 0/0/0. Page 1 of 2 • • MPC -43, Well History (Pre & Post CTD Sidetrack) Date Summary 01/21/09 INITIAL T/ I/ O = 0 /0 /0 SSV CLOSED. RAN SMALL CHARGE TUBING PUNCHER AND SHOT 12670 ' - 12672', ALL SHOTS FIRED. DEPTH CORRECTED TO TUBING TALLY AFTER LIGHTLY TAGGING PX PLUG AT 12696'. LRS ATTEMPTED TO CMIT TxIA, COULD NOT ESTABLISH COMMUNICATION. SLB RIG UP SECOND TUBING PUNCHER. RAN MEDIUM CHARGE PUNCHER AND SHOT 12657' - 12659', 3' AWAY FROM COLLAR. HAD 500 PSI ON TBG AND 0 PSI ON IA PRIOR TO SHOOTING. AFTER SHOOTING TBG DROPPED TO 250 PSI, IAP INCREASED TO 200 PSI. LRS TO CMIT AFTER E -LINE RDMO. DSO NOTIFIED WELL SHUT -IN AND SECURE AND OF VALVE PLACEMENT. FINAL PRESSURES 100/50/0. JOB COMPLETE. 01/21/09 T /I/O= 0/0/0. CMIT T x IA to 2000 psi. Passed. Lost 40 psi on tbg & IA in first 15 minutes & 0 psi on tbg & IA in second 15 minutes. Bleed tbg & IA pressures down to 0 psi. FWHP = 0/0/0. y . r w a ray y Page 2 of 2 • • BP EXPLORATION Page 1 of 6 Operations Summary Report Legal Well Name: MPC -43 Spud Date: 3/19/2004 Common Well Name: MPC 43 S p Event Name: WORKOVER Start: 12/8/2008 End: 12/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/24/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/8/2008 12:00 - 22:00 10.00 MOB P PRE Rig released from MPG -02 @ 12:00. Prep for Rig move. Disassemble rig modules and components. Move Carrier off Well, witnessed by Pad operator, BP/WSL and NAD tourpusher. 22:00 - 23:00 1.00 MOB P PRE Travel from MPG Pad to MPC Pad. 23:00 - 00:00 1.00 MOB P PRE Spot Camp. 12/9/2008 00:00 - 03:30 3.50 MOB P PRE Spot Shop, Gen set, parts house and Rig components, lay mats and spot BOP shipping cradle behind. 03:30 - 09:00 5.50 MOB P PRE Back Carrier over Well C -43 with BP/WSL and NAD Tourpusher present. Spot pipe shed, Wind speed = 27 mph. Spot Mud Pits and Cuttings Box. Berm around the Cellar and spot the Tiger Tank. 09:00 - 12:30 3.50 RIGU P PRE Secure the Cellar. Work on minor welding projects in the Cellar. Remove steam heater, change out heating core and reconnect. Hook up mud lines and take on fluid to the Pits. 12:30 - 18:00 5.50 RIGU P PRE Raise the Derrick but do not scope due to high winds and Derrick visibly rocking. Secure Derrick legs. Turn on steam around the Rig. Lay plywood around the Tree and Cellar. Find leak on bottom of Pits Module in Pit #2. Have vac truck suck out seawater from Pit #2 and begin diagnosis of where the issue might be. Maintain the Rig while waiting on weather. 18:00 - 19:30 1.50 RIGU P PRE RU circulating lines to kill the well. 19:30 - 00:00 4.50 RIGU N WAIT PRE Maintain the Rig while waiting on the weather. Wind speeds at 30+ mph preventing the safe scope up of the Derrick. Clean and maintenance projects while waiting. Continue diagnosis of leak in bottom of Pit #2. 12/10/2008 00:00 - 07:00 7.00 RIGU N WAIT PRE Maintain the Rig while waiting on the weather. Wind speeds at 30+ mph preventing the safe scope up of the Derrick. Clean and maintenance projects while waiting. Continue diagnosis of leak in bottom of Pit #2. 07:00 - 08:30 1.50 RIGU P PRE The winds have died down and safe to proceed with work. Scope the upper section of the Derrick and secure. The Rig was accepted at 0830 hrs on 12/10/2008. 08:30 - 12:00 3.50 KILL P DECOMP Finish spotting and rigging up the hardline to the Tiger Tank. Blow steam through to ensure the line is clear - OK. RU double annulus valve, Kill Manifold and circulating lines to the Tree. 12:00 - 00:00 12.00 KILL N RREP DECOMP Troubleshoot and repair the leak in Pit #2. Removed the old equalizing box and riser from the floor of Pit #2. A crack was found in the floor near the placement of the box and repaired along with the seam behind the box that was never welded shut. 12/11/2008 00:00 - 19:30 19.50 KILL N RREP DECOMP Filled pit #2 with water and it was leaking. Sucked water from pit and clean walls for inspection. After further inspection, holes were found in the corners of the sump and repaired by the welder. Tuboscope on location at 1000 hrs and conduct inspection of the floor in Pit #2. Weld under agitator has a 1 -1/2" long crack in it needing to be re -done. Heavy corrosion visually found near the sump and piping. The floor thickness found to be 0.186" with 0.130" depth giving 0.056" remaining body wall. Call out GBR welders to assist rig welder with repairs. 19:30 - 20:30 1.00 KILL N DECOMP Held safety stand down and discussed hand incident on ADW Printed: 3/4/2009 2:32:23 PM • • BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 12/8/2008 End: 12/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/24/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/11/2008 19:30 - 20:30 1.00 KILL N DECOMP rig. 20:30 - 00:00 3.50 KILL N RREP DECOMP Continue repairs on pit #2 with GBR welders. 12/12/2008 00:00 - 06:00 6.00 KILL N RREP DECOMP Continue welding on pit #2. Released GBR welders at 0200 hrs due to hours worked consecutively. GBR to send additional welders to the Rig with day crew. 06:00 - 20:30 14.50 KILL N DECOMP Pre -tour safety meeting with stand down held. Discussed recent DAFWC incidents as well as the first aid (could have been DAFWC) at 2ES. Main communication was staying focused and in the moment. GBR welders arrive on location at 0630 hrs. Continue welding in Pit #2. 20:30 - 21:30 1.00 KILL N DECOMP Fill #2 Pit with water and check for leaks (No leaks observed). Clean up area outside of pits from welding project. 21:30 - 00:00 2.50 KILL C DECOMP Ordered 2 loads of 130 degree seawater @ 2100 hrs. R/U LRS and pressure test circulating lines to 3500 psi. (Good Test). Wait on trucks. 12/13/2008 00:00 - 04:00 4.00 KILL C DECOMP Continue to wait on trucks with 130 degree seawater. Clean and service rig. Hold safety meeting with crew discussed recent hand injuries. 04:00 - 05:00 1.00 KILL P DECOMP Pressure test lubricator to 500 psi and null BPV. Tubing =540 psi , IA =500 psi , OA =90 psi 05:00 - 09:30 4.50 KILL C DECOMP Continue to wait on trucks with 130 degree seawater. 09:30 - 10:00 0.50 KILL P DECOMP Hold pre -kill safety meeting with the crew and CH2M Hill vac truck drivers. 10:00 - 13:30 3.50 KILL P DECOMP Open the well and monitor the pressures: Tubing = 620 psi , IA = 550 psi , OA = 90 psi. Bleed the IA down to 200 psi and start getting fluid to the Tank. Break circulation with 130 degree, 8.5 ppg seawater down the Tubing taking returns up the IA with both the Rig Pump and Little Red at a combined rate of 4 bpm / 1,000 psi on the Tubing and 150 psi on the IA. Pump 80 bbls and shut down the pump and close the Choke to bullhead. Got 40 bbls returns in the Tiger Tank (50% returns). Bullhead 35 bbls of seawater with Little Red alone at a rate of 3 bpm / 900 psi on the Tubing. Open the Choke and resume circulating out the well with both the Rig Pump and Little Red at a combined rate of 5.3 bpm / 2,100 psi with the IA working from 200 psi up to 350 psi max and final pressure of 100 psi. Pumped a total of 675 bbls of seawater after the bullhead to finish cleaning up the well. Got 500 bbls returns ( -74% returns) after bullheading. Weight of fluid in = 8.5 ppg , weight of returns = 8.5 ppg. 13:30 - 14:30 1.00 KILL P DECOMP Shut down and monitor the well for 30 minutes. Both the Tubing and IA are on a vacuum. Blow down and disconnect lines from the Tree. RD Kill Manifold. Blow down and RD Little Red. RU Little Red to gravity feed the IA. 14:30 - 15:30 1.00 WHSUR P DECOMP PU T -bar and set 2" Type "H" TWC with FMC rep. Pressure test to 3,500 psi for 10 charted mins from above - good test. 15:30 - 17:30 2.00 WHSUR P DECOMP PJSM with crew. Bleed Hanger void with FMC rep. ND 2- 9/16" Tree and Adapter Flange. Check Hanger Threads and they are 2 -7/8" EUE 8rd, screw into them with 9 -3/4 turns. 17:30 - 18:00 0.50 WHSUR P DECOMP Stand up BOP's on craddle. 18:00 - 21:00 3.00 BOPSUF P DECOMP N/U BOPE. 21:00 - 21:30 0.50 BOPSUF P DECOMP Break adapter from tree and remove both from cellar. 21:30 - 00:00 2.50 BOPSUF P DECOMP Test BOPE. Test VBR with 2 -7/8 ", 3 -1/2 ",and 4 -1/2" test joints. Test annular with 2 -7/8" test joint. Test choke and all Printed: 3/4/2009 2:32:23 PM • • I • BP EXPLORATION Page 3 of 6 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 12/8/2008 End: 12/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/24/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/13/2008 21:30 - 00:00 2.50 BOPSUF P DECOMP associated valves. All test 5 minutes each to 250 psi low and 3500 psi high. Witness of test waived by Chuck Scheve with AOGCC @ 0800. Test witnessed by WSL and Toolpusher. 12/14/2008 00:00 - 01:30 1.50 BOPSUF P DECOMP Continue testing BOPE. 01:30 - 02:00 0.50 BOPSUF P DECOMP UD test joint and suck out BOP and blow down choke manifold 02:00 - 03:30 1.50 BOPSUF P DECOMP R/U lubricator and test to 500 psi with diesel. Pull TWC, tubing on vac. Rig down lubricator. 03:30 - 04:30 1.00 PULL P DECOMP P/U landing joint and M/U 9 -3/4 turns. Pull hanger off seat. Moved @ 82k and pulled @ 87k. 04:30 - 07:30 3.00 PULL P DECOMP CBU @ 4BPM with 1100 psi, losses @ 51 BPH. Pumped a total of 565 bbls with minimal crude returns on surface. Total losses 87 bbls while CBU. 07:30 - 08:30 1.00 PULL P DECOMP Monitor the well and it is on a vac. Lay down the Landing Joint and Tubing Hanger. RD circulating equipment. 08:30 - 00:00 15.50 PULL P DECOMP POOH with existing 2 -7/8" Tubing ESP Completion laying down, in the Pipe Shed. Regulating hole fill at 20 bbls per hour fill rate with seawater. 130 Joints out at 1600 hrs. 12/15/2008 00:00 - 03:30 3.50 PULL P DECOMP Continue POOH with existing 2 -7/8" Tubing ESP Completion laying down in the Pipe Shed. Regulating hole fill at 20 bbls per hour fill rate with seawater. Recovered 401 joints of 2 -7/8" 6.5 # L -80 8rnd EUE tubing , 2 ea 10' pup joints , 1 ea 2' pup joints , 2 ea GLM's , 1 ea XN nipple , 207 ea Lasalle clamps , 6 ea Protecterlizers , 3 ea Flat gaurds. 03:30 - 06:30 3.00 PULL P DECOMP PJSM - Lay down ESP pump with Centrilift hand present. 06:30 - 08:00 1.50 PULL P DECOMP Lay down Centrilift tools and remove from the Rig Floor. RD Elephant Trunk. 08:00 - 09:00 1.00 PULL P DECOMP Clear and clean Rig Floor. 09:00 - 09:30 0.50 PULL P DECOMP Service / lubricate the Rig and all floor equipment. 09:30 - 13:00 3.50 CLEAN P DECOMP PU Rathole and set in place. RD Bails from Blocks. PU Swivel and attach to Blocks. PU Kelly Bushing. PU Kelly and MU Bushing to the Kelly. Set back Kelly in the Rathole. 13:00 - 16:00 3.00 CLEAN P DECOMP RU 3 -1/2" Handling Equipment. Load 3 -1/2" Drill Pipe in the Pipe Shed and strap. 16:00 - 17:00 1.00 WHSUR P DECOMP PU Joint with 4 -1/2" IF connection. Set 9.125" ID Wear Ring. LD Joint. 17:00 - 00:00 7.00 CLEAN N WAIT DECOMP Milne Point calls Phase III Conditions. Kuparuk is also in Phase III. Not able to perform crew change. Shut down operations on the Rig., Regulate hole fill at 10 bbls per hour fill rate and monitor the well continuously. 12/16/2008 00:00 - 09:00 9.00 CLEAN N WAIT DECOMP Milne Point calls Phase III Conditions. Kuparuk is also in Phase III. Not able to perform crew change. Shut down operations on the Rig. Regulate hole fill at 10 bbls per hour fill rate and monitor the well continuously. Milne Point called Phase II at 00:30 hrs called Herb Williams about making crew change. Made crew change with heavy equipment escort at 01:00 hrs. Made crew change again at 0830 hrs. Hold pre -tour meeting and perform daily checks. 09:00 - 10:00 1.00 CLEAN P DECOMP PUMU BHA #1 with Baker rep as follows: Polishina Mill. Spacer Sub, Spacer Sub, Top Dressing Mill, 4 ea 4 -3/4" Drill Collars. OAL = 133.54'. The purpose of this BHA is to go downhole and dress off the top of the 4 -1/2" Liner at 12,735'. 10:00 - 21:00 11.00 CLEAN P DECOMP TIH with BHA #1 on 3 -1/2" Drill Pipe from the Pipe Shed 1 x 1. Regulate hole fill at 20 bbls per hour fill rate with seawater. Printed: 3/4/2009 2:32:23 PM • • BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 12/8/2008 End: 12/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/24/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/16/2008 21:00 - 23:30 2.50 CLEAN P DECOMP P/U kelly and torque. Test to 250 psi low and 3500 psi high for 5 charted minutes each. Stand back Kelly. 23:30 - 00:00 0.50 CLEAN P DECOMP TIH with BHA #1 on 3 -1/2" Drill Pipe from the Pipe Shed 1 x 1. Regulate hole fill at 20 bbls per hour fill rate with seawater. 12/17/2008 00:00 - 03:00 3.00 CLEAN P DECOMP Continue to TIH with BHA #1 on 3 -1/2" Drill Pipe from the Pipe Shed 1 x 1. 406 jts. Regulate hole fill at 20 bbls per hour fill rate with seawater. Up wt. - 183k Dn wt. - 54k 03:00 - 04:00 1.00 CLEAN P DECOMP Pick up kelly and tagged up at 12731'. 04:00 - 09:00 5.00 CLEAN P DECOMP Line up and pump down DP @ 2.5 BPM 620 psi while reciprocating DP to clean up hole. Pumped 352 bbls and pump sweep around. 09:00 - 14:30 5.50 CLEAN P DECOMP Mix and pump 1 % "safe lube" to reduce torque. Dress off from 12,730' to 12,739' at 3 bpm / 770 psi, PUW = 175 K, SOW = 65 K, ROT WT = 95 K. 14:30 - 16:00 1.50 CLEAN P DECOMP CBU with Hi -vis sweep, at 3 bpm / 770 psi untill clean. Observed well. Blow down kelly and set back. 16:00 - 00:00 8.00 CLEAN P DECOMP POH from 12,739' with BHA #1 standing back 3 -1/2" DP in derrick with continuous hole fill. 12/18/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Continue to POH with BHA #1 standing back 3 -1/2" DP in derrick with continuous hole fill. 00:30 - 01:30 1.00 CLEAN P DECOMP UD BHA #1. Polish mill showed good sign of being on top of liner. 01:30 - 02:30 1.00 CLEAN P DECOMP Clear and clean rig floor. 02:30 - 03:00 0.50 CLEAN P DECOMP Hold safety meeting with rig crew and discussed permitting process. 03:00 - 04:30 1.50 EVAL P DECOMP PUMU BHA #2. Mule shoe, 4 -1/2" RBP, Setting tool, X -O, 3) 2 -7/8" Pac DP, X -O. 04:30 - 06:00 1.50 EVAL P DECOMP RIH with BHA #2 on 3 -1/2" DP from derrick. 20 stands in at 06:00 hours. 06:00 - 06:30 0.50 EVAL P DECOMP Rig service 06:30 - 13:00 6.50 EVAL P DECOMP Continue RIH with BHA #2 on 3 -1/2" DP from Derrick, Tag liner Top - 12,730'. 13:00 - 18:00 5.00 EVAL P DECOMP PU kelly, go into liner 25ft, Can not go past 12.755' with 15 K down weight. Made repeated attempts to set HES / RBP with HES rep from 12,735' to 12,755'. PUW = 136 K, SOW = 70 K. 18:00 - 00:00 6.00 EVAL P DECOMP POH from 12,755' with BHA #2 and stand back 3 -1/2" DP in Derrick continuos hole fill. 110) Stands in derrick @ 00:00. 12/19/2008 00:00 - 03:00 3.00 EVAL C DECOMP Continue POOH with BHA# 2 standing back 3 -1/2" DP in derrick with continuous hole fill. Monitor well on last stand before BHA. 03:00 - 04:00 1.00 EVAL C DECOMP UD BHA #2. 4 -1/2" RBP missing 2) upper slip seamants and rubber element cut. Talked to Anchorage Engineering and discussed redressing and rerun RBP. (No slip segments on Slope) 04:00 - 05:30 1.50 EVAL P DECOMP PJSM - Cut and slip drilling line. 05:30 - 12:00 6.50 EVAL X DECOMP Confer with ADW Anchorage Engineering on plan forward. Wait on 3.80" mill / string mil from Baker Machine Shop. 12:00 - 13:00 1.00 WHSUR P DECOMP FMC wellhead tech tested 7 -5/8" pack -off to 4,000 psi for 30 minutes, good test. Witnessed by BP/WSL. 13:00 - 16:00 3.00 EVAL X DECOMP Continue to wait on Mill. 16:00 - 16:30 0.50 EVAL P DECOMP PJSM. PUMU 3.80" Junk mill with string mill on 2 -7/8" PAC DP. 16:30 - 22:00 5.50 CLEAN P DECOMP RIH with BHA #3 for clean out run to set 4 -1/2" RTTS on 3 -1/2" Printed: 3/4/2009 2:32:23 PM • • BP EXPLORATION Page 5 of 6 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 12/8/2008 End: 12/24/2008 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 12/24/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/19/2008 16:30 - 22:00 5.50 CLEAN P DECOMP DP from Derrick to 6917' 21:00 - 21:30 0.50 CLEAN P DECOMP Service rig, daily inspections. 21:30 - 00:00 2.50 CLEAN P DECOMP Continue to RIH with BHA #3 for clean out run to set 4 -1/2" RTTS on 3 -1/2" DP from Derrick from 6917' to 12180'. 12/20/2008 00:00 - 01:00 1.00 CLEAN P DECOMP Continue to RIH with BHA #3 for clean out run to set 4 -1/2" RTTS on 3 -1/2" DP from Derrick from 12180' to 12724'. Up wt. =145 Dn wt. =54. 01:00 - 02:00 1.00 CLEAN P DECOMP PUMU kelly and circulate steel lube EP @ 1% concentration @ 4 BPM 950 psi. Up wt. =138 Dn wt. =65 Rt wt. =95 Tq. =9k with pump on. 02:00 - 04:00 2.00 CLEAN P DECOMP Circulate steel lube EP @ .6% concentration surface to surface @ 4 BPM 950 psi to reduce Torque. 04:00 - 05:30 1.50 CLEAN P DECOMP Parameters after circulating steel lube EP - Up wt. =132 Dn wt. =73 Rot. wt. =95 Tq. =7k. Wash down and then rotate twice each down into 4 -1/2" liner to 12795'. Torque dropped off to 5k. No problems going into liner or getting down to 12795' 05:30 - 08:30 3.00 CLEAN P DECOMP Pump Hi -vis sweep and circulate sweep back to surface. Pumped 530 bbls at 3 -1/2 bpm / 900 psi. 08:30 - 09:00 0.50 CLEAN P DECOMP Monitor well, 18 -20 bph / loss. 09:00 - 10:00 1.00 CLEAN P DECOMP Set back and blow down kelly, and UD (2) 20 ft DP pups. 10:00 - 18:00 8.00 CLEAN P DECOMP POH from - 12,730' to 830'. Loss rate is -10 bph. 18:00 - 18:30 0.50 CLEAN P DECOMP Sevice rig and daily inspections. 18:30 - 19:00 0.50 CLEAN P DECOMP Continue POH from 830' to BHA. Monitor well on last stand of DP. 19:00 - 20:00 1.00 CLEAN P DECOMP Lay down BHA #3. Clear and clean rig floor. 20:00 - 21:00 1.00 CLEAN P DECOMP PUMU BHA #4. 4 -1/2" RTTS, 2) X -O's, 3) Jts. 2 -7/8" Pac DP, X -O. 21:00 - 00:00 3.00 CLEAN P DECOMP RIH with BHA #4 on 3 -1/2" DP from derrick for setting RTTS to test casing and tie back. 12/21/2008 00:00 - 04:00 4.00 CLEAN P DECOMP Continue RIH with BHA #4 RTTS to set and test casing. Monitor hole fill and keep trip sheet. 04:00 - 05:00 1.00 CLEAN P DECOMP P/U kelly. Parameters - Up 112k Dn 76k RIH to 12767' to center of RTTS element, close Annular. 05:00 - 06:00 1.00 CLEAN P DECOMP Pressure test 7 -5/8" casing and tie back to 2500 psi for 30 charted minutes. Pumped 5.7 bbls total. 06:00 - 16:00 10.00 CLEAN P DECOMP POH from 12,767' with 4 -1/2" RTTS and LD / DP 1 x 1 in pipe shed. Joint #270. 16:00 - 17:30 1.50 CLEAN P DECOMP P/U Kelly and make service breaks and set back. 17:30 - 21:30 4.00 CLEAN P DECOMP Continue POH LD / DP from joint # 270 to # 408 monitor well on last stand before BHA. 21:30 - 22:30 1.00 CLEAN P DECOMP UD BHA #4 clean EP lube off while UD. 22:30 - 23:30 1.00 CLEAN P DECOMP Clean and clear rig floor of 2 -7/8" and 3 -1/2" handling equipment. 23:30 - 00:00 0.50 CLEAN P DECOMP Pull wear bushing. 12/22/2008 00:00 - 02:30 2.50 CLEAN P DECOMP PJSM - Lay down Kelly, swivel, kelly bushings, rat hole, and mouse hole. 02:30 - 04:00 1.50 RIGU P RUNCMP PJSM - Rig up stabbing board to run chrome completion with compensator. 04:00 - 08:00 4.00 RIGU P RUNCMP Rig up torque turn equipment, double stack tongs, computer and compensator. 08:00 - 11:00 3.00 RIGU P RUNCMP Load last 2 rows of tubing in pipe shed, tally and drift. 11:00 - 11:30 0.50 RUNCOMP RUNCMP PJSM with csg crew and Baker rep. 11:30 - 00:00 12.50 RUNCOMP RUNCMP Run 4 -1/2 ", 12.6# 13Cr work string assembly fill every 10 joints Printed: 3/4/2009 2:32:23 PM • • BP EXPLORATION Page 6 of 6 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 12/8/2008 End: 12/24/2008 Contractor Name: NABORS ALASKA DRILLING 1 Rig Release: 12/24/2008 Rig Name: NABORS 3S Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 12/22/2008 11:30 - 00:00 12.50 RUNCOMP RUNCMP with seawater, fill back side continuously. (140 jts. ran @ 00:00 hrs) 12/23/2008 00:00 - 01:00 1.00 RUNCOMP RUNCMP Shut down for lunch due to lack of manpower while running Chrome. Hold safety meeting with crew and discuss how job is going 01:00 - 06:00 5.00 RUNCOMP RUNCMP Continue to run 4 -1/2 ", 12.6# 13Cr work string assembly, fill every 10 joints with seawater, fill back side continuously. (235 jts. ran @ 06:00 hrs) 06:00 - 13:30 7.50 RUNCOMP RUNCMP Continue to run 4 -1/2 ", 12.6# 13Cr work string assembly, from Joint #235 to joint #318. 13:30 - 18:00 4.50 RUNCOMP RUNCMP PUW = 105K, SOW = 60K. Tag top of tie -back at 12,759'. Confirm depth from surface with several tags and visibly seeing fluid level drop when pulling out of PBR 10.5' with seal assembly. LD jts used to tag and work space -out calculation. MU 5 total pup jts = 37.22'. MU top single joint ( #318 on tally). Ran a total of 313 jts. MU tubing hanger to tubing string. MU XO to landing joint and screw into hanger 7 -3/4 turns. 18:00 - 19:00 1.00 RUNCOMP RUNCMP Land tubing hanger PUW = 105K, SOW = 60K. LD landing jt. and XO. 19:00 - 20:30 1.50 RUNCOMP RUNCMP RD Nabors casing equipment. Clear rig floor. 20:30 - 23:30 3.00 RUNCOMP RUNCMP RU and test tubing to 2500 psi for 30 min - charted. Bleed tubing to 1500 psi, test IA to 2500 psi for 30 min - charted. Bleed IA then tubing to 0 psi. Pressure up IA and shear DCK at 1400 psi. Circulate 2 bbls both ways to ensure good shear. Suck out stack. 23:30 - 00:00 0.00 RUNCOMP RUNCMP Dry rod TWC with FMC rep. Preo to test. 12/24/2008 00:00 - 01:30 1.50 RUNCOMP RUNCMP Pressure test TWC from below to 1000 psi for 10 min - ch d, Test from above to 3500 psi for 10 min - charted. RD test equipment. 01:30 - 03:30 2.00 BOPSUF P RUNCMP PJSM. ND BOPE and lay in cradle. 03:30 - 06:00 2.50 WHSUR P RUNCMP PJSM. NU dry hole tree. RU lines to test. 06:00 - 07:00 1.00 WHSUR P RUNCMP Test tubing hanger void to 5000 psi for 30 minutes. Test tree to 5000 psi, with diesel, and chart for 10 minutes 07:00 - 10:00 3.00 WHSUR P RUNCMP Test lines from LRS to wellhead to 2500 psi. Test lines from wellhead to tiger tank to 1000 psi. Open well to 0 psi and circulate 125 Bbls of diesel down tubing with returns from annulus at 2 BPM and 1100 psi. U -tube tubing to IA for 30 minutes. 10:00 - 13:00 3.00 WHSUR P RUNCMP ND dry hole tree. Replace with complete tree. Test tree to 5000 psi for 5 min - charted. 13:00 - 15:00 2.00 WHSUR P RUNCMP Normal up tree and cellar. RD stabbing board and clear rig floor. Rig released at 15:00 Se_ .3Ols oct - c0 Printed: 3/4/2009 2:32:23 PM • BP EXPLORATION Page 1 of 4 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 2/3/2009 End: 2/10/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/10/2009 Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 2/2/2009 14:00 - 00:00 10.00 RIGD P PRE Rig released from MPL -12 at 14:00. Pepare for Rig move, rig maintenance. Trucks unavailable from Peak for moving rig. 2/3/2009 00:00 - 04:30 4.50 RIGD P PRE Trucks on location at 04:30. Disconnect rig modules, Lower derrick on to carrier. 04:30 - 06:00 1.50 MOB P PRE Pull Rig off of well, witnessed by DSO / WSL. Crew change. 06:00 - 09:30 3.50 MOB P PRE Let MPU Pad operators change out. 07:00 hours move off MPL -pad to MPC -pad. 09:30 - 10:30 1.00 MOB P PRE Spot Camp and Rig modules. 10:30 - 12:30 2.00 MOB P PRE Spot Carrier over Well witnessed by DSO / Nabors Toolpusher. Jack up and level Carrier. 12:30 - 16:00 3.50 MOB P PRE Spot Rig and Camp conponents, raise and scope up Derrick. 16:00 - 19:30 3.50 RIGU P PRE Rig up lines, handrails, berms, spot LRS and put steam around. Rig accepted at 19:30 hours. 19:30 - 20:00 0.50 WHSUR P DECOMP Held pre -spud meeting with Crew, LRS and truck drivers. 20:00 - 23:00 3.00 WHSUR P DECOMP RU kill manifold, second annulus valve, hard lines to choke and test to 2,000 psi. RU down stream lines to Tiger Tank. LRS RU and test lines to 3,000 psi. 23:00 - 00:00 1.00 WHSUR P DECOMP MU and test lubricator with diesel to 500 psi, Well techs pull BPV. Work through ice on top of BPV. WHP's = 0 psi on Tubing, 0 psi on IA, 0 psi on OA. 2/4/2009 00:00 - 01:30 1.50 KILL P DECOMP Change out frozen hose at Tiger Tank. RU and test hard line to tiger tank to 500 psi. 01:30 - 02:00 0.50 KILL DECOMP Truck drivers crew change, held pre -kill meeting. Ambient temp -38 DegF. 02:00 - 04:30 2.50 KILL P DECOMP WHP's, Tubing = 0 psi, IA = 0 psi, OA = 0 psi. Pump with Rig and LRS down the tubing with 570 bbls 140 DegF, 8.45 ppg seawater at 5 -6 bpm / 580 psi, taking returns through the choke to the Tiger Tank. Monitor Well 30 minutes. Well is static. 04:30 - 05:00 0.50 KILL P DECOMP Blow down all lines and manifolds. 05:00 - 06:30 1.50 WHSUR P DECOMP Dry rod TWC with FMC Well head tech, Test from above to 3,500 psi, and from below to 1,000 psi charted both for 10 minutes. - 06:30 - 07:30 1.00 WHSUR P DECOMP Blow down test equipment and kill equipment. RD Kill Manifold from the Cellar. 07:30 - 09:30 2.00 WHSUR P DECOMP ND the 4- 1/16" Tree and Adapter Flange. Check the Hanger threads with FMC rep. Got 6 out of 10 anticipated turns with the crossover. The threads are galled and will have to spear _the Hanger to decmmnIP.tP, Remove the Tree and Adapter Flange from the Cellar. 09:30 - 13:30 4.00 BOPSUF P DECOMP NU 11" x 13 -5/8" DSA and 13 -5/8" / 5K BOPE. 13:30 - 17:00 3.50 BOPSUF P DECOMP Change out the air boot and flange on top of the Annular to the new air boot and Dutch System. Cleaned out each bolt hole thoroughly and prepared for the new installation. 17:00 - 18:00 1.00 BOPSUE P DECOMP Function test BOPE. 18:00 - 00:00 6.00 BOPSUF P DECOMP Test BOPE 250 psi low / 3,500 psi high for 5 charted minutes each. Test 2 -7/8" x 5" VBR and Annular with 2 -7/8" and 4 -1/2" test joint against the TWC. Test witnessed by AOGCC rep Bob Noble, on 2 -4 -09 and NAD Toolpusher and BP WSL. 2/5/2009 00:00 - 00:30 0.50 BOPSUF P DECOMP Blow down lines and choke. 00:30 - 03:30 3.00 PULL P DECOMP Cut and slip 90 ft drilling line. Held after action review. 03:30 - 04:00 0.50 PULL P DECOMP PU / BO landing joint XO. 04:00 - 08:30 4.50 PULL P DECOMP PU and hang tubing stabbing board in Derrick. RU wind walls. 08:30 - 10:00 1.50 PULL P DECOMP RU Tubing Tongs (double stack) and change elevators to Printed: 3/4/2009 2:32:36 PM • • BP EXPLORATION Page 2 of 4 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 2/3/2009 End: 2/10/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/10/2009 Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 2/5/2009 08:30 - 10:00 1.50 PULL P DECOMP 3 -1/2" for pulling the Hanger. RD 2 -7/8" Handling Equipment. 10:00 - 11:00 1.00 PULL P DECOMP Service and lubricate the Drawworks, Drive Shaft, Crown and Blocks. 11:00 - 12:00 1.00 PULL P DECOMP Clear and clean Rig Floor. 12:00 - 13:00 1.00 PULL P DECOMP Pick up 4 -1/2" Handling Equipment to the Rig Floor. 13:00 - 14:00 1.00 PULL P DECOMP Wait on 7" Otis x 4" Otis XO to be delivered to the Rig to be able to make up the Milne Point Lubricator and Pump In Sub to the Dutch Lubricator Extensions. 14:00 - 17:00 3.00 WHSUR P DECOMP PUMU Dutch Lockdown Mandrel and 5' Lubricator Extension. RIH and seat on Lockdown Flange. Run in lock down studs to secure. Close the Annular. 17:00 - 19:00 2.00 WHSUR P DECOMP RU Pump In Sub and Lubricator. Pressure test to 500 - OK. Pull 4" TWC with Well Support . Techs. Check the well - static. LD lubricator. 19:00 - 19:30 0.50 WHSUR P DECOMP Pull and LD Dutch Mandrel system. 19:30 - 20:00 0.50 PULL P DECOMP MU 3.885" Itco spear, spear tubin ham er euLBOLDS, pull tubinchanger to floor, BO / LD Spear and tubing hanger, MU TIW valve. Observed 5 K dropped off when out of SBR, PUW = 105 K, SOW = 60 K. 20:00 - 21:00 1.00 PULL P DECOMP Attempt to Fill IA with seawater and flow line was lu ed resulting in a sill. Call in report to Milne Point # 3300. All appropriate notifications made. Clean -up. 21:00 - 00:00 3.00 PULL N DECOMP Replace 8 foot section of rubber flow line. 2/6/2009 00:00 - 01:30 1.50 PULL N DECOMP Replace 8 foot section of rubber flow line. 01:30 - 02:30 1.00 PULL P DECOMP Bull head 100 bbls 8.45 ppg seawater down IA at 2.5 - 3 bpm / 750 to 1000 psi. Flow check._ Loss rate - 6 bph._ 02:30 - 03:30 1.00 PULL P DECOMP RU chrome tools and compensator. 03:30 - 06:00 2.50 PULL P DECOMP POH from -12 700' inspect and lay down 4 1/2" chrome tubig. n Compensating each connection as breaking loose. Inspecting tubing with Vam representative as POOH. Use continuous hole fill with charge pump. LD 5 pups and 3 joints at 05:30 hours. 06:00 - 16:00 10.00 PULL P DECOMP Continue POH UD 4 -1/2" chrome tubing from joint #3 to # 82. x bad joints layed out. 16:00 - 18:00 2.00 PULL P DECOMP Lay down all tubing pups from rig floor, clean Rig floor and inspect all tubing handling tools. Make up XO's to floor safety valve for 4 -1/2" Vam Ace threads. 18:00 - 00:00 6.00 PULL P DECOMP Continue POH from joint # 83, inspect and lay down 4 -1/2" chrome tubing. Compensating each connection as breaking loose. Inspecting tubing with Vam representative as POOH. Use continuous hole fill with charge pump. At joint # 140 at 00:00 hours. -8 bph loss rate. 2/7/2009 00:00 - 06:00 6.00 PULL P DECOMP Continue POH from joint # 83, inspect and lay down 4 -1/2" chrome tubing. Compensating each connection as breaking loose. Inspecting tubing with Vam representative as POOH. Use continuous hole fill with charge pump. At joint # 214 at 05:30 hours. -8 bph loss rate. (2) bad joints of 4 -1/2" cr Vam Ace. 06:00 - 07:00 1.00 PULL P DECOMP Service the Rig and pre -tour checks. 07:00 - 16:00 9.00 PULL P DECOMP Resume POOH laying down 4 -1/2 ", 12.6 #, 13Cr, Vam Ace Tubing. Vam rep inspecting each Joint as POOH. Use compensator and stabbing guide to break out connections. Maintaining continuous hole fill with seawater with average loss Printed: 3/4/2009 2:32:36 PM • 0 BP EXPLORATION Page 3 of 4 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 2/3/2009 End: 2/10/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/10/2009 Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 2/7/2009 07:00 - 16:00 9.00 PULL P DECOMP rate of 9 bbls / hour. Recovered all workstring tubulars and jewelry. Total Joints marked as bad by Vam rep are: Vam Top = 19 Joints due to coil damage , Vam Ace = 4 Joints due to 3 ea galled seals and 1 ea pitted pin. 16:00 - 18:30 2.50 PULL P DECOMP RD Chrome handling toos and equipment, clean and clear Rig floor. 18:30 - 19:30 1.00 PULL P DECOMP RD and LD stabbing board from Derrick. 19:30 - 22:30 3.00 RUNCOMP RUNCMP Load and tally 2 -7/8" tubing into pipe shed. 2/8/2009 00:00 - 01:00 1.00 RUNCOMP RUNCMP Continue to load and tally 2 -7/8" tubing into pipe shed. Load ESP motor assembly into pipe shed. RU to run ESP completion. Maintaining continuous hole fill with seawater with average loss rate of 5 bbls / hour 01:00 - 03:00 2.00 RUNCOMP RUNCMP Spot ESP cable spooler unit, and load with ESP reels. 03:00 - 08:00 5.00 RUNCOMP RUNCMP PU / MU and service ESP pump and motor assembly. 08:00 - 08:30 0.50 RUNCOMP RUNCMP Add 2 pup joints to top of ESP assembly per Centrilift rep. Check the tech wire and it failed the test. Have to pull the assembly out of the hole and replace with new tech wire at the WeIILift MGU Sensor. 08:30 - 11:00 2.50 RUNCOMP RUNCMP POOH with ESP Assembly. Replace tech wire with new one with Centrilift rep. Also notice that there is a bad spot in the armor of the ESP Cable - Centrilift rep recommends replacing it. Cut off the bad armor section and replace with new. 11:00 - 17:00 6.00 RUNCOMP RUNCMP RIH with new ESP Assembly,on,2 -7/8 ", 6.5 #, L -80, EUE 8rd Tubing from the Pipe Shed. Ran ESP Assembly with new WeIILift Installation. Centrilift rep checked conductivity of ESP cable at 44 joints ran. 17:00 - 19:00 2.00 RUNCOMN RUNCMP Make repairs on 4" charge pump hose to the Mud pump. Perform pre -tour checks at crew change. 19:00 - 19:30 0.50 RUNCOMP RUNCMP Fill tubing and flush ESP pump with 10 bls seawater at 1 -1/4 bpm / 500 psi. 19:30 - 00:00 4.50 RUNCOMP RUNCMP Continue RIH from joint # 44 to joint # 144. Centrilift rep checked conductivity of ESP cable. Fill tubing and flush ESP pump with 10 bls seawater at 1 -1/4 bpm / 920 psi. 2/9/2009 00:00 - 06:00 6.00 RUNCOMP RUNCMP Continue RIH with new ESP Assembly on 2 -7/8 ", 6.5 #, L -80, EUE 8rd Tubing from the Pipe Shed. Maintaining continuous hole fill with seawater with average loss rate of 5 bbls / hour. RIH from joint # 144 to joint # 235 at 06:00 hours. 06:00 - 06:30 0.50 RUNCOMP RUNCMP Pre -tour checks and service the Rig. Fill and flush the pump with 10 bbls of seawater at 1 bpm / 700 psi. 06:30 - 11:00 4.50 RUNCOMP RUNCMP Perform reel to reel splice with Centrilift rep. Clear and clean Rig Floor. Hold weekly safety meeting with crew while Centrilift rep finishes the splice. 11:00 - 15:00 4.00 RUNCOMP RUNCMP Continue RIH with new ESP Assembly on 2 -7/8" Tubing from the Pipe Shed. Stop with 277 Joints in the hole due to portable gen set on the Spooling Unit failing. 15:00 - 18:30 3.50 RUNCOIVN RUNCMP Milne Point mechanic diagnoses problem with Spooling Unit. Apparently they had removed the "winter" doors to the portable gen set due to overheating issues and due to ambien temperatures of -44 degF, it froze up. Put heat on it and let it thaw out. Check all fluids to ensure good to go. 18:30 - 00:00 5.50 RUNCOMP RUNCMP Continue RIH with new ESP Assembly on 2 -7/8 ", 6.5 #, L -80, EUE 8rd Tubing from the Pipe Shed. Maintaining continuous hole fill with seawater with average loss rate of 5 bbls / hour. Printed: 3/4/2009 2:32:36 PM • BP EXPLORATION Page 4 of 4 Operations Summary Report Legal Well Name: MPC -43 Common Well Name: MPC -43 Spud Date: 3/19/2004 Event Name: WORKOVER Start: 2/3/2009 End: 2/10/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 2/10/2009 Rig Name: NABORS 3S Rig Number: N3S Date From - To Hours Task Code NPT Phase Description of Operations 2/9/2009 18:30 - 00:00 5.50 RUNCOMP RUNCMP Fill and flush the pump with 10 bbls of seawater at 1 bpm / 750 psi. RIH from joint # 277 to joint # 387 at 00:00 hours. 2/10/2009 00:00 - 01:00 1.00 RUNCOMP RUNCMP Continue RIH with new ESP Assembly on 2 -7/8 ", 6.5 #, L -80, EUE 8rd Tubing from the Pipe Shed. Maintaining continuous hole fill with seawater with average loss rate of 5 bbls / hour. RIH from joint # 387 to joint # 401. Ran total of 401 joints, XN with 2.250" ID, 1" KBMM GLM w / dummy, 1" KBMM w / DSOV. Ran 2 steel Bands for tech wire, 6 protectolizers, 3 Flat Guards, and 208 Lasalle Clamps. • 01:00 - 01:30 0.50 RUNCOMP RUNCMP Fill and flush the pump with 10 bbls of seawater at 1 bpm / 750 psi. 01:30 - 02:00 0.50 RUNCOMP RUNCMP MU landing joint with TIW valve to Hanger, FMC well head tech install penetrator and shipping cap. 02:00 - 04:00 2.00 RUNCOMP RUNCMP Centrilift Rep perform penetrator splice. 04:00 - 05:00 1.00 RNTBHG P TUBHGR Land Tubing hander, RILDS with FMC well head tech, LD landing joint. PUW = 77 K, SOW = 40 K. 05:00 - 06:30 1.50 WHSUR P RUNCMP Set and test 2 -1/2" ape "H1TWC to 3500 from, aboygf r 10 charted minutes. Line up down the IA and test from hRIow by injecting 'W 3 bpm / 900 -1,100 psi for 10 mins - good, 06:30 - 08:30 2.00 WHSUR P RUNCMP Blow down and rig down test equipment. Drain the Stack. 08:30 - 13:30 5.00 BOPSUF P RUNCMP ND BOPE and DSA. Lay Stack over in the Cradle. 13:30 - 17:00 3.50 WHSUR P RUNCMP NU Adapter Flange and 2- 9/16" Tree with FMC rep. Obtain final ESP Conductivity readings with Centrilift rep: phase to phase = 4.4. ohms , phase to ground = 1 Gigaohm , pressure at intake = 2804 psi , discharge pressure = 2774 psi , temperature at intake = 151 degF , temperature at motor = 151 degF. 17:00 - 18:30 1.50 WHSUR P RUNCMP Pressure test Hanger void to 5,000 psi for 30 mins with FMC rep. Fill Tree with diesel and test to 5,000 psi and check for visual leaks - good test. Drain the Tree. Remove double annulus valve from IA. 18:30 - 19:30 1.00 WHSUR N WAIT RUNCMP Wait on Well Support Techs to arrive due to power outage on MPL and MPF Pads. 19:30 - 21:00 1.50 WHSUR P RUNCMP PJSM with rig crew and well support tech. PU lubricator and stab on tree. P/T lubricator to 500 psi with diesel. Pull TWC. Tubing and IA on vac. Set BPV with lubricator. Secure cellar. Release rig at 21:00 hrs on 2- 10 -09. Printed: 3/4/2009 2:32:36 PM Tree; 2- 9/16" - 5M FMC M p U C-43 L1-01 Wellhead' 11" x 11" 5M F " Gen 5, w 2 -7/8" FMC Tbg. Hgr., 2 -7/8" EUE Top & Btm, 2.5" CIW BPV Profile $ Orig. DF Elev. = 51.10' (Doyon 14) Orig.GL Elev. = 16.40' (Doyon 14) • 20" 91.1# ppf, H -40 BTC 112' / Camco 2 -7/8 "x 1' KBMM 139' % - / 10 3/4 ", 45.5 ppf, L -80 Btrc. 9,363' / 0 1 0 / Camco 2 -7 /8 "x 1' KBMM 12,483' / % . xN 1 XN Nipple (2.813 packing ID) 12,625' 2 -7/8" 6.5 #, L -80, EUE 8rd / 1 I (2.75 no -go ID) 2.441" = Drift ID Cap = .0058 ! WeIlLift Discharge Gauge Unit 12,638' / Centrilift Tandem ESP 7 -5/8" 29.7 ppf, L -80, Btc -mod % 68 -G31 SXD MVP 12,644' ( drift ID = 6.875 ", cap. = 0.0459 bpf) 0 — 66-P31 SXD _ Gas Separator GRSFTX AR 12,673' 4.5" 12.6 #/ft , IBT , mod. / ( drift id = 3.958" , cap = .0152 bpf) 0 Tandem Seal Assembly 12,678' ti Centrilift KMH Motor 12,692' 228 HP, 2305 v / 60 amp 1-----? WeIILift MGU Sensor 12,711' Baker Tie back sly. 1 12,735' Baker 7 -5 /8 "x 5 -1/2" "ZXP" liner pkr. 12,746' 7 - 5/8 ", 29.7# L - 80 btc shoe 12,883' 4 CTD Window - 13460 - 13480 Perforation Summary / 2 -7/8" L -80 Slotted Liner 13482 - 15123 Ref log: Tied Jewelry log into MWD 4/07/04 _ , _ Size SPF Interval (TVD) a 3 -3/8" 12 13,566' - 13,576' 7,297' - 7,307' I 3 -3/8" 12 13,580' - 13,600' 7,311' - 7,331' 2 -7/8" 6 13,619' - 13,628' 7,350' - 7,359' 2 - 7/8" SIot/Perf Liner 13696 - 15501 PF -3412 HMX Charges / 12spf 3.3/8" / .69" hole . O� = ' 2 HES RTTS slip segments • 4.5" Landing collar (PBTD) 13,727' 4.5" 12.6 #, L -80 float shoe 13,815' DATE REV. BY COMMENTS 04/09/04 MDO Drilled and completed Doyon 14 MILNE POINT UNIT n4/26/n4 nnnn Arid fray pPrfs WELL C-43L1 & L1 -01 05/25/05 MDO Converted to ESP Nabors 4 -es API NO: 50- 029 - 23200 -00 01/14/09 Nordic 2 CTD Laterals 2/10/09 REH Re- complete w/ ESP - Nabors 3S BP EXPLORATION (AK) ~ STATE OF ALASKA 11/14/07 OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: ;iii _r~;~~.~>~,~s#~_~.~z_~} i~i2~:.%3n~i:r _~E'~3~ii ~;3cj.~ ~S ~~cEic?S~ci.i~tlif Contractor: Nabors Rig No.: 3S DATE: 2/5/2009 Rig Rep.: G. Sweatt/J. Fritts Rig Phone: 659-4487 Rig Fax: 659-4486 Operator: Bp Op. Phone: 659-4485 Op. Fax: 659-4628 Rep.: W. Hoffman/D. Rhodes Field/Unit & Well No.: MP C- 43 PTD # 2040390 Operation: Drlg: Workover: x Explor.: Test: Initial: x Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 TEST DATA MISC. INSPECTIONS: FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly 0 NA Housekeeping: P Drl. Rig P Lower Kelly 0 NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP 1 P BOP STACK: Quantity Size Test Result CHOKE MANIFO LD: Annular Preventer 1 13 5/8 5000 P Quantity Test Result Pipe Rams 1 2 7/8 X 5 P No. Valves 13 P Lower Pipe Rams 0 NA Manual Chokes 1 P Blind Rams 1 Blind P Hydraulic Chokes 1 P Choke Ln. Valves 1 3 1/8" 5000 P HCR Valves 2 3 1/8" 5000 P ACCUMULATOR SYSTEM: ', Kill Line Valves 1 2 1/16" 5000 P Time/Pressure Test Result Check Valve 0 NA System Pressure 3050 P Pressure After Closure 1700 P MUD SYSTEM: Visual Test Alarm Test 200 psi Attained 32sec P Trip Tank P P Full Pressure Attained 2 min 45 sec P Pit Level Indicators P P Blind Switch Covers: All stations P Flow Indicator P P Nitgn. Bottles (avg): 1650 psi Meth Gas Detector P P H2S Gas Detector P P Test Results Number of Failures: 0 Test Time: 5 Hours Components tested ALL Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Superviser at: 'ir::.~ eg ~al~sx:~, cif Remarks: Tested against 2 way check, tested w/2 7/8" and 4 1 /2" test its /tested 24 HOUR NOTICE GIVEN YES X NO Waived By Date 02/03/09 Time 0600 hrs Witness B.Noble,J.Fritts,D.Rhode Test start 1900hrs Finish 2400hrs BOP Test (for rigs) BFL 11/14/07 ~~~~~~ ~~~ ~ ~ 2~~~ Nabors 3s BOP Test MP C-43 2-5-2009.x1s • ~ ,~,... MICROFILMED 03/01 /2008 DO NOT PLACE ,,'' ` ~~ ~1. 'K`, Y. ANY NEW MATERIAL UNDER THIS PAGE F:1LaserFiche\CvrPgs_InsertslMicrofilm Marker.doc RE: FW: MPL-06 (PTD #1900100) and MPC-43 (PTD #2040390)... . . Tom, The lAP on C-43 runs 240 - 340 psi and the lAP on L-06 runs 300 - 400 psi. Please let me know if you need anything else. Thanks, 5CANNEMAY 0'72007 JRC From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Thursday, May 03, 2007 10:56 AM To: MPU, Well Operations Supervisor Subject: Re: FW: MPL-06 (PTD #1900100) and MPC-43 (PTD #2040390) ESP Completion with lAP> 2000 psi. Thanks John. What is the annulus pressure normally when everything is operating? Tom MPU, Well Operations Supervisor wrote, On 5/3/2007 10:28 AM: Hi Tom, Just an FYI, we did get the compressor back on line at Milne Point. As a result the MPL-06 and MPC-43 are back on line and the IA pressures are back down to below 2000 psi. If you have any questions, please don't hesisitate to let me know. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Friday, April 06, 20078:24 AM To: MPU, Well Operations Supervisor Subject: Re: MPL-06 (PTD #1900100) ESP Completion with lAP> 2000 psi. John, It is up to you all how to manage the pressure. In this case the cause of the pressure is known, it is being observed and continued build up is the result of direct communication with the reservoir and 10f3 5/3/20072:45 PM RE: FW: MPL-06 (PTD #1900100) and MPC-43 (PTD #2040390)... . . no production. This is a much different case than managing pressure in an annulus due to a communication problem or well start up. I looked at the Sustained Casing Pressure Order (CO 496) for Milne. It appears that the "action pressures" for an IA are 2000 psi or 45% of burst. You have notified me ofthe pressure at or over 2000 psi. It would seem that based on the pressure build up examination that the SICP would likely remain below the 45% threshold. If the 7" casing is 26#, NIL-80 with 7240 published burst, 45% would be 3258 psi. If it 7" 29#, N/L-80 45% is 3672 psi. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 4/6/20077:57 AM: Hi Tom, Please see the attached. It does appear that the well could build-up to >2500 psi. if the pressure buildup doesn't begin to stabilize. If the surface pressure does exceed 2500 psi., our plan is to bullhead dead crude down the IA to knock down the pressure until we can bring the well back on line. Please let me know if you have any questions or if you would like to discuss in further detail. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907 -670-3330 From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, April 04, 2007 1:12 PM To: MPU, Well Operations Supervisor Subject: Re: MPL-06 (PTD #1900100) ESP Completion with lAP> 2000 psi. Hi John, I did get your message and got your call. Looking at the buildup, has anyone projected how high the pressure could build with another month SI? I look forward to your reply. Tom Maunder, PE AOGCC MPU, Well Operations Supervisor wrote, On 3/31/2007 12:02 PM: Hi Tom, MPL-06 is a packerless, high GOR ESP completion that was shut-in on 3/12/07 due to reduced gas handling capacity at our Milne Point processing facility. Our reduced gas handling capacity is due to maintenance work on one of our large gas injection compressors. Due to the wells high GOR, when the well is SI for an extended period of time gas pressure on the IA builds due to 20f3 5/3/20072:45 PM RE: FW: MPL-06 (PTD #1900100) and MPC-43 (PTD #2040390)... . . gas breakout on top of the fluid in the IA. Once we bring the well back on-line, the IA pressure will relieve through the orifice in the tubing. Current pressure on the IA is 2020 psi. Our plan is to have our compressor back on line in early May 2007. During the interm, we request permission to continue to monitor the IA pressure and to not pump a kill fluid into the IA unless the pressure increases to over 2500 psi. Please let me know if you have any questions or if you would like to discuss in further detail. Thanks, John R. Cubbon MPU Well Operations Supervisor 1-907-670-3330 «MPL-06.ZIP» «MPL-06 TIO.ZIP» 3 of3 5/3/20072:45 PM MPC-43 (PTD #2040390) Classified as Problem Well Due to high lAP . All, Well MPC-43 (PTD #2040390) has an ESP completion and has been found to have sustained casing pressure on the IA. The TIO pressures on 04/15/07 were SSV/2000/0. The well is thought to be at the end of a WAG cycle and the pressures should stabilize at -2000 psi. The plan forward for this well is as follows: 1. Operations: Monitor WHPs 2. Operations: If IA builds to 2500 psi, load the IA to knock down pressure 3. Operations: Put the well back on production once the gas compressor is back up A well bore schematic has been included for reference. «MPC-43.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, )fnna (])u6e, œ. P.. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 ~tHNED APR 3 0 2007 Content-Description: MPC-43.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 4/17/200712:37 PM · 20" 91.1# ppf, H-40 BTC ~ 103/4",45.5 ppf, L-80 Btrc. KOP @ 300' Max. hole angle = 69 deg. Hole angle thru' perfs = 7 deg. 7-5/8" 29.7 ppf, L-80, Btc-mod ( drift ID = 6.875", cap. = 0.0459 bpf) 4.5" 12.6 #/ft, IBT , mod. ( drift id = 3.958" , cap = 0.0125 bpf) Baker Tie back slv. 112,735' I Baker 7-5/8"x 5-1/2" "ZXP" liner pkr·112,746' I 7-5/8",29.7# L-80 btc shoe 112,883" Perforation Summary Ref log: Tied Jewelry log into MWD 4/07/04 Size SPF Interval (TVD) 3-3/8" 12 13,566' - 13,576' 7,291' - 7,301' 3-3/8" 12 13,580' - 13,600' 7,311' - 7,331' PF-3412 HMX Charges I 12spf3.3/8" 1.69" hole DATE 04/09/04 04/26/04 OS/25/05 REV. BY MPU C-43 MDO MDO MDO COMMENTS Drilled and completed Doyon 14 Add frac perfs Converted to ESP Nabors 4-es Orig. D.. = 51.10' (Doyon 14) Orig.GL.: . = 16.40' (Doyon 14) 4.5" Landing collar (PBTD) 4.5" 12.6#, L-80 float shoe 13,727' 13,815' MILNE POINT UNIT WELL C-43 API NO: 50-029-23200-00 · STATE OF ALASKA ALASWOIL AND GAS CONSERVATION COMM.N REPORT OF SUNDRY WELL OPERATIONS D D D ,. 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development P Stratigraphic P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 51.1 KB 8. Property Designation: ADLO-355017 ' 11. Present Well Condition Summary: Total Depth measured 13817 . feet true vertical 7547.24 . feet Effective Depth measured 13700 feet true vertical 7131 feet Casing Length Size MD Conductor 78' 20" 94# H-40 34' - 112' Surface 9328' 10-3/4" 45.5# L-80 35' - 9363' Production 12850' 7-5/8" 29.7# 1-80 33' - 12883' Liner 1080' 4-1/2" 12.6# L-80 12735' - 13815" Perforation depth: Measured depth: 13566 - 13576 True Vertical depth: 7297.75 - 7307.66 13580 - 13600 7311.63 - 7331.47 Tubing: (size, grade, and measured depth) 4-1/2" 12.6# Packers and SSSV (type and measured depth) RECf.: o Stimulate 0 . Other WaiverD Time~ãi<m[j Gas Cons C. " Re-enter Suspended Well 0 . . OOlm!$sl 5. Permit to Drill Number: 204-0390 Exploratory Service 6. API Number: 50-029-23200-00-00 . 9. Well Name and Number: MPC-43 10. Field/Pool(s): MILNE POINT Field/ KUPARUK RIVER OIL Pool Plugs (measured) None Junk (measured) None TVD 34' - 112' 35' - 4736' 33' - 6641' 6503' - 7545' Collapse 470 2480 4790 7500 Burst 1490 5210 6890 8430 C;) /r 13619 - 13628 7350.34 - 7359.28 L-80 32' - 12754' 7-5/8"X5-1/2" ZXP LINER PKR o o o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 120 710 0 121 722 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil P" -Gas WAG 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 X Oil-Bbl 424 422 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble 12746' o o o RBDMS BH ø s 2006 Tubing pressure 200 200 . Service WINJ WDSPL Title Data Engineer Signature Submit Original Only /rll?/45 A1> ~?~ Date 10/27/2006 k~~ .# . . I , MPC-43 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/24/2006;T/I/O=350/220/300 Acid treatment - Pump 5 bbls crude, 10 bbls 12% DAD acid, 3 bbls neet (for flushing lines), 67 bbls ¡crude down tbg. I ***Continued on next day WSR**** ¡ nn-'_'_" ~~W~_A_A_A_A_ ,·v,",_"'_nwn_'_'_'_'_'_'_~A_~^_mmn ·'_·,__·Ü'^~,WNNNNNNNNN~_NA_'_'_'_ 10/25/2006 T/I/O=350/220/300 ****Acid treat. continued from previous dayWSR**** Finish pumping 67 bbls crude displacement. FLUIDS PUMPED BBLS 72 CRUDE 3 NEET 10 12% DAD ACID 85 total . . 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: 1E-104, CD3-302 PB1, 05-20B, 15-46 L1 PB1, MPK-09, MPE-31, MPC-43, MPE-25A. lE-104 'J04... g,;;>':) 1~~6<J CD3-302PB18ö(o-olo IloIlO/ 05-20B v 801.../-;134 '404~ 15-46 Ll PBl QoL(-ID3 ¡"-lIvO MPK-09 gö~- 0/«( li.IIO~ MPE-31 do5"" - Ot-d./'"-/I 03 MPC-43 804- 030¡ t~ 10;) MPE-25A V'1:C- Gol..( - 045" ';).6"15£{ Digital LIS DATA: SCANNED AUG 3 1 2006 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. })LEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: 15j;~D/ík> Signed: d¿L ~~ ~ .~~ DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 '> f i.L¿ l C{ MWI. N1N) Y API No. 50-029-23200-00-00 Permit to Drill 2040390 Well Name/No. MILNE PT UNIT KR C-43 Operator BP EXPLORATION (ALASKA) INC MD 13817 Completion Date 4/26/2004 Completion Status 1-01L UIC N Current Status 1-01L TVD 7547 REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes - DATA INFORMATION Types Electric or Other Logs Run: MWD, GYRO, RES, PWD, DIR, GR, IFRlCASANDRA Well Log Information: (data taken from Logs Portion of Master Well Data Maint Log/ Electr Data Digital Dataset Log Log Run Interval OHI Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments úÓ ~- D Asc Directional Survey 4/23/2004 IIFR t Directional Survey 0 0 4/23/2004 IIFR Asc Directional Survey 0 0 4/23/2004 MWD Directional Survey 0 0 4/23/2004 MWD Lis 12578 Formation Tester 2055 5607 Open 6/9/2004 MWD, FORMATION EVALUATION LOG ~~ LIS Verification 2055 5607 Open 6/9/2004 MWD, DSN 21578 Lis 13532 I nductionlResistivity 112 13817 Open 2/22/2006 ROP DGR EWR Plus Graphics Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMn\[ION Well Cored? y\ri) ~ Daily History Received? Chips Received? ~ Analysis '><cŒr:. Received? Formation Tops ~ Comments: . . Permit to Drill 2040390 MD 13817 TVD Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 4/24/2006 Well Name/No. MILNE PT UNIT KR C-43 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23200-00-00 7547 ~Ietion Date 4/26/2004 Current Status 1-RIL l Jl! Ii. . UIC N Date: ~../. 7 ~ Þ Completion Status 1-01L . . ·1 . v WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16,2006 /31:J3'd- RE: MWD Formation Evaluation Logs MPC-43, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 MPC-43 : LAS Data & Digital Log Images: 50-029-23200-00 ¿t!4- 'D:11 1 CD Rom {\~\f\.rf t\ lì h U ~ no"1- ~~9-to~ STATE OF ALASKA _ ALASKAa AND GAS CONSERVATION C~ISSION REPORT OF SUNDRY WELL OPERATIONSs 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 8. Property Designation: ADL 355017 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): o Suspend o Repair Well øa Pull Tubing KBE = 51.10' 13817 7547 13700 7131 Length 78' 9328' 12850' 1080' Change Out ESP o Operation Shutdown o Plug Perforations o Perforate New Pool øa Perforate o Stimulate o Waiver øa Other o Re-Enter Suspended Well o Time Extension 4. Current Well Class: øa Development 0 Exploratory o Stratigraphic 0 Service 5. Permit To Drill Number: 204-039 6. API Number: 50-029-23200-00-00 99519-6612 9. Well Name and Number: MPC-43 10. Field I Pool(s): Milne Point Unit / Kuparuk River Sands feet feet Plugs (measured) NIA feet Junk (measured) NIA feet Size MD TVD Burst 20" 112' 112' 1490 10-3/4" 9363' 4736' 5210 7-5/8" 12883' 6641' 6890 4-1/2" 12735' - 13815' 6503' - 13815' 8430 Collapse 470 2480 4790 7500 13566' - 13628' 7298' - 7359' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 2-7/8", 6.5# L-80 12707' Treatment description including volumes used and final pressure: IRBDMS BFL SEP .1 9 2005 13. Prior to well operation: Subsequent to operation: 14. Attachments: Oil-Bbl 331 312 Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casina Pressure 500 457 408 408 484 Tubina Pressure 357 640 15. Well Class after proposed work: o Exploratory øa Development 0 Service 16. Well Status after proposed work: øa Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 o Copies of Logs and Surveys run øa Daily Report of Well Operations øa Well Schematic Diagram Printed Name Sondra Stewman Si ur Form 10-404 Revised 04/2004 Title Technical Assistant Phone t~ Prepared By Name/Number: Date LT t,;14-Ds'sondra Stewman, 564-4750 Submit Original Only 564-4750 u Ii L .Iœ.e;. 2-9/16" - 5M FM_ Wellhead: 11" x 11" 5 Gen 5, W 2-7/8" FMC TI:5. gr., UPTBG Top & Btm, 2.5" CIW BPV Profile 20" 91.1 # ppf, H-40 BTC @J 103/4",45.5 ppf, L-80 Btrc. ~ KOP @ 300' Max. hole angle = 69 deg. Hole angle thru' perfs = 7 deg. 2-7/8" 6.5 ppf, L-80 8rd eue tbg. ( drift id = 2.347" cap = .00592 bpf) 7-5/8" 29.7 ppf, L-80, Btc-mod ( drift ID = 6.875", cap. = 0.0459 bpf) 4.5" 12.6 #/ft, IBT , mod. ( drift id = 3.958" , cap = 0.0125 bpf) Baker Tie back slv. 112,735' I Baker 7-5/8"x 5-1/2" "ZXP" liner Pkr·112,746' II 7-5/8",29.7# L-80 btc shoe 112,883' .,.. Perforation Summary Ref log: Tied Jewelry log into MWD 4/07/04 Size SPF Interval (TVD) 3-318" 12 13,566' - 13,576' 7,297' - 7,307' 3-3/8" 12 13,580' - 13,600' 7,311' -7,331' 2-7/8" 6 13,619' - 13,628' 7,350' - 7,359' PF-3412 HMX Charges 1 12spf 3.3/8" 1.69" hole DATE REV. BY MPU C-43 ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ,I ~ ,I ,I ~ ,. .. , , , " .. ~ .. 04/09/04 04/26/04 05/25/05 MDO MDO MDO COMMENTS Drilled and completed Doyon 14 Add frac perfs Converted to ESP Nabors 4-es Orig. DFie. = 51.10' (Doyon 14) Orig.GL v. = 16.40' (Doyon 14) Cameo 2-7/8"x l' KBMG M-2 Camc02-7/8"x l' KBMG M-2 XN Nipple (2.813 packing 10) (2.75 no-go 10) 139' 12,482' I 12,635' I Centrilift 109/GC 1700 ESP, 12,648' 1 19/GC 8200 series 513, GPMTAR1:1 Tandem I 12,669' I Gas Separator GRSFTX AR H6 Tandem Seal Assembly GSB3DBUT AB/HSN PFSAiFSA CL5 Centrilift KMH Motor 152 HP, 2325 v /40 amp Pumpmate Sensor w/ fins I II. ï ;I ;I ;I ;I '- 4.5" Landing collar (PBTD) 4.5" 12.6#, L-80 float shoe I 12,674' I I 12,687' I 112,701' I 13,727' I 13,815' I MILNE POINT UNIT WELL C-43 API NO: 50-029-23200-00 RP FXPI ORATION (AK) legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 WORKOVER NABORS ALASKA DRilLING I NABORS 4ES Start: 8/18/2005 Rig Release: 8/25/2005 Rig Number: 4ES Spud Date: 3/19/2004 End: 8/25/2005 8/18/2005 18:00 - 21 :00 3.00 RIGU P DECOMP RID equip. Scope down & lower derrick. 21 :00 - 00:00 3.00 RIGU P DECOMP Begin moving from MPJ-18 to MPC"43. 6 mile move. 8/19/2005 00:00 - 02:00 2.00 RIGU P DECOMP Con't to move from MPJ-18 to MPC-43. Total distance 6 miles. Layout Herculite & matting boards. 02:00 - 04:00 2.00 RIGU P DECOMP Spot rig, pits & pipe shed over well. RlU. Raise & scope up derrick. spot in tiger tank. 04:00 - 05:30 1.50 RIGU P DECOMP ACCEPTED RIG 0400 hrs. Con't to R/U. Take on hot seawater in pits. M/U lines to tree & tiger tank. 05:30 - 06:30 1.00 RIGU P DECOMP P/U lubricator & pull BPV. UD lubricator. 06:30 - 07:30 1.00 RIGU P DECOMP Test lines to 3500 psi. Hold PJSM & Pre-Spud meeting wI all hands. 07:30 - 11 :30 4.00 KILL P DECOMP Open well SITP = 40 psi, SICP 540 psi. Circulate well 4 BPM @ 400 psi. Took 88 bbls to catch fluid. Pumped total of 588 bbls. SID & Monitor well, Well Dead. 11 :30 - 12:00 0.50 WHSUR P DECOMP Install TWC. Test same to 3500 psi. Blow down & RID lines. 12:00 - 13:00 1.00 WHSUR P DECOMP NID tree & adapter flange. 13:00 - 15:00 2.00 BOPSUP P DECOMP N/U BOPE. 15:00 - 19:30 4.50 BOPSUP P DECOMP Test BOPE as per BP/AOGCC requirements. LP 250 psi. HP 3500 psi. Test witnessing waived by John Crisp wI AOGCC. 19:30 - 20:30 1.00 BOPSUP P DECOMP R/U lubricator & extension. Pull TWC. RID lubricator and LD same. 20:30 - 22:00 1.50 PULL P DECOMP Make up landing joint. BOLDS. Pull Tubing Hanger. Work Tubing to 80% of yield (230K). packer failed to release. Land Tubing Hanger. RILDS. Lay down landing joint. 22:00 - 23:30 1.50 PULL P DECOMP NID flow nipple. Nipple up shooting flange. 23:30 - 00:00 0.50 PULL P DECOMP Clear and clean rig floor. Wait on SWS arrival. 8/20/2005 00:00 - 03:00 3.00 PULL P DECOMP R/U SWS E-line equipment. P/U lubricator. PIT to 500 psi. 03:00 - 06:00 3.00 PULL P DECOMP RIH wlstring shot to 12,684 and shoot same. POOH w/wireline. 06:00 - 09:30 3.50 PULL P DECOMP Hold PJSM. M/U chemical cutter assy. RIH & correlate depth & tie-in. Fire cutter & cut tubing @ 12688'. Good indication on surface. POOH & inspect cutting assy. All indications of good cut. UD tools & RID E-line. 09:30 - 1 0:00 0.50 PULL P DECOMP NID shooting flange & N/U flow nipple. 10:00 - 10:30 0.50 PULL P DECOMP M/U landing jt into hanger. BOLDS. 10:30 - 11 :00 0.50 PULL P DECOMP Pull hanger to floor. Tubing came free wI 148K. UD landing jt & hanger. 11:00 - 12:30 1.50 PULL P DECOMP Circulate bottoms up. Had some gas to surface. 5 BPM @ 3500 psi. 12:30 - 00:00 11.50 PULL P DECOMP POOH & UD 41/2" completion. Recovered:260 jts. 4 1/2" 12.6# L80 TTC-II tubing & 5 GLM Assys. 8/21/2005 00:00 - 01 :30 1.50 PULL P DECOMP POOH & UD 41/2" completion. Total recovery as follows: 300 jts 41/2" 12.6#, L-80, IBT tubing, 5 GLM Assys, 1 - Sliding Sleeve Assy. 1 Cut off tubing pup 3' long. Had good clean cut on tubing pup. Top of stub @ 12688'. 01 :30 - 03:00 1.50 PULL P DECOMP Clear & clean rig floor. RID tubing handling equip. R/U DP handling tools. 03:00 - 04:30 1.50 PULL P DECOMP Load, tally & M/U BHA #1 as follows: CIL Guide, 57/8" Overshot, Ext, Top Sub, Bumper Sub, Jars, 9*43/4" DCs, Ace. Jar. TL = 315.09'. 04:30 - 06:00 1.50 PULL P DECOMP P/U 3 1/2" DP, 1x1 & RIH wI BHA #1. 06:00 - 06:30 0.50 PULL P DECOMP Service rig. 06:30 - 15:30 9.00 PULL P DECOMP P/U 3 1/2" DP, 1x1 & RIH wI BHA #1. P/U 298 jts. (12660') Printed: 8/26/2005 11 :36: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/18/2005 Rig Release: 8/25/2005 Rig Number: 4ES Spud Date: 3/19/2004 End: 8/25/2005 8/21/2005 15:30 - 22:00 6.50 PULL P DECOMP POOH w/3 1/2 DP & BHA #1. POOH to Change out BHA# 1. 22:00 - 00:00 2.00 PULL P DECOMP P/U BHA #2 & RIH w/3 1/2" DP. Remove pack off in overshot & P/U pump out sub. 8/22/2005 00:00 - 05:00 5.00 PULL P DECOMP P/U BHA #2 & RIH w/3 1/2" DP. 05:00 - 05:30 0.50 PULL P DECOMP Engage top of fish with overshot at 12,688'. P/U Wt = 148K, S/O 75K. Rot Wt = 100K. P/U to 245K. Packer came free & weight dropped to 175K. P/U 26' & allow rubbers to relax. 05:30 - 08:30 3.00 PULL P DECOMP Circulate bottoms up. 4 BPM @ 870 psi. Pumped 615 bbls. Lost 110 bbls. 08:30 - 11 :00 2.50 PULL P DECOMP POOH wI Overshot & fish. Initially pulling 25-35k over. Fluid level dropping. 11 :00 - 12:00 1.00 PULL P DECOMP Shut down operations for a Milne Point Code 99 @ F-Pad. 12:00 - 03:30 15.50 PULL P DECOMP Con't to POOH WI DP & fish. Stand back 114 stands. 03:30 - 06:00 2.50 PULL P DECOMP Stand back 4 3/4" DCs. Break out fish from Overshot. Had to punch tubing. String filled wI Heavy, gassy thick hydocarbons & water. Had difficulty breaking out tailpipe due to Baker-Lok connections. Recovery as follows: 6' Cut tubing pup, "X" Nipple assy, Baker premier Packer Assy, "XN" Nipple Assy & WLEG Assy. 100% completion recovery. 06:00 - 07:30 1.50 PULL P DECOMP Clear and clean rig floor. 07:30 - 00:00 16.50 CLEAN P DECOMP P/U cleanout BHA and RIH w/muleshoe, 32 jts. 27/8" PAC DP, jars, 9 x 4 3/4 DC, and 3 1/2" DP. 8/23/2005 00:00 - 03:00 3.00 CLEAN P DECOMP P/U cleanout BHA and RIH wlmuleshoe, 32 jts. 27/8" PAC DP, jars, 9 x 4 3/4 DC, and 288 jts. 31/2" DP. Tagged top of fill at 13,592'. Fluid level at 4800 ffs. 03:00 - 06:00 3.00 CLEAN P DECOMP Fill hole. Break circulation at 4.0 bpm at 1000 psi. Switch to reverse circulation. Reverse circulate hole at 4.0 bpm at 700 psi. Fluid loss = - 1.0 bpm. Cleanout fill to 13,705' 4ES KB. 06:00 - 08:00 2.00 CLEAN P DECOMP Reverse circulate hole clean. Pumped 5112 BPM @ 900 psi. Spot 40 bbls E-P Mud Lube pill. 08:00 - 09:00 1.00 CLEAN P DECOMP POOH & UD 45 jts of 31/2" DP. 09:00 - 10:00 1.00 CLEAN P DECOMP Hold PJSM. Cut & slip 84' of drilling line. 10:00 - 16:30 6.50 CLEAN P DECOMP Con't to POOH & UD 3 1/2" DP. Laid down total of 398 jts. 16:30 - 18:00 1.50 CLEAN P DECOMP UD BHA #3. 9 * 4 3/4" DCs, 32 jts 2 7/8" PAC, Jars, Bumper Sub, Pump Out Sub, XO, & Muleshoe. 18:00 - 19:00 1.00 CLEAN P DECOMP Pull Wear bushing. NID flow nipple & NIU shooting nipple. 19:00 - 23:00 4.00 PERFUB P OTHCMP R/U SWS E-line unit. P/U lubricator. PfT to 500 psi. P/U 9' x 27/8" PJ perf. gun with shooting bridal and loaded for 6 SPF. Total shots - 55. 23:00 - 00:00 1.00 PERFUB P OTHCMP RIH w/9' x 2 7/8" PJ perf. gun, weight bar and 3.5' of 2.5" roller stem w/3.5" rollers. 8/24/2005 00:00 - 01 :00 1.00 PERFUB P OTHCMP RIH w/9' x 2 7/8" PJ perf. gun with shooting bridal and loaded for 6 SPF. Total shots - 55. Correlate depth to Sperry Sun MWD log dated 07 April 2004. Shoot gun with top shot at 13,619'. SIWHP before shoot gun - 0 psi. 01 :00 - 01 :30 0.50 PERFUB P OTHCMP Monitor SIWHP for 30 minutes. SIWHP after 30 minutes - 0 psi. 01 :30 - 03:30 2.00 PERFUB P OTHCMP POOH wltool string and perf. gun. All shots fired. UD tool string and perf gun. UD lubricator. Lost roller stem in hole. Roller stem body O.D. = 2.50". Fishing neck = 1.4375" 0.0. Total length = 3.50 ft. 03:30 - 06:00 2.50 RUNCOMP RUNCMP NID shooting flange. N/U flow nipple. Clear and clean rig floor. Prep to run 2 7/8" tubing and ESP completion. Printed: 8/26/2005 11 :36: 11 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 8/18/2005 Rig Release: 8/25/2005 Rig Number: 4ES Spud Date: 3/19/2004 End: 8/25/2005 8/24/2005 06:00 - 07:30 1.50 RUNCOMP RUNCMP Spot in spooling unit. Load pump & motor into pipe shed & break out of shipping containers. R/U handling tools for running 27/8" ESP completion. 07:30 - 1 0:30 3.00 RUNCOMP RUNCMP M/U pump & motor. Service same. Pull MLE over sheave, Plug into ESP. Test & check same. 10:30 - 18:00 7.50 RUNCOMP RUNCMP P/U 2 7/8" 6.5#, L-80, EUE, 8RD tubing, 1x1 & RIHwl ESP. Test & pump thru ESP every 2000'. 1 BPM @ 400 psi. 18:00 - 19:30 1.50 RUNCOMP RUNCMP Change out reels in spooling unit. Make reel to reel splice in ESP cable. 19:30 - 00:00 4.50 RUNCOMP RUNCMP P/U 27/8" 6.5#, L-80, EUE, 8RD tubing, 1x1 & RIHwl ESP. Test & pump thru ESP every 2000'. 1 BPM @ 400 psi. 8/25/2005 00:00 - 04:30 4.50 RUNCOMP RUNCMP P/U 2 7/8" 6.5#, L-80, EUE, 8RD tubing, 1x1 & RIHwl ESP. Test & pump thru ESP every 2000'. 1 BPM @ 400 psi. Ran 201 jts. Bottom of pump @ 12707'. Used 3 Flat Guards, 3 Protectolizers & 208 LaSalle Clamps. 04:30 - 07:00 2.50 RUNCOMP RUNCMP P/U landing jt. and tubing hanger. Make up lower wellhead connector to ESP cable and megger test same. 07:00 - 08:00 1.00 RUNCOMP RUNCMP Land ESP completion @ 12707'. RILDS. 08:00 - 08:30 0.50 RUNCOMP RUNCMP Install TWC & test to 2500 Psi. 08:30 - 10:00 1.50 BOPSUF P RUNCMP N/U BOPE. 10:00 - 11 :30 1.50 WHSUR P RUNCMP Install Adapter flange & X-mas Tree. Test same to 5000 psi. Tested Good. 11 :30 - 12:00 0.50 WHSUR P RUNCMP P/U lubricator & set BPV. UD same. Secure tree & cellar. RELEASE RIG @ 1200 hrs. Printed: 8/26/2005 11 :36: 11 AM . STATE OF ALASKA e ALAS~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG , 1a. Well Status: IBI Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD , GYRO, RES, PWD , DIR , GR , IFR\CASANDRA CASING, LINER AND CEMENTING RECORD S¡;TI1NßP¡;P:THMO SËTTINßP¡;PTH1W BOTTOM "top BOTTOM 112' 34' 112' 9363' 35' 4736' 12883' 33' 6641' 13815' 6503' 7545' 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: 1344' NSL, 2290' WEL, SEC. 10, T13N, R10E, UM Top of Productive Horizon: 498' NSL, 509' WEL, SEC. 33, T14N, R10E, UM Total Depth: 525' NSL, 523' WEL, SEC. 33, T14N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 558168 y- 6029627' Zone- ASP4 TPI: x- 554577 y- 6039312 Zone- ASP4 Total Depth: x- 554562' y- 6039339 f Zone- ASP4 18. Directional Survey IBI Yes 0 No 22. 20" 10-3/4" 7-5/8" 4-1/2" 94# 45.5# 29.7# 12.6# H-40 L-80 L-80 L-80 34' 35' 33' 12735' . 23. Perforations open to Production (MD + TVD of T<æ and Bottom Interval, Size and Number; if none, state none"): 3-3/8" Gun Diameter, 12 SPF MD TVD MD TVD 13566' - 13576' 7298' - 7308' 13580' - 13600' 7312' -7331' 26. Date First Production: June 10, 2004 Date of Test Hours Tested PRODUCTION FOR 6/7/2004 6 TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Press. 24-HoUR RATE One Other 5. Date Camp., Susp., or Aband. 4-26-2004 J 6. Date Spudded 3-19-2004 7. Date T.D. Reached 4-6-2004 8. KB Elevation (ft): KBE = 51.10' /' 9. Plug Back Depth (MD+ TVD) 13700 + 7131 10. Total Depth (MD+ TVD) j 13817 + 7547 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 42" 13-1/2" 9-718" 6-3/4" SIZE 4-1/2", 12.6#, L-80 1b. Well Class: IBI Development 0 Exploratory o Stratigraphic Test 0 Service 12. Permit to Drill Number 204-039 13. API Number 50- 029-23200-00-00 14. Well Name and Number: MPC-43 15. Field / Pool(s): Milne Point Unit I Kuparuk River Sands Ft Ft 16. Property Designation: ADL 355017 17. Land Use Permit: 20. Thickness of Permafrost 1800' (Approx.) 260 sx Arctic Set (Approx.) 1023 sx Arctic Set III, 258 sx 'G' 150 sx Class 'G' 203 sx Class 'G' DEPTH SET (MD) 12745' PACKER SET (MD) 12705' DEPTH INTERVAL (MD) 13566' - 13600' AMOUNT & KIND OF MATERIAL USED Frac'd A Sand with 213500 #'s Carbolite placed 213000 #'s behind pipe. Freeze protected with 164 Bbls of Diesel 2500' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Electric Submersible Pump OIL -BSL GAs-McF 658 74 OIL-BsL GAs-McF 2632 295 W A TER-BsL 439 WATER-BsL 1755 I GAS-OIL RATIO 112 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 c~ chips; if none, state "none". (" ..... None ~JiB~If'__ßfL 1M 2 II. 11J1)~ 0 Q I G N A L IY~:~1 1,:.._ .... ,.....~___."'d Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE c,rG - e e 28. GEOLOGIC MARKERS 29. FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". TKUD 13298' 7034' None TKC1 13457' 7190' TKUB 13465' 7198' TKA6 13556' 7288' TKUA 13558' 7291' TKA4 13565' 7297' TKA3 13565' 7297' TKA2 13583' 7315' TKA1 13617' 7348' TMLV 13665' 7396' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys, Post-Rig Work Summary and a Leak-Off Test Summary. 31. I hereby certify that the foregoing is true and .correct to the best of my knowledge. Signed Sondr¿~;e~~__~,_ Title Technical Assistant DateO(O' z.1-{y.j MPC-43 204-039 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Drilling Engineer: Matt Green, 564-5581 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-Altemating-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 . '\ ~ ¡ j AL Orig. D&. = 51.10' (Doyon 14) Orig.G~~~ = 16.40' (Doyon 14) Tree:CIW41/16" 5M~' MPU C-43 Wellhead: 11" x 11" 5~C Gen 5 11" 5M x 4 1/16" 5M adapter and 11" x 4.5" tbg. hng. 4.5" TC-11 threads top and bottom and 4" CIW-H SPV profile. .. 20" 91.1# ppf, H-40 STC ~ 4.5" X 1" KBG-2 Sz MD TVD Dev. 4.5 3,291' 2,390' 68° 4.5 7,384' 3,957' 69° 4.5 9,990' 4,947' 68° 103/4",45.5 ppf, L-80 Btrc. I 9,363' ~ 4.5 11,608' 5,611' 61° 4.5 12,517' 6,302' 23° KOP @ 300' Max. hole angle = 69 deg. Hole angle thru' perfs = 7 deg. 7-5/8" 29.7 ppf, L-80, Stc-mod ( drift ID = 6.875", cap. = 0.0459 bpf ) 4.5" 12.6 #Ift ,1ST, mod. ( drift id = 3.958" , cap = 0.0125 bpf) Baker Tie back slv. 112,735' I Baker 7-518"x 5-1/2" "ZXP" liner pkr·112,746' I, 7-5/8",29.7# L-80 btc shoe 112,883' I- Perforation Summary Ref log: Tied Jewelry log into MWD 4/07/04 Size SPF Interval (TVD) 3-3/8" 12 13,566' - 13,576' 7,297' - 7,307' 3-3/8" 12 13,580' - 13,600' 7,311' - 7,331' PF-3412 HMX Charges /12spf 3.3/8"/ .69" hole DATE 04/09104 04/26/04 REV. BY 4.5' HES XD Duro Sleeve I 12,670' I 7-5/8 x 4.5" Baker Premier Pkr. 12,705' 12,731' I 12,744' I .- 4.5" HES "XN-NIPPLE( 3.813") No-Go id 3.725" II. WLEG / / / / ¡I (. ~ 4.5" Landing collar (PSTD) 4.5" 12.6#, L-80 float shoe 113,727' I 113,815' I MDO MDO COMMENTS Drilled and completed Doyon 14 Add fraç perfs MILNE POINT UNIT WELL C-43 API NO: 50-029-23200-00 -. RP FXPI ORATION lAK) Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 3/18/2004 07:00 - 11 :30 4.50 MOB P PRE Slide rig floor from drlg to move position - Move off well MPC-42 - Move and spot rig over MPC-43 - Slide floor from move position to drlg position 11 :30 - 12:30 1.00 MOB P PRE Rig up floor - Steam to rig floor - Spot rock washer and berm - Take on water in pits - (Accept rig 12:30 hrs) 12:30 - 14:30 2.00 RIGU P PRE Nipple up Diverter - Diverter line - Loading pipe shed with 5" drill pipe 14:30 - 15:30 1.00 RIGU P PRE Change out handling equipment from 4" to 5" 15:30 - 20:30 5.00 DRILL P SURF Pick up 5" drill pipe from pipe shed and stand back in derrick 20:30 - 21 :00 0.50 RIGU P PRE Function test Diverter - Prefrom Accumulator test - Check alarms for Gas, Flow, PVT - Jeff Jones WlthAOGCC witnessed the Diverter and alarm test 21 :00 - 00:00 3.00 DRILL P SURF Pick up 5" drill pipe from pipe shed and stand back in derrick 3/19/2004 00:00 - 02:00 2.00 DRILL P SURF Pick up 5" drill pipe from pipe shed - Rack back in derrick 02:00 - 02:30 0.50 DRILL P SURF Pick up HWT and Jars stand back in derrick 02:30 - 05:00 2.50 DRILL P SURF Pick up BHA to rig floor - Make up BHA - Orient same 05:00 - 05:30 0.50 DRILL P SURF Rig up Sperry Sun Gyro equipment - Pre Spud Meeting with all personnel - Fill hole - Check for surface leaks 05:30 - 06:00 0.50 DRILL P SURF Spud in Well - Drill 13.5" Surface hole from 112' to 174' 06:00 - 07:00 1.00 DRILL P SURF POH - Pick up Flex DC's - RIH - Run Gyro survey 07:00 - 00:00 17.00 DRILL P SURF Directional Drill 13.5" Surface hole from 174' to 1475' - WOB 30 - GPM 450 - PP on 1440 - off 1050 - RPM 80 - TO on 7K- off 2K - PU 95K - SO 95K - ROT 95K 3/20/2004 00:00 - 05:00 5.00 DRILL P SURF Directional Drill from 1474' to 2099' - MWD giving large Azim swings - Trip for new MWD tool 05:00 - 06:30 1.50 DRILL N DPRB SURF Pump to HWT - @ 628' - Pump at drlg rate 500 gpm 06:30 - 09:30 3.00 DRILL N DPRB SURF Stand Back HWT I Flex DC's - Down load MWD - Change out Pulser - Up load MWD - Lay down UBHO - Shallow pulse test - Good 09:30 - 11 :00 1.50 DRILL N DPRB SURF RIH to 1378' - Survey each stand from 1378' to 2032' 11 :00 - 00:00 13.00 DRILL P SURF Directional Drill from 2099' to 4290' - WOB 25K to 40K - RPM 80 - TO on 12K - off 7K - GPM 544 - PP on 2300 - off 1900- PU 120K - SO 87K - ROT 106K 3/21/2004 00:00 - 12:30 12.50 DRILL P SURF Directional Drill From 4290' to 5606' 12:30 - 14:30 2.00 DRILL P SURF CBU 2 X - 80 RPM - TO 8K - GPM 550 - PP 1900 PSI 14:30 - 20:00 5.50 DRILL P SURF Pump out to HWT - Pump at drlg rate - GPM 525 20:00 - 22:00 2.00 DRILL P SURF Stand back BHA - Change out bits - Adjust motor to 1.15 degree - Surface test MWD - 105 spm @ 650 psi - Install 12.25" straight blade string stablizer on top of HWDP 22:00 - 00:00 2.00 DRILL P SURF RIH from 632' to 5606' - Fill pipe every 25 stands 3/2212004 00:00 - 16:30 16.50 DRILL P SURF Directional Drill from 5606' to 7590' - WOB 40K - RPM 90 - TO on 15K - off 14K - GPM 550 - PP on 3050 - off 2780 - PU 175K - SO 95K - ROT 128K - (High pump pressure - 40 SPM 4000 psi) 16:30 - 19:30 3.00 DRILL N DFAL SURF Pump out of hole from 7590' to 5650' - Pump rate 70 spm - PP 1700 psi 19:30 - 22:30 3.00 DRILL N DFAL SURF POH with out pump - from 5650' to 631' @ BHA 22:30 - 00:00 1.50 DRILL N DFAL SURF Stand back BHA - Break bit - Flush motor - Bearing locked - Rotated free but rough - Lay down Sperry Sun motor 3/23/2004 00:00 - 00:30 0.50 DRILL P SURF Top Drive I Rig Service 00:30 - 01 :30 1.00 DRILL N DFAL SURF Pick up Sperry Sun motor - Set to 1.15 degree - Orient - Shallow pulse test 01 :30 - 04:00 2.50 DRILL N DFAL SURF RIH - Fill pipe every 25 stands - Precauctionary wash from Printed: 4/12/2004 11 :30:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 3/23/2004 01 :30 - 04:00 2.50 DRILL N DFAL SURF 7495' to 7590' 04:00 - 00:00 20.00 DRILL P SURF Directional Drill from 7590' to 9025' - WOB 35K to 45K - RPM 80 - TQ on 18K - off 17K - GPM 550 - PP on 2400 - off 2240- PU 200 - SO 105 - ROT 145 3/24/2004 00:00 - 04:30 4.50 DRILL P SURF Directional Drill from 9025' to 9290' - TD 13 1/2" Surface hole- WOB 40K to 45K - RPM 100 - TQ on 18K - off 16K - GPM 550 - PP on 2450 - off 2250 - PU 205K - SO 105K - ROT 130K 04:30 - 06:30 2.00 CASE P SURF CBU 1 X - GPM 550 - ICP 2250 - FCP 2150 - RPM 120 - TQ 17K - Flow Check 06:30 - 08:00 1.50 CASE P SURF Pump out to 7500' with drlg rate - RIH from 7500 to 9200' - Hole in good shape 08:00 - 08:30 0.50 CASE P SURF Precauctionary wash I ream from 9200' to 9290' 08:30 - 09:30 1.00 DRILL P SURF Directional Drill additional surface hole from 9290' to 9376' as per Geologist - TO 13 1/2" Surface hole - WOB 40K - RPM 100 - TQ on 18K - off 17K - GPM 550 - PP On 2490 - off 2250 - PU 215K - SO 105K - ROT 130K 09:30 - 15:00 5.50 CASE P SURF CBU 3 X - GPM 550 - ICP 2250 - FCP 2050 - RPM 120 - TQ 16K 15:00 - 23:30 8.50 CASE P SURF Pump out from 9376' to HWT@ 631' - Pump at drlg rate 23:30 - 00:00 0.50 CASE P SURF Stand back 5" HWT I Jars - Lay down 8" BHA 3/25/2004 00:00 - 01 :30 1.50 CASE P SURF Lay down 8" BHA - Down load MWD 01 :30 - 03:00 1.50 CASE P SURF Clear rig floor of all unnecessary - PJSM - Rig up 10 3/4" casing tools - Franks Fill up tool - Load remaining casing in pipe shed 03:00 - 13:00 10.00 CASE P SURF PJSM - Pick up - make up - float equipment - Check floats - Pick up and run 225 joints of 103/4" 45.5# L-80 BTC-M to 9340' - Break circulation @ 2500' - 5800' - 7400' - 8100' - SO 130K 13:00 - 13:30 0.50 CASE P SURF Make up landing joint I Hanger - RIH land casing @ 9363' - Lay down Franks fill up tool - Blow down Top Drive - Install cement Schlumberger head - 13:30 - 16:30 3.00 CASE P SURF Break circulation 4 bpm 600 psi - Stage up pumps to 7.5 bpm @ 400 - Circulate and condition mud for pending cement job - 16:30 - 00:00 7.50 CASE N WAIT SURF Circulate at 5 bpm @ 180 psi - Waiting on vac trucks to do cement job - (Lost total mud 345 bbls 260 to break circulation 85 bbl circulating up to 22:00 hrs)(lost 25 bbls additional mud circfrom 22:00 hrs to 00:00 hrs) . 3/26/2004 00:00 - 01 :30 1.50 CASE N WAIT SURF Circulate 7 bpm 280 psi - Waiting on trucks for cement job - Lost 25 bbls mud while circulating) 01 :30 - 04:30 3.00 CEMT P SURF PJSM - Pump 10 bbls water - Test lines to 4000 psi - Pump 25 bbls CW100 wash @ 6 bpm 120 psi - Pump 45 bbls Mud Push mixed at 10 ppg @ 7.5 bpm 140 psi - Drop bottom by pass wiper dart - Load bottom plug - Mix and pump 573 sxs 'Artie set Lite - yield 4.28 cf/sx 437 bbls slurry mixed at 10.7 ppg @ 7.5 bpm 140 psi - Mix and pump 258 sxs Class 'G' yield 1.17 cf/sx 54 bbls slurry mixed at 15.8 ppg @ 5.6 bpm 80 psi - Kick out top plug with 30 bbls water from Schlumberger - Give to rig - Full returns no losses 04:30 - 06:30 2.00 CEMT P SURF Rig displacement - 666 bbls mud @ 7.5 bpm 350 psi - 75 bbls water @ 7.5 bpm 700 psi - 121.8 bbls of mud at 1230 psi. Began losing returns with 520 bbls of dlsplaoement pumped and lost total returns just before bumping plug. Lost atotaJ 01 "200 bbIs of mud during displacement. Bumped plug with 1500 Printed: 4/12/2004 11:30:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 3/26/2004 04:30 - 06:30 2.00 CEMT P SURF psi at 06: 16 hrs 3-26-04. Bled off pressure and floats held. 06:30 - 08:00 1.50 CASE P SURF Loaded 10-3/4" cementing head with closing plug. Pressured up on casing and shifted open ES Cementer with 2400 psi. Broke circulation at 7.5 bpm and circulated out annulus volume and 75 bbls of water in casing. No cement circulated out of hole. 08:00 - 09:30 1.50 CEMT P SURF PJSM - Pumped 10 bbls of water - test lines to 4000 psi - Pumped 25 bbls of CW100 chemical wash - Pumped 40 bbls of Mud Push mixed at 10 ppg with 2 gallons of dye @ 7.5 bpm 180 psi -Mixed and pumped 450 sxs (356 bbls) of 'Artie Set Lite' - yield of 4.28 cfls at 10.7 ppg. Observed red dye in spacer at surface. 09:30 - 10:00 0.50 CEMT P SURF Dropped closing plug and kicked out with 30 bbls of water. Switched to rig pumps and displaced cement at 7.5 bpm at 360 psi with full returns. Slowed pumps to 2.5 bpm @ 190 psi 10 bbls before bumping plug. Bumped plug at 0950 hrs 3-26-04. Closed ES Cementer with 1140 psi - continued pressuring up to 1500 psi. Bled off pressure and floats held. Had 181 bbls of good cement to surface. 10:00 - 11 :00 1.00 CASE P SURF Rig down Dowell Cement head - cement lines - Lay down Landing joint - Flush stack and flow lines 11 :00 - 13:00 2.00 CASE P SURF Nipple down Diverter - lines - Riser 13:00 - 13:30 0.50 CASE P SURF Nipple up FMC speed head - FMC 11' x 11' 5K G5 tubing head - test to 1000 psi for 10 mins 13:30 - 15:00 1.50 CASE P SURF Nipple up BOP's 15:00 - 16:00 1.00 CASE P SURF Install test plug - open annulus valves - Rig up testing equipment 16:00 - 20:30 4.50 CASE P SURF Test BOP's - Annular 250 low 2500 high 5 mins each test - Top - Btm - Blind rams - Choke manifold - HCR kill - HCR choke - Manual kill - Manual choke - Upper 1 Lower IBOP - Dart valve - TIW valve - 250 low 4500 high 5 mins each test - Accumulator test was performed - TIW valve failed and was replaced with Doyon valve - tested ok - Detection monitor for gas failed - replaced - retested - good - Chuck Sheave with AOGCC witness of the BOP test. 20:30 - 21 :00 0.50 CASE P SURF Rig down testing equipment - Pull test plug - Install wear ring - close annulus valves 21 :00 - 23:00 2.00 CASE P SURF Make up bit to motor - PU MWD - orient - Make up BHA - RIH with 5" HWT - Surface test - Test good 23:00 - 00:00 1.00 CASE P SURF RIH - picking up 5" DP from pipe shed - from 628' to 3/27/2004 00:00 - 00:30 0.50 CASE P SURF RIH - Picking up 5" DP from pipe shed - From 628' to 1950'- Wash from 1950' to 1983' - Tag plug at ES Cementer 00:30 - 01 :00 0.50 CASE P SURF Break circulation - stage up pump - circulate out thick clabbered mud from 4 bpm to 10 bpm 01 :00 - 05:00 4.00 CASE P SURF Drill plug At ES Cementer - 1983' to 1986' - wash to 2013' - WOB 5K to 40K - RPM 10 to 60 - TQ 3 to 5 - GPM 390 to 450 - PP 750 to 920 - 05:00 - 06:30 1.50 CASE P SURF Con't RIH - Picking up 5" DP from pipe shed - from 2013' to 3845' 06:30 - 08:30 2.00 CASE P SURF RIH from derrick from 3845' to 9204' - Fill pipe @ 3845' - 5821' -7700' 08:30 - 09:30 1.00 CASE P SURF PJSM - Cut drlg line - Inspect brake linkage - Brake bands 09:30 - 10:00 0.50 CASE P SURF Rig service - Top drive service I Printed: 4/12/2004 11 :30:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 3/27/2004 10:00 - 11 :30 1.50 CASE P SURF Rig up to test casing - Teat,easing to 2500 psi for 30 mins - rEKlOfdOO chart - Rig down testing equip 11 :30 - 12:00 0.50 CASE P SURF circulate out thick - clabbered mud out of hole - slowly staging up pumps to 402 gpm 12:00 - 13:00 1.00 CASE P SURF Drill landing collar @ 9275' - Float collar @ 9318' - wash to top of float shoe @ 9361' - WOB 20K - RPM 60 - TO 25K - GPM 397 - PP 1100 13:00 - 14:30 1.50 CASE N WAIT SURF Circulate - Waiting on Vac trucks to return from being sent to R Pad with thick containmented mud - GPM 385 - PP 1020- RPM 60 - TO 23K - 14:30 - 15:00 0.50 CASE P SURF Drill float shoe from 9361' to 9363' - GPM 420 - PP 1600 - RPM 60 - WOB 20K - Wash rat hole from 9363' to 9376' 15:00 - 15:30 0.50 CASE P SURF Drill 20' new hole - 80 RPM - GPM 420 - PP 1600 - WOB 20K from 9376' to 9396' 15:30 - 17:00 1.50 CASE P SURF Displace well to LSND 9.1 ppg mud - RPM 80 TO 23K - GPM 590 - PP 1700 17:00 - 18:00 1.00 CASE P SURF "FIT - MW 9.1 - MD 9363' - TVD 4740' - Surface pressure 591 '" EMW11.5 18:00 - 00:00 6.00 DRILL P INT1 Directional Drill 97/8" hole - WOB 17K - RPM 100 - TO on 20K - off 20K - GPM 600 - PP on 2320 - off 2050 - PU 235K - SO 105K - ROT 144K 3/28/2004 00:00 - 00:00 24.00 DRILL P INT1 Directional Drill from 10143' to 12550" - WOB 15 to 20 - RPM 90 to 100 - TO on 20 - off 18 - GPM 585 - PP on 3120 - off 2660 - PU 240 - SO 135 - ROT 175 - ECD 10.5 3/29/2004 00:00 - 04:00 4.00 DRILL P INT1 Directional Drill from 12550' to 12895' - TD 9 7/8" hole - WOB 15 to 20 - RPM 90 to 100 - TO 20K - off 18K - GPM 550 to 585 - PP on 3120 - off 2700' - ECD 10.5 04:00 - 06:30 2.50 CASE P INT1 CBU 2 X - GPM 590 - PP 2700 - RPM 120 - TO 18K . 06:30 - 10:30 4.00 CASE P INT1 Pump out of hole at 500 gpm at 1800 psi from 12895' to 10-3/4" shoe at 9363'. No problems. 10:30 - 11 :30 1.00 CASE P INT1 Circulated bottoms up inside the casing while rotating and reciprocating the drill pipe. 550 gpm at 2000 psi. Circulated cutting out of hole - no clay balls. 11 :30 - 12:00 0.50 CASE P INT1 Serviced topdrive. 12:00 - 13:00 1.00 CASE P INT1 Run back in hole to 12895' filling the drill pipe every 25 stands. No problems. 13:00 - 16:30 3.50 CASE P INT1 CBU 3X while rotating and reciprocating the drill pipe. 120 RPM with 20K torque - 142 spm @ 2640 psi. 16:30 - 20:30 4.00 CASE P INT1 Pump out of hole from 12895' to 9297' @ 500 gpm. ICP 1950 FCP 1730 psi. Flow check at shoe - negative. 20:30 - 21 :30 1.00 CASE P INT1 CBU 1 X 600 gpm at 2350 psi. Circulated cuttings out of hole. 21 :30 - 23:00 1.50 CASE P INT1 Pulled out of hole from 9297' to 6106' standing drill pipe on off-driller side of pipe rack. 23:00 - 00:00 1.00 CASE P INT1 Pulling out of hole laying down drill pipe in pipe shed. 3/30/2004 00:00 - 04:00 4.00 CASE P INT1 Finished laying down 5" drill pipe in pipe shed. 04:00 - 04:30 0.50 CASE P INT1 Lay down BHA 04:30 - 06:00 1.50 CASE P INT1 Download MWD 06:00 - 07:30 1.50 CASE P INT1 Clear floor, Change rams to 7 5/8, test doors to 1500 PSI 07:30 - 08:30 1.00 CASE P INT1 PJSM, Rig up to run 7 5/8 csg 08:30 - 16:00 7.50 CASE P INT1 PJSM, pickingup 7 5/8 29# L-80 BTC-Mod. csg to 9,207 16:00 - 17:30 1.50 CASE P INT1 Circ with 340 gpm 870 psi 17:30 - 19:00 1.50 CASE P INT1 Picking up, 7 5/8 csg to 9413, set down on bridge, pulled into csg @ 9363, attempt to eire, packed off, worked pipe and try to Printed: 4/12/2004 11 :30:58 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 3/30/2004 17:30 - 19:00 1.50 CASE P INT1 Establish eire, no good 19:00 - 19:30 0.50 CASE N DPRB INT1 Layed down 4 jts of csg, pickup wt 300k, slackoff 50k to 100K, swabbing when we layed down pipe, Attempt to circ @ 9207 still packed off, no circ. 19:30 - 20:30 1.00 CASE N DPRB INT1 Re- Rigcsg tools to lay down csg, PJSMon laying down casing 20:30 - 00:00 3.50 CASE N DPRB INT1 Laying down 7 5/8 csg to 7964' to pipe shed, filling csg every 20 jts on the inside, Csg not swabbing, but not taking mud from annulus, pipèpt¡fling dfY 3/31/2004 00:00 - 10:00 10.00 CASE N DPRB INT1 Laying down 7 5/8 csg to pipe shed, filling csg every 20 jts on the inside 10:00 - 11 :30 1.50 CASE N DPRB INT1 Change top rams to 2 7/8 X 5, test door seals to 1500 psi 11 :30 - 14:00 2.50 CASE N DPRB INT1 Picking up 9 7/8 hole opener and BHA #6 14:00 - 19:00 5.00 CASE N DPRB INT1 Picking up 5" drill pipe from pipe shed 19:00 - 20:00 1.00 CASE N DPRB INT1 Tripping in hole with pipe out of derrick to 9142' 20:00 - 21 :00 1.00 CASE N DPRB INT1 Wash and ream from 9142' to 9612 with 425 gpm 100 rpms, saw no fill, or problems 21 :00 - 23:00 2.00 CASE N DPRB INT1 Tripping in to 12806', Washed to bottom,12895' 23:00 - 00:00 1.00 CASE N DPRB INT1 Circ and reciprocate with 600 gpm 2180 psi 150 rpms,20K torque, pump 40 bbl Sapp and nut plug sweep, and 40 bbls hi vis sweep, hole unloading lots of shale, sand and clay, bottoms up gas was 220 units 4/1/2004 00:00 - 04:30 4.50 CASE N DPRB INT1 Circ and reciprocate 4.5 bottoms up with 600 gpm 2000 psi 150 rpms,20K torque, hole unloading lots of shale, sand and clay, Started clearing up after 3 bottoms up, Condition mud to run Csg, spot LCM pill in hole, 04:30 - 11 :30 7.00 CASE N DPRB INT1 Slug pipe, Tripping out of hole, with 72 stands in derrick, lay down the rest of the pipe 11 :30 - 13:00 1.50 CASE N DPRB INT1 Laying down BHA 13:00 - 14:30 1.50 CASE N DPRB INT1 PJSM, Change rams to 7 5/8, test door seals to 1500 psi 14:30 - 15:30 1.00 CASE N DPRB INT1 PJSM, Rig up to run CSG. 15:30 - 22:30 7.00 CASE N DPRB INT1 PJSM, picking up 7 5/8 29# L·80 BTC Csg to 8000 ft, 22:30 - 23:30 1.00 CASE N DPRB INT1 Service rig, repair pipe skate 23:30 - 00:00 0.50 CASE N DPRB INT1 Picking up 7 5/8 29# L-80 BTC Csg to 8600 ft, 4/2/2004 00:00 - 00:30 0.50 CASE N DPRB INT1 Picking up 7 5/8 29# L·80 BTC Csg to 9363 ft, 00:30 - 02:00 1.50 CASE P INT1 Circ, Csg Volume with 336 gpm 750 psi 02:00 - 05:00 3.00 CASE P INT1 Picking up 7 5/8 29# L-80 BTC Csg to 12,883 ft total jts run 310 jts, P/u 360K Slo 120K 05:00 - 05:30 0.50 CASE P INT1 Rig down Franks Tool and Pick up Cement head 05:30 - 10:00 4.50 CASE P INT1 Circ and thin mud for cement job. Held PJSM for cementing job. 10:00 - 10:30 0.50 CEMT P INT1 Lined Dowell up to cement. Pumped 5 bbls of CW 100 chemical wash - test lines to 3500 psi - pumped 10 bbls of CW100 chemical wash - pump 20 bbls of 10.5 ppg mud push- dropped bottom plug - mixed and pumped 150 sxs (31 bbls) Class G cement +.4% D-167 + .3% D-065 + .2% D-046 + .08% B-155 mixed in a 15.8 ppg slurry with a yield of 1.16 cftlsx. Flushed Jines with 5 bbls of water. Dropped top plug and kicked out with 20 bbls of water. 10:30 - 12:00 1.50 CEMT P INT1 Displaced cement with rig pumps at 8 bpm at 550 psi. Slowed pumps down to 3 bpm before bumping plug. Had full returns and reciprocated pipe until cement exited casing. Bumped the plug with 1500 psi at 1145 hrs. and held for 3 minutes. Bled off Printed: 4/12/2004 11 :30:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 4/2/2004 10:30 - 12:00 1.50 CEMT P INT1 pressure and floats held. 12:00 - 12:30 0.50 CASE P INT1 Flushed packott area thru lower annulus valve and laid down landing joint. 12:30 - 13:30 1.00 CASE P INT1 Rigged down casing elevators, long bales and installed short bales 13:30 - 15:00 1.50 CASE P INT1 Install 7-5/8" packott as per FMC Tech and test to 5000 psi for 10 minutes. 15:00 - 17:00 2.00 CASE P INT1 PJSM, Install new drilling line 17:00 - 00:00 7.00 CASE P INT1 PJSM, Laying down 5' drill pipe in mouse hole 4/3/2004 00:00 - 00:30 0.50 CASE P INT1 install test plug, load pipe shed with 4" pipe 00:30 - 02:30 2.00 CASE P INT1 PJSM, Change rams to 2 7/8 x 5',Change out saver sub and handing tools on top drive 02:30 - 07:30 5.00 CASE P INT1 PJSM, Testing BOPS and manifold with 4,500 to 250 psi for 5 min. per test,Hydrill 2500 psi-250 psi for 5 min. per test,the ri~htwitoess Bop test was wavíer by Lou Grimaldi AOOGC 07:30 - 10:00 2.50 CASE P INT1 PIck up 50 jts new 4" pipe and pump thru, stand back in derrick 10:00 - 12:00 2.00 CASE P INT1 Picking up BHA #7,6.75 bit DS104 with 4 x 10 jets, stab, gammlreslpwd, Dir HOC,TM hoc,stab,flex dC,stab,2 flex dc,jars, xo, 12:00 - 00:00 12.00 CASE P INT1 Pick up 4 drill pipe from pipe shed, circ ever 50 jts to 12,758 4/4/2004 00:00 - 00:30 0.50 CASE P INT1 Circ, drill pipe volume @ 12,758 00:30 - 01 :30 1.00 CASE P INT1 Test Csg to 4,500 psi for 30 min. good test 01 :30 - 02:00 0.50 CASE P INT1 Drill cement and float collar @ 12,797 02:00 - 03:00 1.00 CASE P INT1 Daylight saving time change 03:00 - 04:00 1.00 CASE P INT1 Drill cement and float shoe @ 12883, wash and ream to 12,895 with 260 Gpm 2250 psi 80 rpms 04:00 - 12:00 8.00 CASE P INT1 Circ and treat mud for cement contamination and raise mud wt to 10.0 12:00 - 12:30 0.50 CASE P INT1 Drill new hole from 12,895 to 12,915 12:30 - 15:00 2.50 CASE P INT1 Circ and treat mud for cement contamination and raise mud wt to 10.0 ~ ,\Sllt-,.\..CCè ,t~'Y\1"(t. 15:00 - 16:00 1.00 CASE P INT1 FIT test TVD 664) 1320 psi, 10 # mud wt:: 13.8 EMW 16:00 - 19:00 3.00 DRILL P PROD1 Drilling from 12915 to 13, 155, with 150 rpms 270 GPM 2450 psi 19:00 - 19:30 0.50 DRILL P PROD1 Circ and Reciprocate wI Geologists talk to town 270 GPM 2450 psi 19:30 - 20:00 0.50 DRILL P PROD1 Drilling from 13,155 to 13,165, with 150 rpms 270 GPM 2450 psi ECD 11.6 ADT 1.93 20:00 - 21 :00 1.00 DRILL P PROD1 Circ bottoms up for Fit test 270 gpm, 2450 psi, 150 rpms 21 :00 - 21 :30 0.50 DRILL P PROD1 Pumping out with full drlg rate to 12,883 21 :30 - 22:30 1.00 DRILL P PROD1 FtT test; WIth 1550 psi, 10# mud wt. 6641TVD=: 14.5 EMW, QQOCI test ~ ,C;{~~ <;.~o(c 22:30 - 23:00 0.50 DRILL N HMAN PROD1 Trip to bottom 13,165 kf~>/1.- 23:00 - 00:00 1.00 DRILL N HMAN PROD1 Circ bottoms up, 270 gpm, 2450 psi, 150 rpms 4/5/2004 00:00 - 00:30 0.50 DRILL N HMAN PROD1 Pump out to csg shoe 12,883' with full drilling rate 00:30 - 05:00 4.50 DRILL N HMAN PROD1 Flow check,slug pipe and Tripping out to Pickup motor 05:00 - 06:30 1.50 DRILL N HMAN PROD1 Tripping out with BHA, Download MWD 06:30 - 07:30 1.00 DRILL N HMAN PROD1 Pickup BHA #8, DS104 6.75 bit with 4 X 10 jets, 4 3/4 Sperrydrill with 1.15 bend,stab,float sub,GammalRes/Pwd,dir hoc,TM hoc,stab,stab,3 flex de. jars 07:30 - 12:00 4.50 DRILL N HMAN PROD1 Trip in hole, fill pipe every 25 stands, wash last stand to bottom 12:00 - 15:00 3.00 DRILL P PROD1 Circ @ 13,165', PJSM, Displace well with 12.3 mud wt. ECD 13.8 base line with 250 gpm. 120 rpms Printed: 4/12/2004 11 :30:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: 3/18/2004 Rig Release: 4/10/2004 Rig Number: 14 Spud Date: 3/19/2004 End: 4/512004 15:00 - 00:00 9.00 DRILL P PROD1 Drill from 13,165' to 13365' with 250 gpm, 3,200 psi, 120 rpms, ECD 13.8, AST 2.42, ART 1.41, BGG 34 units 4/6/2004 00:00 - 03:00 3.00 DRILL P PROD1 Drill from 13365' to 13419' with 250 gpm, 3,300 psi, 120 rpms, ECD 13.8 to 14.3 03:00 - 03:30 0.50 DRILL P PROD1 Circ due to high ECD, due to long slides, ECD drop from 14.3 to 14.0 03:30 - 06:00 2.50 DRILL P PROD1 Drill from 13419' to 13,520' with 250 gpm, 3,300 psi, 120 rpms, ECD 14.0 06:00 - 07:30 1.50 DRILL P PROD1 Mad pass 13520 to 13360 150 ft per hr. 07:30 - 08:00 0.50 DRILL P PROD1 Drill from 13,520' to 13547' with 250 gpm, 3,300 psi, 120 rpms, ECD 14.0 08:00 - 09:30 1.50 DRILL P PROD1 Circ, one bottoms up with 250 gpm 3000 psi, 120 rpms 09:30 - 10:00 0.50 DRILL P PROD1 Pump out to csg shoe @ 12883 with full drilling rate 10:00 - 10:30 0.50 DRILL P PROD1 Monitor well 10:30 - 11 :00 0.50 DRILL P PROD1 RIH to 13547, shift MWD mode 11 :00 - 15:30 4.50 DRILL P PROD1 Drill from 13547' to 13817' with 250 gpm, 3,300 psi, 120 rpms, ECD 14.0, short trip gas 155 units, max gas drilling A sand 1620 units 15:30 - 18:00 2.50 CASE P PROD1 Circ, two bottoms up with 260 gpm 3200 psi, 120 rpms, BG gas 50 units, mud wt. 12.3+, ECD 13.9 18:00 - 19:30 1.50 CASE P PROD1 Pump out to 12,883, with full drilling rate, mad pass 13682 to 13,550 19:30 - 20:00 0.50 CASE P PROD1 Monitor well, service top drive 20:00 - 20:30 0.50 CASE P PROD1 RIH 20:30 - 00:00 3.50 CASE P PROD1 Circ, three bottoms up, Ralnfl'lUd wt. to 12.5, with 260 gpm, 3300 psi, 120 rpms, short trip gas 250 units, BG gas 25 units, ECD 14, mud wt. 12.5 41712004 00:00 - 00:30 0.50 CASE P PROD1 Finish Circ, three bottoms up 00:30 - 01 :30 1.00 CASE P PROD1 Pumping out to 12,883' with full drilling rate 01 :30 - 02:30 1.00 CASE P PROD1 Circ. bottoms up @ 12883 with 260 gals min, 3000 psi, 120 rpms 02:30 - 06:30 4.00 CASE P PROD1 Tripping out to BHA 06:30 - 08:00 1.50 CASE P PROD1 lay down BHA, down load MWD 08:00 - 09:00 1.00 CASE P PROD1 PJSM, Clear floor, rig up to pickup Liner 09:00 - 11 :00 2.00 CASE P PROD1 Picking up 25 Jts 4.5 12.6# L-80 IBT liner, Baker flex lock hanger,Baker ZXP liner top packer 11 :00 - 11 :30 0.50 CASE P PROD1 Circ liner volume 5 bbls min 270 psi 11 :30 - 12:00 0.50 CASE P PROD1 Tripping in with liner to 1,588 12:00 - 12:30 0.50 CASE P PROD1 Service rig and top drive 12:30 - 14:30 2.00 CASE P PROD1 Tripping in with liner to 6094, fill every 10 stands 14:30 - 15:00 0.50 CASE N RREP PROD1 Link tilt assy. broke, remove same 15:00 - 20:00 5.00 CASE P PROD1 Pjsm on tripping with out link tilt, Tripping in with liner 12809 20:00 - 21 :30 1.50 CASE P PROD1 Circ, Drill pipe and Liner volume with 3.5 bbls min 1250 psi 21 :30 - 22:00 0.50 CASE P PROD1 Tripping in with Liner to 13,801 22:00 - 22:30 0.50 CASE P PROD1 Pickup cement head, wash out line,safety line 22:30 - 00:00 1.50 CASE P PROD1 Wash liner to bottom 13,817, Circ. with 3.5 bbls min 1350 psi, reciprocate liner 20 ft strokes 4/8/2004 00:00 - 01 :00 1.00 CASE P PROD1 Circ, bottoms up with 3.5 bbls min 1350 psi, no gas cut mud to surface 01 :00 - 03:00 2.00 CEMT P PROD1 Cement with Schlumberger, with 5 bbls water, test lines to 4,000 psi, 15 bbls CW-100,20 bbls mud push mix at 13.5,43 bbls Class G with 2.0 gal/sx GasBlok, yield 1.20 mixed @ Printed: 4/12/2004 11:30:58 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-43 MPC-43 DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 3/18/2004 4/10/2004 14 Spud Date: 3/19/2004 End: 4/812004 01 :00 - 03:00 2.00 CEMT P PROD1 15.8., washed out cement line,drop plug, Displace with 150 bbls 12.5 mud @ 4 bbls min, r~ till cement rounded shoe. bump plUlfwith 3,500 psi to set hanger, floats held, full returns thru out job 03:00 - 03:30 0.50 CASE P PROD1 Release from liner and set packer as per Baker rep. Liner shoe @ 13,815, float collar 13,770, landing collar 13,727, hanger 12,752, packer 12,746, top of tie back 12,735 03:30 - 04:30 1.00 CASE P PROD1 Pull off liner with 1000 psi, lost pressure, closed Hydrill and reverse drill pipe with 12.5 mud 5 bbls min. 1650 psi, reverse two drill pipe volumes, 15 bbIs of good cement to surface 04:30 - 05:00 0.50 CASE P PROD1 Rig down cement head, cement line 05:00 - 10:00 5.00 CASE P PROD1 Slug pipe and Tripping out with running tools 10:00 - 11 :00 1.00 CASE P PROD1 lay down running tool, Clear floor of tools 11 :00 - 17:00 6.00 RUNCOMP COMP Pick up 6.75 bit and Csg scraper, trip in to 12,735 top of liner 17:00 - 17:30 0.50 RUNCOMP COMP Circ.. on top of liner 17:30 - 19:00 1.50 RUNCOMP COMP Tè8t Csg to 4500 psi for 30 min. good tést 19:00 - 23:00 4.00 RUNCOMP COMP Displace well with 100 rpms 9 bbls min. 3500 psi, hi vis sweep, 520 bbls water, Hi vis sweep, 620 bbls sea water, 520 bbls sea water treated with corrosion inhibiter 23:00 - 00:00 1.00 RUNCOrvP COMP PJSM, Laying down drill pipe 4/9/2004 00:00 - 09:00 9.00 RUNCOMP COMP Laying down drill pipe 09:00 - 10:00 1.00 RUNCOMP COMP Clear floor, pull wear ring 10:00 - 19:00 9.00 RUNCOMP COMP Picking up 300 jts, 4.512.6# L-80 IBT tubing, wire line guide 12,743, XN 12731, Packer 12704, x nipple 12693, Sliding sleeve 12669, % GLMS 12517, 11608, 9990,7384,3290 with DCK valve, PU wt 150K, Slo wt. 95k, Block wt. 50k 19:00 - 20:30 1.50 RUNCOMP COMP Space out and land tubing, test TWC to 1000 psi, 20:30 - 21 :30 1.00 RIGD P COMP Nipple down BOPS 21 :30 - 23:00 1.50 RIGD P COMP Nipple up Fmc 11 x 4" adapter flange, CIW 4 1/16 5M tree, test tree to 4000psi, Test Tubing hanger to 5,000 psi 23:00 - 00:00 1.00 RIGD P COMP Drop ball and rod, wait 15 min.,pressure up on tubing to set packer, test tubing to 4000 psi, recorded on chart for 30 min. good test 4/10/2004 00:00 - 01 :30 1.50 RIGD P COMP Bleed tubing pressure back to 3,000 psi,:reat ennuloo and packer to 4500 psi, recorded on chart for for 30 min. good test, bleed tubing pressure off and DCK valve shear with 2500 psi differential. 01 :30 - 03:00 1.50 RIGD P COMP Pump 92 bbls diesel with HB&R down annulus and let U-tube 1 hr. to tubing for freeze protection 03:00 - 04:00 1.00 RIGD P COMP Install 4" CIW type H BPV and test to 1000 psi from back side 04:00 - 04:30 0.50 RIGD P COMP Nipple down Circ. and test lines, secure well, suck out cellar Rig release for rig move to MPE-25A @ 0430 hrs 4/10/2004 Printed: 4/12/2004 11:30:58 AM e e Well: Field: API: Permit: MPC-43 Milne Point Unit I Kuparuk River 50-029-23200-00-00 204-039 Accept: Spud: Release: Rig: 03-18-04 03-19-04 04-1 0-04 Doyon 141 POST-RIG WORK 04/26/04 RAN JEWELRY LOG WI TEMPERATURE PRESSURE DATA, AND PERFORATED FROM 13,580- 13,600 AND 13,566 - 13,576 (REF. MWD LOG) WI 12 SPF 3.38" POWERFLOW GUNS. TAGGED TD WI 1-11/16" TOOL AT 13610' MD, TAGGED WI 3.38" GUNS AT 13604'. 04/27/04 PRESSURE TEST IA TO 4000-PSI 05/08/04 TIIA =1325/0 PSI. E LINE WORK IN PROGRESS AT ARRIVAL. PUMP ON E LINE TO ASSIST GETTING IN THE HOLE. PUMPED 1.7 BBLS DIESEL TO 3,500 PSI. .7 BBLS DIESEL MORE TO 4000 PSI. MONITOR. BLEED WELL BACK TO 1300 PSI. RIG BACK UP TO TREE CAP WIHARDLlNE. PUMP ON TUBING. WELL BROKE OVER @ 4375 PSI. PUMPED 20 BBLS DIESEL TO DISPLACE. AN SCMTtOOW~ATTËMPTED. COULD NOT PASS GLM @ 3291 DUE TO DEVIATION. TRIED TO PUMP FLUIDS, BUT FORMATION WAS LOCKED UP. RIGGED DOWN. FIRST ENERGY WAS ABLE TO PUMP INTO FORMATION. WIND SPEEDS DID NOT ALLOW FOR ANOTHER RIG UP 05/09/04 RIH WITH HEAD/SWIVEL/WEIGHTBAR/ROLLERS/wIEGHTBAR/PSPT/SCMT AT 110 FPM. HUNG UP NEAR GAS LIFT MANDREL AT 3291 FT. HAD HB&R PUMP 60 BBLS OF DIESEL AT 0.5 BPM TO 3.1 BPM IN ORDER TO WORK PAST. TAG TD AT 13605 FT. TIED INTO SPERRY-SUN MWD LOG DATED 7-APR-2004. PERFORMED MAIN CEMENT LOG OVER INTERVAL 12,600 -13,605 FT. LOG INDICATES GOOD CEMENT BOND ACROSS THE ENTIRE 4-1/2" LINER. OS/20/04 FRAC'D "A" SAND PERFS 13566'-13600' WI 213.5K# CARBOLlTE USING YF-130LG SYSTEM. PLACED 213K# BEHIND PIPE, UNDER DISPLACE BY 5 BBLS, LEFT 1450# IN CSG. FP WORKSTRING WITH 40 BBLS DIESEL. EST. TOS= 10400' MD. MAX TREAT= 4600 PSI, AVG TREAT=4000 PSI. LOAD TO RECOVER-1447 BBLS, ALL CUPS AND ELEMENTS FROM ISOLATION TOOL RECOVERED. OS/21/04 MIRU CTU # 8. RIH CLEAN OUT WITH FLOPRO TO 13695'(UP). 1:1 RETURNS THROUGHOUT JOB. SLIGHT CARBOLlTE RETURNS. FREEZE PROTECT WELL TO 2500'. OS/24/04 PT FLOWLINE TO 2500 PSI FROM DBB LATERAL VALVE TO MOD 26 OS/28/04 TOOLS FALLING VERY SLOW DUE TO THICK CRUDE. COULD NOT GET PAST 9550'WLM WHEN ATTEMPTING TO RUN SBHP SURVEY. RAN 3" DRIVE DOWN BAILER TO 9550'WLM, COULD NOT WORK PAST. FOUND SMALL TRACES OF FRAC SAND IN BAILER AND QC'S. WILL RETURN TO BRUSH & FLUSH TUBING WI DIESEL, AND SET 12A JET PUMP 05/31/04 RAN BL BRUSH WHILE PUMPING DIESEL @ 1.5 BPM. AFTER PUMPING 42 BBLS TUBING PRESSURED UP TO 2950PSI. TAGGED TD WI @ 13499' CORRECTED WLM. APPROXIMATELY MPC-43 Page 2 e e 67'OF FILL ABOVE PERFS. ATTEMPTED TO SHIFT SSD, BUT COULD NOT GET PAST 9155'WLM. TOOLS CONTAINED TRACES OF FRAC SAND. T/I/O= 100010/175, ASSIST SLB WITH BRUSH AND FLUSH, PUMPED 42 BBLS 120 DEG DSL DOWN TBG WHILE SL WAS ENTERING TBG WITH BRUSH AND GAUGE RING. FINALS T/I/O= 100010/150. 06/04/04 CTU#8: FILL CLEAN OUT. WELL SHUT IN UPON ARRIVAL. MIRU. RIH 2" STINGERINOZZLE. BEGIN REVERSING OUT @ 2000'. REVERSE OUT FRAC SAND FROM 13478' TO 13700' CTMD. RECIPROCATE ACROSS ALL GLM'S AND HES DURO SLEEVE. RBIH TO 13700' CTMD. REVERSE UNTIL RETURNS ARE CLEAN. SWAP TO DIESEL, REVERSE IN 164 BBLS DIESEL. 06/05/04 AT SURFACE. FLUSH COIL WITH 50/50 METHANOL. RD OS CTU #8. WELL IS SHUT-IN, CLEANED OUT TO 13700' CTMD AND TOPPED WITH 164 BBLS DIESEL. SIWHP = 1230 PSIG. RAN SBHP SURVEY. TAGGED TO @ 13659'WLM (13694'CWLMD), USED CORRECTION OFF OF SSD. SHIFTED SSD TO OPEN POSITION. 06/06/04 SET12'AJET PUMP (SER# BP-1099). SET 12A JET PUMP (BP-1099) AT 12633' WLM. Legal Name: MPC-43 Common Name: MPC-43 3/18/2004 3/27/2004 4/4/2004 FIT FIT FIT (ft) 9,363.0 (ft) 13,165.0 (ft) (ft) 4,740.0 (ft) 6,641.0 (ft) (ppg) 9.10 (ppg) 10.00 (ppg) (psi) 591 (psi) 1,550 (psi) (psi) 2,832 (psi) 5,000 (psi) 11.00 (ppg) 11.50 (ppg) 14.49 (ppg) e e Printed: 4/12/2004 11 :30:50 AM e e 17-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well MPC-43 Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00' MD 0.00' MD 13,817.00' 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 /I Date. R3 ~~ L/ Signed ~. ðlWvJ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager R 1j0( -()}~ Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPC MPC-43 Job No. AKZZ2979490, Surveyed: 6 April, 2004 Survey Report 16 April, 2004 Your Ref: API 500292319600 Surface Coordinates: 6029626.64 N, 558167.60 E (70029' 29.6060· N, 149031'28.0736. W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 1029626.64 N, 58167.60 E (Grid) Surface Coordinates relative to Structure Reference: 2278.00 N, 127.39 E (True) Kelly Bushing Elevation: 51. 10ft above Mean Sea Level Kelly Bushing Elevation: 51. 10ft above Project V Reference Kelly Bushing Elevation: 51.10ft above Structure Reference 5pe............y-5u., DRILLING seR.VIc:;es A Halliburton Company DEFINITIVE e e Survey Ref: svy1379 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 Your Ref: AP/500292319600 Job No. AKZZ2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 0.00 0.000 0.000 -51.1 0 0.00 0.00 N 0.00 E 6029626.64 N 558167.60 E 0.00 Tolerable Gyro 81.00 0.600 51.000 29.90 81.00 0.27 N 0.33 E 6029626.91 N 558167.93 E 0.741 0.14 176.00 0.950 358.000 124.89 175.99 1.37 N 0.69 E 6029628.01 N 558168.28 E 0.799 1.05 267.00 2.600 322.000 215.85 266.95 3.75 N 0.61 W 6029630.38 N 558166.96 E 2.104 3.73 355.00 4.800 306.000 303.66 354.76 7.49 N 4.82W 6029634.09 N 558162.72 E 2.738 8.68 e 446.00 6.500 298.000 394.22 445.32 12.14 N 12.45 W 6029638.68 N 558155.06 E 2.054 15.66 539.00 8.400 295.000 486.43 537.53 17.48 N 23.25 W 6029643.94 N 558144.21 E 2.085 24.36 632.00 8.750 300.000 578.39 629.49 23.89 N 35.53 W 6029650.25 N 558131.88 E 0.885 34.57 AK-6 BP JFR-AK 653.60 9.130 307.110 599.73 650.83 25.75 N 38.32 W 6029652.09 N 558129.08 E 5.405 37.27 756.62 11.340 322.550 701.12 752.22 38.72 N 51.00 W 6029664.96 N 558116.29 E 3.402 53.79 851.77 12.880 324.660 794.15 845.25 54.80 N 62.83 W 6029680.95 N 558104.35 E 1.684 72.94 947.28 13.870 329.790 887.07 938.17 73.38 N 74.75 W 6029699.43 N 558092.28 E 1.617 94.46 1037.82 15.880 323.580 974.58 1025.68 92.73 N 87.56 W 6029718.68 N 558079.32 E 2.831 117.02 1132.56 20.000 325.430 1064.69 1115.79 116.51 N 104.46 W 6029742.33 N 558062.23 E 4.390 145.14 1227.69 24.970 329.180 1152.57 1203.67 147.17N 123.99 W 6029772.84 N 558042.46 E 5.435 180.62 1321.37 28.770 332.320 1236.12 1287.22 184.13 N 144.60 W 6029809.63 N 558021.56 E 4.329 222.39 1416.75 31.740 332.180 1318.50 1369.60 226.65 N 166.98 W 6029851.98 N 557998.86 E 3.115 270.00 1512.56 35.470 331.820 1398.29 1449.39 273.46 N 191.87 W 6029898.59 N 557973.59 E 3.899 322.49 1603.78 39.850 331.510 1470.48 1521.58 322.50 N 218.33 W 6029947.42 N 557946.76 E 4.806 377.61 1699.87 44.860 331.180 1541.47 1592.57 379.29 N 249.37 W 6030003.97 N 557915.27 E 5.219 441.58 1793.51 43.890 330.860 1608.40 1659.50 436.58 N 281.10 W 6030061.00 N 557883.10 E 1.063 506.25 1886.88 43.470 330.540 1675.93 1727.03 492.81 N 312.65 W 6030116.99 N 557851.10 E 0.508 569.87 e 1979.30 44.300 337.990 1742.58 1793.68 550.45 N 340.40 W 6030174.41 N 557822.90 E 5.657 633.52 2069.87 46.650 335.130 1806.09 1857.19 609.67 N 366.11 W 6030233.42 N 557796.73 E 3.435 697.95 2165.35 52.390 336.040 1868.05 1919.15 675.78 N 396.09 W 6030299.30 N 557766.23 E 6.055 770.32 2259.03 55.270 335.040 1923.34 1974.44 744.60 N 427.41 W 6030367.88 N 557734.37 E 3.193 845.70 2354.52 58.910 333.210 1975.21 2026.31 816.70 N 462.42 W 6030439.70 N 557698.81 E 4.137 925.42 2450.34 63.160 332.830 2021.60 2072.70 891.39 N 500.45 W 6030514.09 N 557660.20 E 4.449 1008.60 2541.74 64.260 336.490 2062.10 2113.20 965.44 N 535.50 W 6030587.86 N 557624.57 E 3.786 1090.16 2633.18 66.500 336.960 2100.19 2151.29 1041.80 N 568.34 W 6030663.96 N 557591.13 E 2.494 1173.14 2729.16 69.120 340.440 2136.44 2187.54 1124.59 N 600.59 W 6030746.49 N 557558.23 E 4.327 1261.96 2820.77 69.030 342.360 2169.17 2220.27 1205.68 N 627.88 W 6030827.37 N 557530.31 E 1.960 1347.50 2916.14 68.710 342.430 2203.54 2254.64 1290.47 N 654.79 W 6030911.95 N 557502.74 E 0.342 1436.38 3009.05 68.720 342.670 2237.27 2288.37 1373.06 N 680.75 W 6030994.33 N 557476.13 E 0.241 1522.87 3103.10 68.790 342.780 2271.35 2322.45 1456.76 N 706.78 W 6031077.83 N 557449.45 E 0.132 1610.44 16 April, 2004 - 7:37 Page 2 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 Your Ref: API 500292319600 Job No. AKZZ2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 3197.53 68.860 343.660 2305.46 2356.56 1541.07 N 732.20 W 6031161.93 N 557423.37 E 0.872 1698.36 3291.68 68.780 343.930 2339.48 2390.58 1625.37 N 756.70 W 6031246.04 N 557398.21 E 0.281 1785.96 3385.96 67.840 342.340 2374.32 2425.42 1709.20 N 782.11 W 6031329.67 N 557372.14 E 1.857 1873.44 3480.25 68.970 340.020 2409.03 2460.13 1792.18 N 810.40 W 6031412.42 N 557343.21 E 2.583 1961.08 3574.61 69.430 339.430 2442.54 2493.64 1874.92 N 840.96 W 6031494.93 N 557311.99 E 0.761 2049.29 e 3666.13 69.490 339.410 2474.65 2525.75 1955.15 N 871.09 W 6031574.92 N 557281.24 E 0.069 2134.99 3760.73 68.840 339.210 2508.30 2559.40 2037.87 N 902.33 W 6031657.38 N 557249.36 E 0.715 2223.39 3854.10 68.780 339.220 2542.05 2593.15 2119.26 N 933.22 W 6031738.53 N 557217.83 E 0.065 2310.44 3948.96 67.910 339.340 2577.05 2628.15 2201.72 N 964.41 W 6031820.75 N 557185.99 E 0.925 2398.60 4043.48 68.040 339.410 2612.50 2663.60 2283.72 N 995.28 W 6031902.51 N 557154.49 E 0.154 2486.21 4136.93 67.240 339.950 2648.05 2699.15 2364.77 N 1025.29 W 6031983.31 N 557123.84 E 1.009 2572.63 4230.67 66.310 339.760 2685.01 2736.11 2445.64 N 1054.96 W 6032063.95 N 557093.54 E 1.009 2658.78 4315.91 66.510 339.850 2719.12 2770.22 2518.96 N 1081.92 W 6032137.05 N 557066.00 E 0.254 2736.89 4420.90 67.590 341.210 2760.06 2811.16 2610.10N 1114.14 W 6032227.95 N 557033.07 E 1.575 2833.56 4515.63 67.310 341.710 2796.39 2847.49 2693.05 N 1141.96 W 6032310.67 N 557004.61 E 0.570 2921.02 4608.11 66.770 341.760 2832.47 2883.57 2773.91 N 1168.65 W 6032391.33 N 556977.29 E 0.586 3006.14 4701.73 66.860 342.010 2869.33 292Q.43 2855.71 N 1195.41 W 6032472.91 N 556949.89 E 0.264 3092.16 4795.27 65.850 341.810 2906.84 2957.94 2937.16 N 1222.01 W 6032554.15 N 556922.65 E 1.097 3177.80 4887.86 66.850 342.280 2943.98 2995.08 3017.84 N 1248.16 W 6032634.62 N 556895.87 E 1.176 3262.56 4981.60 65.840 341.710 2981.59 3032.69 3099.50 N 1274.69 W 6032716.07 N 556868.70 E 1.213 3348.38 5077.23 67.970 340.220 3019.11 3070.21 3182.64 N 1303.39 W 6032798.99 N 556839.35 E 2.649 3436.32 5171.03 67.850 340.390 3054.38 3105.48 3264.47 N 1332.68 W 6032880.59 N 556809.42 E 0.211 3523.24 e 5265.31 67.760 340.860 3090.00 3141.10 3346.82 N 1361.64 W 6032962.71 N 556779.82 E 0.471 3610.53 5360.25 68.240 340.430 3125.56 3176.66 3429.87 N 1390.82 W 6033045.53 N 556750.00 E 0.657 3698.55 5453.30 69.290 340.430 3159.26 3210.36 3511.59 N 1419.87 W 6033127.02 N 556720.31 E 1.128 3785.28 5548.21 67.570 340.370 3194.15 3245.25 3594.74 N 1449.47 W 6033209.93 N 556690.05 E 1.813 3873.54 5647.74 67.060 341.950 3232.54 3283.64 3681.65 N 1479.13 W 6033296.60 N 556659.71 E 1.552 3965.34 5741.69 65.700 342.400 3270.18 3321.28 3763.59 N 1505.48 W 6033378.34 N 556632.72 E 1.513 4051.36 5835.85 65.030 342.500 3309.43 3360.53 3845.20 N 1531.29 W 6033459.74 N 556606.28 E 0.718 4136.88 5929.74 65.420 342.630 3348.78 3399.88 3926.53 N 1556.83 W 6033540.87 N 556580.10 E 0.434 4222.05 6023.30 66.170 342.840 3387.14 3438.24 4008.02 N 1582.16W 6033622.16 N 556554.14 E 0.827 4307.29 6118.86 66.500 341.960 3425.49 3476.59 4091.44 N 1608.62 W 6033705.37 N 556527.02 E 0.911 4394.74 6212.20 66.970 342.620 3462.36 3513.46 4173.13 N 1634.71 W 6033786.85 N 556500.30 E 0.822 4480.42 6306.72 68.720 342.030 3498.01 3549.11 4256.53 N 1661.29 W 6033870.05 N 556473.07 E 1.940 4567.89 6400.34 68.440 341.770 3532.20 3583.30 4339.37 N 1688.36 W 6033952.67 N 556445.34 E 0.395 4655.00 16 April, 2004 - 7:37 Page 30f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 Your Ref: API 500292319600 Job No. AKZZ2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 6494.10 67.240 341.480 3567.56 3618.66 4421.78 N 1715.73 W 6034034.86 N 556417.33 E 1.312 4741.80 6589.12 65.690 342.840 3605.50 3656.60 4504.70 N 1742.43 W 6034117.57 N 556389.99 E 2.093 4828.86 6685.01 65.560 341.850 3645.08 3696.18 4587.93 N 1768.92 W 6034200.59 N 556362.85 E 0.950 4916.13 6778.67 67.050 341.350 3682.72 3733.82 4669.30 N 1795.99 W 6034281.75 N 556335.14 E 1.664 5001.86 6870.16 68.450 338.910 3717.36 3768.46 4748.93 N 1824.77 W 6034361.15 N 556305.73 E 2.904 5086.53 e 6964.47 68.910 338.290 3751.65 3802.75 4830.72 N 1856.83 W 6034442.69 N 556273.03 E 0.783 5174.35 7057.03 69.830 339.120 3784.26 3835.36 4911.43 N 1888.29 W 6034523.15 N 556240.95 E 1.301 5260.95 7155.56 68.780 340.000 3819.08 3870.18 4997.80 N 1920.48 W 6034609.26 N 556208.08 E 1.354 5353.12 7247.79 67.460 340.290 3853.45 3904.55 5078.30 N 1949.55 W 6034689.53 N 556178.38 E 1.461 5438.70 7342.85 66.710 341.090 3890.47 3941.57 5160.93 N 1978.50 W 6034771.93 N 556148.78 E 1.106 5526.25 7437.55 65.920 341.120 3928.51 3979.61 5242.98 N 2006.59 W 6034853.76 N 556120.06 E 0.835 5612.96 7531.21 69.250 342.430 3964.22 4015.32 5325.21 N 2033.65 W 6034935.77 N 556092.35 E 3.783 5699.49 7626.71 68.320 343.030 3998.78 4049.88 5410.22 N 2060.08 W 6035020.58 N 556065.26 E 1.136 5788.42 7721.08 66.790 342.530 4034.81 4085.91 5493.53 N 2085.90 W 6035103.68 N 556038.79 E 1.694 5875.54 7812.60 68.190 343.300 4069.84 4120.94 5574.34 N 2110.73W 6035184.30 N 556013.32 E 1.716 5959.98 7905.31 68.630 343.670 4103.96 4155.06 5656.99 N 2135.24 W 6035266.75 N 555988.17 E 0.602 6046.03 7999.71 68.130 343.230 4138.74 4189.84 5741.11 N 2160.24 W 6035350.68 N 555962.52 E 0.684 6133.64 8094.89 66.580 343.580 4175.38 4226.48 5825.29 N 2185.33 W 6035434.66 N 555936.77 E 1.663 6221.33 8189.23 66.700 342.060 4212.79 4263.89 5908.03 N 2210.91 W 6035517.20 N 555910.54 E 1 .485 6307.84 8283.96 66.570 342.470 4250.36 4301.46 5990.86 N 2237.40 W 6035599.81 N 555883.41 E 0.420 6394.73 8378.54 66.720 340.240 4287.86 4338.96 6073.13 N 2265.15 W 6035681.86 N 555855.00 E 2.170 6481.53 8474.22 65.840 341.230 4326.35 4377.45 6155.82 N 2294.06 W 6035764.32 N 555825.45 E 1.320 6569.12 e 8567.98 65.440 339.970 4365.02 4416.12 6236.38 N 2322.43 W 6035844.66 N 555796.46 E 1.296 6654.53 8664.02 64.950 340.350 4405.32 4456.42 6318.38 N 2352.02 W 6035926.43 N 555766.23 E 0.624 6741.71 8756.32 63.670 341.130 4445.33 4496.43 6396.90 N 2379.45 W 6036004.73 N 555738.18 E 1.582 6824.88 8851.08 64.810 339.900 4486.51 4537.61 6477.35 N 2407.92 W 6036084.95 N 555709.08 E 1.677 6910.21 8945.14 66.430 340.580 4525.34 4576.44 6557.98 N 2436.88 W 6036165.35 N 555679.49 E 1.844 6995.88 9037.53 67.120 340.350 4561.77 4612.87 6637.99 N 2465.27 W 6036245.14 N 555650.47 E 0.781 7080.78 9130.41 67.500 340.160 4597.60 4648.70 6718.64 N 2494.22 W 6036325.57 N 555620.89 E 0.451 7166.47 9220.27 68.500 339.240 4631.26 4682.36 6796.78 N 2523.13 W 6036403.48 N 555591.37 E 1.463 7249.79 9317.38 67.920 339.920 4667.31 4718.41 6881.29 N 2554.59 W 6036487.73 N 555559.25 E 0.883 7339.95 9417.51 65.690 340.620 4706.74 4757.84 6967.91 N 2585.66 W 6036574.11 N 555527.50 E 2.318 7431.98 9511.35 66.560 340.120 4744.72 4795.82 7048.73 N 2614.49 W 6036654.71 N 555498.04 E 1.047 7517.79 9605.34 68.580 339.410 4780.59 4831.69 7130.25 N 2644.54 W 6036735.98 N 555467.36 E 2.260 7604.66 9700.03 68.530 339.260 4815.20 4866.30 7212.71 N 2675.65 W 6036818.20 N 555435.61 E 0.157 7692.79 16 April, 2004 - 7:37 Page 4 of7 DrilIQuest~O~0~002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 Your Ref: AP/500292319600 Job No. AKZZ2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9794.61 67.930 338.750 4850.28 4901.38 7294.71 N 2707.12 W 6036899.95 N 555403.50 E 0.808 7780.61 9890.54 68.450 338.270 4885.92 4937.02 7377.58 N 2739.74 W 6036982.56 N 555370.22 E 0.714 7869.64 9981.79 67.640 339.210 4920.04 4971.14 7456.45 N 2770.43 W 6037061.19 N 555338.92 E 1.304 7954.25 10074.96 67.440 339.960 4955.64 5006.74 7537.15 N 2800.47 W 6037141.65 N 555308.26 E 0.774 8040.35 10169.75 67.660 341.610 4991.84 5042.94 7619.87 N 2829.30 W 6037224.14 N 555278.78 E 1.625 8127.94 e 10261.98 67.780 344.060 5026.81 5077.91 7701.40 N 2854.48 W 6037305.48 N 555252.96 E 2.461 8213.18 10355.83 67.250 343.250 5062.70 5113.80 7784.61 N 2878.88 W 6037388.49 N 555227.91 E 0.977 8299.72 10447.91 66.910 342.640 5098.56 5149.66 7865.69 N 2903.76 W 6037469.38 N 555202.40 E 0.713 8384.42 10543.34 66.900 343.390 5135.99 5187.09 7949.65 N 2929.40 W 6037553.13 N 555176.10 E 0.723 8472.09 10637.76 66.050 342.520 5173.68 5224.78 8032.42 N 2954.77 W 6037635.69 N 555150.08 E 1.235 8558.55 10732.18 66.930 342.790 5211.35 5262.45 8115.06N 2980.58 W 6037718.13 N 555123.62 E 0.968 8645.04 10827.81 66.780 341.600 5248.94 5300.04 8198.78 N 3007.47 W 6037801.64 N 555096.08 E 1.155 8732.91 10921.70 67.380 342.020 5285.50 5336.60 8280.93 N 3034.47 W 6037883.58 N 555068.44 E 0.760 8819.35 11013.88 67.180 341.850 5321.10 5372.20 8361.77 N 3060.83 W 6037964.21 N 555041 .45 E 0.276 8904.33 11106.96 67.990 341.730 5356.60 5407.70 8443.51 N 3087.72 W 6038045.73 N 555013.92 E 0.878 8990.34 11201.81 67.850 342.720 5392.25 5443.35 8527.20 N 3114.55 W 6038129.22 N 554986.43 E 0.978 9078.17 11297.10 67.380 341.960 5428.54 5479.64 8611.16 N 3141.28 W 6038212.96 N 554959.05 E 0.887 9166.21 11390.93 66.990 342.110 5464.92 5516.02 8693.43 N 3167.96 W 6038295.02 N 554931.73 E 0.441 9252.65 11485.35 64.340 340.480 5503.83 5554.93 8774.91 N 3195.53 W 6038376.28 N 554903.52 E 3.217 9338.65 11579.84 61.570 340.010 5546.79 5597.89 8854.11 N 3223.97 W 6038455.26 N 554874.46 E 2.965 9422.80 11673.43 56.250 339.140 5595.10 5646.20 8929.20 N 3251.91 W 6038530.12 N 554845.93 E 5.740 9502.91 11769.04 50.690 340.920 5651.99 5703.09 9001.36 N 3278.18 W 6038602.07 N 554819.10 E 6.004 9579.70 e 11864.11 46.840 340.380 5714.65 5765.75 9068.80 N 3301.85 W 6038669.33 N 554794.90 E 4.072 9651.18 11956.50 43.270 341.240 5779.90 5831.00 9130.54 N 3323.36 W 6038730.90 N 554772.91 E 3.920 9716.55 12050.94 38.790 340.770 5851.13 5902.23 9189.15 N 3343.52 W 6038789.35 N 554752.29 E 4.755 9778.52 12144.55 35.260 341.340 5925.85 5976.95 9242.45 N 3361.83 W 6038842.51 N 554733.57 E 3.789 9834.87 12237.86 31.710 341.930 6003.66 6054.76 9291.30 N 3378.06 W 6038891.23 N 554716.96 E 3.820 9886.33 12332.25 28.340 340.970 6085.38 6136.48 9336.08 N 3393.06 W 6038935.89 N 554701.60 E 3.606 9933.54 12421.54 26.400 340.900 6164.67 6215.77 9374.87 N 3406.47 W 6038974.58 N 554687.89 E 2.173 9974.58 12512.25 24.000 341.390 6246.74 6297.84 9411.42 N 3418.96 W 6039011.02 N 554675.12 E 2.656 10013.19 12606.58 23.040 342.510 6333.23 6384.33 9447.20 N 3430.63 W 6039046.72 N 554663.17 E 1.123 10050.81 12701.47 22.430 342.450 6420.75 6471.85 9482.18 N 3441.67 W 6039081.60 N 554651.86 E 0.643 10087.45 12793.78 21.270 339.610 6506.43 6557.53 9514.66 N 3452.81 W 6039114.00 N 554640.46 E 1.700 10121.79 12827.53 21.050 339.160 6537.90 6589.00 9526.07 N 3457.10W 6039125.37 N 554636.08 E 0.810 10133.98 12903.50 19.870 339.720 6609.08 6660.18 9550.93 N 3466.43 W 6039150.16 N 554626.56 E 1.574 10160.53 16 April, 2004 - 7:37 Page 50f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 Your Ref: AP/500292319600 Job No. AKZZ2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 12998.40 19.970 340.560 6698.30 6749.40 9581.34 N 3477.41 W 6039180.48 N 554615.34 E 0.319 10192.86 13093.67 19.410 342.490 6788.00 6839.10 9611.78 N 3487.59 W 6039210.84 N 554604.92 E 0.901 10224.95 13186.54 17.950 343.060 6875.97 6927.07 9640.18 N 3496.41 W 6039239.18 N 554595.89 E 1.584 10254.66 13282.25 14.860 341.750 6967.78 7018.88 9665.95 N 3504.55 W 6039264.88 N 554587.54 E 3.251 10281.66 13379.14 11.350 342.660 7062.13 7113.23 9686.86 N 3511.28 W 6039285.73 N 554580.64 E 3.629 10303.61 e 13475.67 8.530 341.520 7157.20 7208.30 9702.72 N 3516.38 W 6039301.55 N 554575.42 E 2.928 10320.26 13570.82 7.440 341.820 7251.43 7302.53 9715.27 N 3520.54 W 6039314.07 N 554571.16 E 1.146 10333.47 13667.98 6.080 340.640 7347.91 7399.01 9726.10 N 3524.21 W 6039324.87 N 554567.41 E 1 .407 10344.90 13744.68 5.840 341.410 7424.19 7475.29 9733.63 N 3526.80 W 6039332.38 N 554564.76 E 0.330 10352.87 - 13817.00 5.840 341.410 7496.14 7547.24 9740.60 N 3529.15 W ~6039339.34 N - 554562.36 E 0.000 10360.22 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 340.070° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13817.00ft., The Bottom Hole Displacement is 10360.22ft., in the Direction of 340.084° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) e Comment 13817.00 7547.24 9740.60 N 3529.15 W Projected Survey 16 April, 2004 - 7:37 Page 60f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC . MPC-43 Your Ref: AP/S00292319600 Job No. AKZZ2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Survey too/program for MPC-43 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 632.00 0.00 632.00 629.49 13817.00 629.49 Tolerable Gyro 7547.24 AK-6 BP _IFR-AK e e 16 April, 2004 - 7:37 Page 70f7 Dri/lQuest 3.03.06.002 e e 17-Apr-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well MPC-43 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 0.00 I MD 0.00' MD 13,817.00' 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 Date ;2 ) ~ lø-ö y Signed 1LJ ð.~ Please call me at 273-3545 if you have any questions or concerns. Regards, Å ð C( -- D;, c( William T. Allen Survey Manager Attachment(s) Halliburton Sperry-Sun Milne Point Unit BPXA Milne Point MPC MPC-43 MWD e Job Ho. AKMW2979490, Surveyed: 6 April, 2004 Survey Report 16 April, 2004 Your Ref: API 500292319600 Surface Coordinates: 6029626.64 H, 558167.60 E (70· 29' 29.6060· H, 149· 31' 28.0736· W) Grid Coordinate System: HAD27 Alaska State Planes, Zone 4 e Surface Coordinates relative to Project H Reference: 1029626.64 H, 58167.60 E (Grid) Surface Coordinates relative to Structure Reference: 2278.00 H, 127.39 E (True) Kelly Bushing Elevation: 51. 10ft above Mean Sea Level Kelly Bushing E/evation: 51. 10ft above Project V Reference Kelly Bushing Elevation: 51. 10ft above Structure Reference spe..........y-su'ï! DRILLII\I.G Se¡RVICe¡S A Halliburton Company Survey Ref: svy1378 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 MWD Your Ref: AP/500292319600 Job No. AKMW2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-5ea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northin9s Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 0.00 0.000 0.000 -51.10 0.00 0.00 N 0.00 E 6029626.64 N 558167.60 E 0.00 Tolerable Gyro 81.00 0.600 51.000 29.90 81.00 0.27 N 0.33 E 6029626.91 N 558167.93 E 0.741 0.14 176.00 0.950 358.000 124.89 175.99 1.37 N 0.69 E 6029628.01 N 558168.28 E 0.799 1.05 267.00 2.600 322.000 215.85 266.95 3.75N 0.61 W 6029630.38 N 558166.96 E 2.104 3.73 355.00 4.800 306.000 303.66 354.76 7.49 N 4.82W 6029634.09 N 558162.72 E 2.738 8.68 e 446.00 6.500 298.000 394.22 445.32 12.14N 12.45 W 6029638.68 N 558155.06 E 2.054 15.66 539.00 8.400 295.000 486.43 537.53 17.48 N 23.25 W 6029643.94 N 558144.21 E 2.085 24.36 632.00 8.750 300.000 578.39 629.49 23.89 N 35.53 W 6029650.25 N 558131.88 E 0.885 34.57 MWD Magnetic 653.60 9.130 307.110 599.73 650.83 25.75 N 38.32 W 6029652.09 N 558129.08 E 5.405 37.27 756.62 11.340 322.550 701.12 752.22 38.72 N 51.00 W 6029664.96 N 558116.29 E 3.402 53.79 851.77 12.880 324.660 794.15 845.25 54.80 N 62.83 W 6029680.95 N 558104.35 E 1.684 72.94 947.28 13.870 329.790 887.07 938.17 73.38 N 74.75 W 6029699.43 N 558092.28 E 1.617 94.46 1037.82 15.880 323.580 974.58 1025.68 92.73 N 87.56 W 6029718.68 N 558079.32 E 2.831 117.02 1132.56 20.000 325.430 1064.69 1115.79 116.51 N 104.46 W 6029742.33 N 558062.23 E 4.390 145.14 1227.69 24.970 329.180 1152.57 1203.67 147.17 N 123.99 W 6029772.84 N 558042.46 E 5.435 180.62 1321.37 28.770 332.320 1236.12 1287.22 184.13 N 144.60 W 6029809.63 N 558021.56 E 4.329 222.39 1416.75 31.740 332.180 1318.50 1369.60 226.65 N 166.98 W 6029851.98 N 557998.86 E 3.115 270.00 1512.56 35.470 331.820 1398.29 1449.39 273.46 N 191.87W 6029898.59 N 557973.59 E 3.899 322.49 1603.78 39.850 330.900 1470.48 1521.58 322.35 N 218.60 W 6029947.27 N 557946.49 E 4.841 377.56 1699.87 44.860 339.230 1541.53 1592.63 381.02 N 245.63 W 6030005.73 N 557919.00 E 7.821 441.93 1793.51 43.890 324.300 1608.64 1659.74 438.42 N 276.37 W 6030062.89 N 557887.81 E 11.182 506.37 1886.88 43.470 331.260 1676.21 1727.31 492.90 N 310.72 W 6030117.09 N 557853.04 E 5.166 569.30 e 1979.30 44.300 338.780 1742.86 1793.96 550.90 N 337.70 W 6030174.88 N 557825.60 E 5.709 633.02 2069.87 46.650 336.000 1806.38 1857.48 610.48 N 362.55 W 6030234.27 N 557800.28 E 3.394 697.50 2165.35 52.390 336.620 1868.33 1919.43 676.97 N 391.70 W 6030300.52 N 557770.61 E 6.032 769.94 2259.03 55.270 335.510 1923.62 1974.72 746.07 N 422.39 W 6030369.39 N 557739.38 E 3.220 845.37 2354.52 58.910 333.510 1975.49 2026.59 818.41 N 456.91 W 6030441 .45 N 557704.30 E 4.198 925.14 2450.34 63.160 333.430 2021.89 2072.99 893.40 N 494.35 W 6030516.14 N 557666.28 E 4.436 1008.40 2541.74 64.260 336.700 2062.38 2113.48 967.69 N 528.88 W 6030590.17 N 557631.17 E 3.426 1090.02 2633.18 66.500 337.740 2100.47 2151.57 1044.33 N 561.06 W 6030666.55 N 557598.39 E 2.659 1173.03 2729.16 69.120 340.960 2136.72 2187.82 1127.48 N 592.37 W 6030749.45 N 557566.43 E 4.135 1261.88 2820.77 69.030 342.320 2169.44 2220.54 1208.69 N 619.32 W 6030830.45 N 557538.84 E 1.390 1347.41 2916.14 68.710 342.680 2203.82 2254.92 1293.53 N 646.07 W 6030915.08 N 557511.43 E 0.486 1436.29 3009.05 68.720 343.070 2237.55 2288.65 1376.26 N 671.56 W 6030997.61 N 557485.29 E 0.391 1522.76 3103.10 68.790 343.400 2271.63 2322.73 1460.20 N 696.85 W 6031081.34 N 557459.35 E 0.335 1610.28 16 April, 2004 - 7:32 Page 20f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 MWD Your Ref: AP/500292319600 Job No. AKMW2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northin9s Eastin9s Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 3197.53 68.860 343.640 2305.74 2356.84 1544.63 N 721.83 W 6031165.58 N 557433.71 E 0.248 1698.18 3291.68 68.780 344.110 2339.76 2390.86 1628.97 N 746.21 W 6031249.72 N 557408.67 E 0.473 1785.77 3385.96 67.840 342.400 2374.60 2425.70 1712.86N 771.44 W 6031333.41 N 557382.78 E 1.958 1873.24 3480.25 68.970 340.080 2409.31 2460.41 1795.86 N 799.64 W 6031416.19 N 557353.93 E 2.583 1960.88 3574.61 69.430 339.640 2442.82 2493.92 1878.67 N 830.02 W 6031498.76 N 557322.91 E 0.654 2049.09 e 3666.13 69.490 339.480 2474.93 2526.03 1958.98 N 859.94 W 6031578.83 N 557292.36 E 0.176 2134.79 3760.73 68.840 339.550 2508.57 2559.67 2041.80 N 890.89 W 6031661.41 N 557260.77 E 0.691 2223.20 3854.10 68.780 339.870 2542.32 2593.42 2123.46 N 921.07 W 6031742.83 N 557229.94 E 0.326 2310.25 3948.96 67.910 339.960 2577.33 2628.43 2206.26 N 951.35 W 6031825.39 N 557199.02 E 0.921 2398.42 4043.48 68.040 339.800 2612.77 2663.87 2288.53 N 981.49 W 6031907.43 N 557168.23 E 0.209 2486.04 4136.93 67.240 340.600 2648.33 2699.43 2369.85 N 1010.77 W 6031988.51 N 557138.32 E 1.166 2572.46 4230.67 66.310 340.280 2685.29 2736.39 2451.02 N 1039.61 W 6032069.45 N 557108.85 E 1.041 2658.60 4315.91 66.510 340.660 2719.40 2770.50 2524.64 N 1065.72 W 6032142.87 N 557082.16 E 0.471 2736.71 4420.90 67.590 341.530 2760.34 2811.44 2616.10N 1097.04 W 6032234.08 N 557050.12 E 1.281 2833.38 4515.63 67.310 342.230 2796.67 2847.77 2699.25 N 1124.25 W 6032317.01 N 557022.27 E 0.744 2920.82 4608.11 66.770 344.010 2832.75 2883.85 2780.73 N 1148.98 W 6032398.30 N 556996.90 E 1.866 3005.85 4701.73 66.860 342.300 2869.61 2920.71 2863.09 N 1173.92W 6032480.46 N 556971.32 E 1.682 3091 .78 4795.27 65.850 342.050 2907.12 2958.22 2944.67 N 1200.15 W 6032561.83 N 556944.45 E 1.107 3177.41 4887.86 66.850 342.130 2944.27 2995.37 3025.37 N 1226.23 W 6032642.32 N 556917.74 E 1.083 3262.17 4981.60 65.840 341.790 2981.88 3032.98 3107.01 N 1252.82 W 6032723.75 N 556890.52 E 1.128 3347.98 5077.23 67.970 340.620 3019.39 3070.49 3190.28 N 1281.16 W 6032806.80 N 556861.52 E 2.495 3435.92 5171.03 67.850 341.130 3054.66 3105.76 3272.39 N 1309.64 W 6032888.69 N 556832.40 E 0.520 3522.83 e 5265.31 67.760 341.930 3090.28 3141.38 3355.19 N 1337.29 W 6032971.27 N 556804.10 E 0.791 3610.09 5360.25 68.240 340.800 3125.84 3176.94 3438.60 N 1365.42 W 6033054.45 N 556775.32 E 1.214 3698.10 5453.30 69.290 340.770 3159.55 3210.65 3520.50 N 1393.97 W 6033136.13 N 556746.13 E 1.129 3784.82 5548.21 67.570 340.870 3194.44 3245.54 3603.86 N 1422.96 W 6033219.26 N 556716.49 E 1.815 3873.07 5647.74 67.060 342.290 3232.82 3283.92 3690.98 N 1451.98 W 6033306.15 N 556686.79 E 1.413 3964.87 5741.69 65.700 343.010 3270.47 3321.57 3773.14 N 1477.65 W 6033388.11 N 556660.48 E 1.609 4050.86 5835.85 65.030 342.890 3309.71 3360.81 3854.97 N 1502.75 W 6033469.73 N 556634.74 E 0.721 4136.34 5929.74 65.420 342.900 3349.06 3400.16 3936.45 N 1527.82 W 6033551.01 N 556609.03 E 0.415 4221.48 6023.30 66.170 343.060 3387.42 3438.52 4018.04 N 1552.80 W 6033632.41 N 556583.42 E 0.817 4306.71 6118.86 66.500 342.460 3425.78 3476.88 4101.63N 1578.74 W 6033715.80 N 556556.82 E 0.671 4394.13 6212.20 66.970 342.790 3462.64 3513.74 4183.47 N 1604.35 W 6033797.43 N 556530.58 E 0.599 4479.80 6306.72 68.720 342.510 3498.29 3549.39 4267.03 N 1630.45 W 6033880.78 N 556503.82 E 1.872 4567.25 6400.34 68.440 342.200 3532.48 3583.58 4350.08 N 1656.87 W 6033963.62 N 556476.75 E 0.429 4654.33 16 April, 2004 - 7:32 Page 3 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 MWD Your Ref: API 500292319600 Job No. AKMW2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 6494.10 67.240 341.650 3567.84 3618.94 4432.63 N 1683.81 W 6034045.96 N 556449.17 E 1.390 4741.12 6589.12 65.690 343.230 3605.79 3656.89 4515.67 N 1710.10 W 6034128.80 N 556422.23 E 2.233 4828.15 6685.01 65.560 342.450 3645.36 3696.46 4599.13 N 1735.86 W 6034212.05 N 556395.81 E 0.753 4915.39 6778.67 67.050 341.910 3683.00 3734.10 4680.77 N 1762.11 W 6034293.49 N 556368.92 E 1.676 5001.10 6870.16 68.450 339.750 3717.64 3768.74 4760.75 N 1789.92 W 6034373.24 N 556340.49 E 2.668 5085.76 e 6964.47 68.910 339.250 3751.93 3803.03 4843.04 N 1820.69 W 6034455.29 N 556309.08 E 0.694 5173.61 7057.03 69.830 339.580 3784.55 3835.65 4924.13 N 1851.15 W 6034536.14 N 556277.99 E 1.048 5260.23 7155.56 68.780 340.210 3819.37 3870.47 5010.68 N 1882.83 W 6034622.44 N 556245.63 E 1.222 5352.40 7247.79 67.460 340.330 3853.74 3904.84 5091.24 N 1911.72W 6034702.77 N 556216.11 E 1.436 5437.98 7342.85 66.710 341.190 3890.75 3941.85 5173.91 N 1940.58 W 6034785.21 N 556186.61 E 1.148 5525.53 7437.55 65.920 341.190 3928.79 3979.89 5256.00 N 1968.54 W 6034867.08 N 556158.00 E 0.834 5612.24 7531.21 69.250 342.830 3964.50 4015.60 5338.34 N 1995.26 W 6034949.21 N 556130.64 E 3.906 5698.75 7626.71 68.320 343.470 3999.06 4050.16 5423.54 N 2021.07 W 6035034.21 N 556104.16 E 1.157 5787.65 7721.08 66.790 342.970 4035.09 4086.19 5507.05 N 2046.25 W 6035117.51 N 556078.33 E 1.694 5874.74 7812.60 68.190 343.920 4070.13 4121.23 5588.09 N 2070.33 W 6035198.36 N 556053.61 E 1.805 5959.14 7905.31 68.630 344.280 4104.24 4155.34 5671.00 N 2093.95 W 6035281.08 N 556029.35 E 0.596 6045.13 7999.71 68.130 344.210 4139.02 4190.12 5755.46 N 2117.78 W 6035365.35 N 556004.86 E 0.534 6132.65 8094.89 66.580 344.320 4175.67 4226.77 5840.01 N 2141.60W 6035449.71 N 555980.38 E 1.632 6220.26 8189.23 66.700 342.810 4213.07 4264.17 5923.07 N 2166.10 W 6035532.58 N 555955.23 E 1.4 75 6306.70 8283.96 66.570 343.220 4250.64 4301.74 6006.24 N 2191.51 W 6035615.55 N 555929.17 E 0.420 6393.55 8378.54 66.720 340.960 4288.14 4339.24 6088.85 N 2218.21 W 6035697.96 N 555901.83 E 2.199 6480.32 8474.22 65.840 341.940 4326.63 4377.73 6171.90 N 2246.08 W 6035780.78 N 555873.31 E 1.313 6567.89 e 8567.98 65.440 340.630 4365.31 4416.41 6252.79 N 2273.48 W 6035861.46 N 555845.27 E 1.342 6653.28 8664.02 64.950 340.340 4405.60 4456.70 6334.96 N 2302.60 W 6035943.40 N 555815.51 E 0.579 6740.45 8756.32 63.670 341 .280 4445.61 4496.71 6413.51 N 2329.94 W 6036021.73 N 555787.55 E 1.663 6823.62 8851.08 64.810 340.620 4486.79 4537.89 6494.18 N 2357.80 W 6036102.18 N 555759.07 E 1.357 6908.95 8945.14 66.430 341.190 4525.62 4576.72 6575.14 N 2385.82 W 6036182.91 N 555730.41 E 1.809 6994.61 9037.53 67.120 341.700 4562.05 4613.15 6655.63 N 2412.84 W 6036263.19 N 555702.77 E 0.903 7079.49 9130.41 67.500 340.870 4597.88 4648.98 6736.79 N 2440.34 W 6036344.13 N 555674.64 E 0.920 7165.16 9220.27 68.500 340.720 4631.54 4682.64 6815.46 N 2467.74 W 6036422.59 N 555646.61 E 1.124 7248.47 9317.38 67.920 340.070 4667.59 4718.69 6900.41 N 2498.00 W 6036507.29 N 555615.70 E 0.862 7338.64 9417.51 65.690 341.680 4707.03 4758.13 6987.35 N 2528.16W 6036594.00 N 555584.86 E 2.673 7430.66 9511.35 66.560 341.910 4745.01 4796.11 7068.87 N 2554.97 W 6036675.30 N 555557.41 E 0.954 7516.43 9605.34 68.580 340.000 4780.87 4831.97 7150.98 N 2583.32 W 6036757.19 N 555528.41 E 2.854 7603.29 9700.03 68.530 339.670 4815.49 4866.59 7233.71 N 2613.70 W 6036839.68 N 555497.39 E 0.329 7691.42 16 April, 2004 - 7:32 Page 4 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 MWD Your Ref: API 500292319600 Job No. AKMW2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 9794.61 67.930 339.210 4850.57 4901.67 7315.95 N 2644.55 W 6036921.68 N 555465.90 E 0.779 7779.25 9890.54 68.450 338.920 4886.21 4937.31 7399.13 N 2676.37 W 6037004.61 N 555433.42 E 0.610 7868.30 9981.79 67.640 341.070 4920.33 4971.43 7478.65 N 2705.33 W 6037083.90 N 555403.85 E 2.359 7952.92 10074.96 67.440 342.020 4955.92 5007.02 7560.32 N 2732.58 W 6037165.35 N 555375.95 E 0.966 8039.00 10169.75 67.660 342.410 4992.12 5043.22 7643.74 N 2759.34 W 6037248.56 N 555348.54 E 0.445 8126.54 e 10261.98 67.780 345.160 5027.09 5078.19 7725.68 N 2783.17 W 6037330.31 N 555324.07 E 2.762 8211.69 10355.83 67.250 343.490 5062.99 5114.09 7809.17 N 2806.60 W 6037413.61 N 555300.00 E 1.738 8298.17 10447.91 66.910 342.500 5098.85 5149.95 7890.27 N 2831.40 W 6037494.52 N 555274.56 E 1.057 8382.86 10543.34 66.900 344.870 5136.29 5187.39 7974.51 N 2856.06 W 6037578.56 N 555249.25 E 2.284 8470.46 10637.76 66.050 343.390 5173.98 5225.08 8057.78 N 2879.73 W 6037661.64 N 555224.93 E 1.696 8556.81 10732.18 66.930 343.220 5211.64 5262.74 8140.71 N 2904.60 W 6037744.38 N 555199.40 E 0.947 8643.26 10827.81 66.780 341.640 5249.23 5300.33 8224.54 N 2931.14 W 6037828.00 N 555172.21 E 1.527 8731.11 10921.70 67.380 343.130 5285.80 5336.90 8306.96 N 2957.31 W 6037910.21 N 555145.40 E 1.595 8817.52 11013.88 67.180 342.380 5321.40 5372.50 8388.16 N 2982.51 W 6037991.21 N 555119.56 E 0.781 8902.45 11106.96 67.990 342.120 5356.89 5407.99 8470.11 N 3008.75 W 6038072.96 N 555092.68 E 0.908 8988.43 11201.81 67.850 342.930 5392.55 5443.65 8553.95 N 3035.14 W 6038156.58 N 555065.63 E 0.805 9076.24 11297.10 67.380 342.260 5428.84 5479.94 8638.02 N 3061.49 W 6038240.45 N 555038.62 E 0.816 9164.27 11390.93 66.990 342.420 5465.22 5516.32 8720.44 N 3087.73 W 6038322.65 N 555011.74 E 0.444 9250.69 11485.35 64.340 340.500 5504.13 5555.23 8801.99 N 3115.07W 6038404.00 N 554983.77 E 3.363 9336.68 11579.84 61.570 339.770 5547.09 5598.19 8881.14 N 3143.66 W 6038482.91 N 554954.56 E 3.011 9420.83 11673.43 56.250 339.410 5595.40 5646.50 8956.23 N 3171.59 W 6038557.78 N 554926.04 E 5.694 9500.94 11769.04 50.690 340.890 5652.29 5703.39 9028.45 N 3197.70 W 6038629.79 N 554899.37 E 5.947 9577.74 e 11864.11 46.840 340.490 5714.94 5766.04 9095.91 N 3221.33 W 6038697.07 N 554875.21 E 4.062 9649.21 11956.50 43.270 341.520 5780.20 5831.30 9157.72 N 3242.63 W 6038758.71 N 554853.43 E 3.944 9714.58 12050.94 38.790 340.620 5851.43 5902.53 9216.36 N 3262.71 W 6038817.19 N 554832.89 E 4.785 9776.55 12144.55 35.260 341.270 5926.15 5977.25 9269.62 N 3281.13 W 6038870.31 N 554814.06 E 3.794 9832.91 12237.86 31.710 341.960 6003.96 6055.06 9318.46 N 3297.37 W 6038919.02 N 554797.43 E 3.826 9884.36 12332.25 28.340 341.140 6085.67 6136.77 9363.26 N 3312.30 W 6038963.70 N 554782.15 E 3.597 9931.57 12421.54 26.400 341.670 6164.96 6216.06 9402.17 N 3325.40 W 6039002.50 N 554768.75 E 2.190 9972.60 12512.25 24.000 343.720 6247.04 6298.14 9439.02 N 3336.91 W 6039039.27 N 554756.95 E 2.815 10011.18 12606.58 23.040 342.540 6333.53 6384.63 9475.05 N 3347.83 W 6039075.21 N 554745.75 E 1.134 10048.77 12701.47 22.430 342.480 6421.05 6472.15 9510.02 N 3358.85 W 6039110.10 N 554734.45 E 0.643 10085.40 12793.78 21.270 339.690 6506.73 6557.83 9542.52 N 3369.96 W 6039142.51 N 554723.09 E 1.686 10119.74 12827.53 21.050 339.130 6538.20 6589.30 9553.93 N 3374.25 W 6039153.88 N 554718.71 E 0.885 10131.93 12903.50 19.870 339.900 6609.38 6660.48 9578.80 N 3383.55 W 6039178.68 N 554709.22 E 1.593 10158.48 16 April, 2004 - 7:32 Page 50f7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 MWD Your Ref: API 500292319600 Job No. AKMW2979490, Surveyed: 6 April, 2004 BPXA Milne Point Unit Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 12998.40 19.970 340.740 6698.60 6749.70 9609.24 N 3394.43 W 6039209.03 N 554698.10 E 0.319 10190.81 13093.67 19.410 342.700 6788.30 6839.40 9639.72 N 3404.51 W 6039239.43 N 554687.78 E 0.909 10222.89 13186.54 17.950 343.480 6876.27 6927.37 9668.17 N 3413.17 W 6039267.81 N 554678.90 E 1.595 10252.60 13282.25 14.860 342.640 6968.08 7019.18 9694.03 N 3421.02 W 6039293.61 N 554670.84 E 3.238 10279.58 13379.14 11.350 342.680 7062.43 7113.53 9715.00 N 3427.57 W 6039314.53 N 554664.13 E 3.623 10301.53 e 13475.67 8.530 341.640 7157.50 7208.60 9730.86 N 3432.66 W 6039330.35 N 554658.92 E 2.927 10318.18 13570.82 7.440 341.990 7251.73 7302.83 9743.42 N 3436.78 W 6039342.88 N 554654.70 E 1.147 10331.39 13667.98 6.080 340.510 7348.21 7399.31 9754.25 N 3440.44 W 6039353.68 N 554650.95 E 1.411 10342.82 13744.68 5.840 341.460 7424.49 7475.59 9761.78 N 3443.04 W 6039361.19 N 554648.30 E 0.338 10350.78 13817.00 5.840 341.460 7496.44 7547.54 9768.76 N 3445.38 W 6039368.15 N 554645.90 E 0.000 10358.14 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 340.070· (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13817.0Oft., The Bottom Hole Displacement is 10358.54ft., in the Direction of 340.573° (True). Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) e Comment 13817.00 7547.54 9768.76 N 3445.38 W Projected Survey 16 April, 2004 - 7:32 Page 6 of 7 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for Milne Point MPC - MPC-43 MWD Your Ref: API 500292319600 Job No. AKMW2979490, Surveyed: 6 April, 2004 ". BPXA Milne Point Unit Survey tool program for MPC-43 MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 632.00 0.00 632.00 629.49 13817.00 629.49 Tolerable Gyro 7547.54 MWD Magnetic e e 16 April, 2004 - 7:32 Page 70f7 DrilIQuest~0~0~002 e . dt!f1'6~~,~,,~ /26-78" WELL LOG TRANSMfITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 June 01, 2004 RE: MWD FOImation Evaluation Logs MPC-43, AK-MW-2979490 1 LIS fonnatted Disc with verification listing. ~I#: 50~29-23200~0 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99649-6612 DmeÞ/:ft( RECEIVED I' .. , () 0 f"ll\ut\4 ,r..':; U 7 tv ' i\.I~sk8 Oíí & Gas Cons. Commissior l"m~OI'age . íñìn· . l~ . FRANK H. MURKOWSKI, GOVERNOR AI,ASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Matt Green Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Milne Point MPC-43 BP Exploration (Alaska) Inc. Permit No: 204-039 Surface Location: 1344' NSL, 2290' WEL, SEC. 10, T13N, RlOE, UM Bottomhole Location: 401' NSL, 481' WEL, SEC.33, T14N, R10E, UM Dear Mr. Green: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you ITom obtaining additional permits or approvals required by law ftom 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 erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 9 607 (pager). BY ORDER!}F THE COMMISSION DATED this~ day of March, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. III Drill 0 Redrill 1 a. 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: 1344' NSL, 2290' WEL, SEC. 10, T13N, R10E, UM'/ Top of Productive Horizon: 401' NSL, 481' WEL, SEC. 33, T14N, R10E, UM Total Depth: 401' NSL, 481' WEL, SEC. 33, T14N, R10E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-558168' y-6029627' Zone-ASP4'/ 16. Deviated Wells: Kickoff Depth 18.· C¡:¡singProgram Size Casing 20" 10-3/4" 7-518" 4-1/2" ALASKAtL AND ~:~~g~S~~'::¡ON CO!ISSlof$ CEI PERMIT TO DRILL FEB24 2004 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test 0 Service 5. Bond: IBI Blanket 0 Single Well Bond No. 2S100302630-277 . 6. Proposed Depth: MD 13784' . TVD 7526" 7. Property Designation: ADL 355017 ,/ k 3{, 8~iv~'ð~~~n\;ð~ Gtj;M&I~gl~~6~!~n o Developmef\'t¡"ror QiSingle Zone 11. Well Name and Number: MPC-43 12. Field / Pool(s): Milne Point Unit I Kuparuk River Sands 8. Land Use Permit: 300' ft Maximum Hole Angle 13. Approximate Spud Date: 03/10/04 9. Acres in Property: 14. Distance to Nearest Property: ..25ê6" 'N~ Ai> 5780' 10. KB Elevation 15. Distance to Nearest Well Within Pool (Height above GL): Plann;1~BE = feet 1960' away from MPC-19 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4346 psig Surface: 3649 psig 67° Hole 42" 13-112" 9-7/8" 6-3/4" Weight 92# 45.5# 29.7# 12.6# Grade H-40 L-80 L-80 L-80 Coupling Weld BTC-M BTC-M BTC-M Length MD TVD MD TVD (including stage data) 122' Surface Surface 122' 122' 260 sx Arctic Set (Approx.) 9275' Surface Surface 9275' 4701' 1273 sx Arctic Set III, 259 sx 'G' 12906' Surface Surface 12906' 6651' 141 sx Class 'G' 984' 12800' 6549' 13784' 7526' 159 sx Class 'G' PRESENT WELL CONDITION SUMMARY (To be completed for Redrill AND Re-entry Operations) ,Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): I Effective Depth MD (ft): Depth TVD Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments IBI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth TVD (ft): IBI Drilling Program 0 Time vs Depth Plot o Seabed Report IBI Drilling Fluid Program o Shallow Hazard Analysis IBI 20 AAC 25.050 Requirements Date: Contact Matt Green, 564-5581 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 Name Matt Title Drilling Engineer Phone Permit Approval IÁ 'IJ Date: 'j 0 Mud Log Required Directional Survey Required I See cover letter for other requirements DYes ,ØNo ]:)?Yes 0 No Permit To Drill . / Q API Number: .., ~ Number: 2ð't-03-f 50-02..e; - 23~ -C:iJ Conditions of Approval: Samples Required 0 Yes ~o Hydrogen ulfide Measures ~Y es 0 No ORIGINAl BY ORDER OF THE COMMISSION Dme ~ite . . MPC-43 Well Program IWell Name: IMPC-43 Drill and Complete Plan Summary I Type of Well (service I producer I injector): I Producer ,/ Surface Location: 3935' FNL, (1344' FSL)," 2290' FEL; (2989' FWL), SEC. 10, T13N,R1 OE E=558167.60 N=6029626.64 +-V"Y';ftc.';./ 4 7. #LJ6¿4 Z·l.5'.t>'¡ .4Þ 4878' FNL, (401' FSL), 481' FEL, (4798' FWL), SEC. 33, T14N, R10E E=554605 N=6039215 Z=7215-ft TVDss 4878' FNL, (401' FSL), 481' FEL, (4798' FWL), SEC. 33, T14N, R10E E=554605 N=6039215 Z=7475-ft TVDss Target Location: Top A-Sand Target Location: BHL Well TD I AFE Number: 1 I Estimated Start Date: 110 Mar 2004 "bíffe....-, J.:J If'" +~" K ¥~ '" ¿'" inl?'-- dll""e.qf¡';"¿f I . $eA "''''e.;j' þl> I Rig: 1 Doyon 14 I Operating days to complete: 118.0 I MD: 113,784 1 rTVD: 17,526 1 I Max Inc: 167 I I KOP: 1300 I I KBE:151.0 I Well Design (conventional, slim hole, etc.): 1 Conventional Fractured Producer I Objective: I Kuparuk A-Sand Mud Program: 13.5-in Surface Hole Mud Properties: Density (ppg) Funnel Vis YP I HTHP 8.6 - 9.5 75 -150 25 - 60 N/A 9.875-in Intermediate Hole Mud Properties: Density (ppg) PV I YP I HTHP 9.0-9.4 10-20 22-28 N/A 6.75-in Production Hole 1 Mud Properties: Density (ppg) PV YP HTHP 9.8 - 10.2 10 - 20 22 - 28 N/A Spud - LSND Freshwater Mud pH API Fi Itrate I LG Solids 9.0-9.5 < 12 < 15 LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 4.75-in Production Hole 2 Mud Properties: Density (ppg) PV YP HTHP 12.4 - 12.6 10 - 20 22 - 28 N/A LCM Restrictions: None. Waste Disposal: NO ANNULAR INJECTION. Drill Cuttings taken to DS-4 disposal site Call the Pad 4 waste disposal site prior to truck leaving location so the site can be ready to unload waste. Exempt liquid wastes can be taken to DS-4 or Phillips KRU 1 R. Version 1.0 23 Feb 2004 LSND Freshwater Mud pH API Filtrate LG Solids 9.0 - 9.5 < 8 < 12 . . MPC-43 Permit Casin~ Size 110-3/4" 45.5-lb/ft L-80 BTC-M Surface Casing First Stage Basis 40% Excess for Tail Slurry, Gauge hole below To ES Cementer (-1900') for Lead Slurry Total Cement Volume: 668-bbl Wash 20-bbl water Spacer 40-bbl 1 0.2-lb/gal Alpha Spacer Lead 615-bbl, 806-sx 10.7Ib/gal ArcticSetLight 3 - 4.45 ft;;/sx Tal 53-bbl, 259-sx 15.8 Ib/gal Prem G - 1.17 ft;;/sx I (top of tail at -8,775-ft MD) CasinQ Size 110-3/4" 45.5-lb/ft L-80 BTC-M Surface Casing - Second Stage Basis 1175% excess over gauge hole in permafrost interval Total Cement \ t Volume: 356-bbl Wash 20-bbl water ~~.\cò\. ~ "à-aOQ Spacer 40-bbl 10.2-lb/gal Alpha Spacer Lead 356-bbl, 467-sx 10.7Ib/gal ArcticSetLight 3 - 4.45 ft;;/sx (cement to surface) Casin~ Size 17-5/8" 29.7-lb/ft L-80 BTC-M Intermediate Casing Ba· Top of tail cement 500-ft above Shoe. 40% excess over gauge. SIS Total Cement Volume: 31-bbl Wash 10-bbl water Spacer 20-bbl 10.2-lb/gal MudPush II Spacer Tail 31-bbl, 141-sx 15.8Ib/gal Prem G -1.17 fe/sx (top of tail at 7S't&-tt MD) 4..U A.f\ J. \ 'à40 b JŒi; fYVf CasinQ Size 14-1/2" 12.6-lb/ft L-80 ST-L Drilling Liner Basis 140% Excess in Open Hole, Liner Lap + 200' above Liner Top in Annulus Total Cement Volume: 31-bbl Wash 10-bbl water Spacer 1 0-bbI13.5-lb/gal MudPush II Spacer Tail 31-bbl, 141-sx 15.8 Ib/gal Prem G - 1.16 fe/sx CasinQ Size 15-1/2" 17-lb/ft L-80 ST-L Drilling Liner - Contingency Basis 140% Excess in Open Hole, Liner Lap + 200' above Liner Top in Annulus Total Cement Wash 10-bbl water Volume: 33-bbl Spacer 1 0-bbI13.5-lb/gal MudPush II Spacer Tail 33-bbl, 159-sx 15.8 Ib/gal Prem G - 1.16 fe/sx 2 Version 1.0 23 Feb 2004 . . MPC-43 Permit Casin~ Size 13-1/2" 9.2 Ibltt L-80 BTC Production Liner - Contingency Basis 140% Excess in Open Hole, Liner Lap + 200' above Liner Top in Annulus Total Cement Volume: 19-bbl Wash 5-bbl water Spacer Lead Temp 5-bbl 1 0.2-lb/gal Alpha Spacer (Alpha) 19-bbl, 86-sx 15.8 Ib/gal Prem G - 1.16 fe/sx BHST ::=175°F from SOR Evaluation Program: 13.5-in Section Open Hole: MWD/GR IFRlCASANDRA Cased Hole: N/A 9.875-in Section Open Hole: MWD/GRlRES I FRlCASANDRA Cased Hole: N/A 6.75-in Section Open Hole: MWD/GRlRES GR at bit IFRlCASANDRA Cased Hole: N/ A 4.75-in Section Open Hole: MWD/GRlRES I FRlCASANDRA Cased Hole: SCMT Formation Markers: Formation Tops MDrkb TVDrkb Pore Pressure Estimated EMW (ft) (ft) (psi) (Ib/gal)* BPRF 1942 1751 738 8.35 TUZC 6929 3791 1624 8.35 SBF2-NA 8115 4251 1824 8.35 SBA5 8760 4501 1932 8.35 THRZ 13028 6771 2918 8.35 BHRZ 13078 6821 2940 8.35 KLGM 13139 6881 4262 12.0 / TKUD 13274 7016 4346 12.0 3 Version 1.0 23 Feb 2004 . . MPC-43 Permit TKUC 13424 7166 4440 12.0 TKUB 13429 7171 4443 12.0 TKUA 13524 7266 4502 12.0 TKA3 13529 7271 4505 12.0 TKA2 13549 7291 4518 12.0 TKA1 13584 7326 4540 12.0 TMLV 13634 7376 4571 12.0 / CasinglTubing Program: Hole Csg Diam WtlFt Grade Conn Burst Collapse Length Top Bottom Size MDfTVDrkb MDfTVDrkb 42-in 20-in* 92 H-40 Weld 1530 520 122-ft 0 122-ft/ 122-ft 13.5-in 10.75-in 45.5 L-80 BTC-M 5210 2480 9,275-ft 0 9,275-ft / 4,701-ft 9.875-in 7.625-in 29.7 L-80 BTC-M 6890 4790 12,906-ft 0 12,906-ft / 6,651-ft 6.75-in 4.5-in 12.6 L-80 BTC-M 8440 7500 984-ft 12,800-ft 13,784-ft/ 7,526-ft 6.75-in 5.5-in 17.0 L-80 ST-L 7740 6280 320-ft 12,800-ft 13,120-ft / Contingency 6,861-ft 4.75-in 3.5-in 9.2 L-80 ST-L 10160 10530 1,084-ft 12,700-ft 13,784-ft/ Contingency 7,526-ft *The 20-in casing is NOT insulated Recommended Bit Program: BHA Hole Size Depth (MD) Bit Type Nozzle/Flow rate 1 13.5-in o - 4,500-ft Hughes 3-15's & 1-10 MX-C1 2 13.5-in 4,500 - 9,275-ft Hughes 3-15's & 1-10 MX-C1 3 9.875-in 9,275 - 12,906-ft ??? ??? ,/ 500 - 650-gpm 4 6.75-in 12,906 - 13, 120-ft ??? ??? 5 4.75-in 13, 120-ft - 13,784-ft ??? ??? Contingency 4 Version 1.0 23 Feb 2004 . Well Control: Surface Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance and integrity Planned BOP test pressure Casing Test Pressure (10.75-in) Intermediate Interval BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance and integrity Planned BOP test pressure Casing Test Pressure (7.625-in) Production Interval 1 BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance and integrity Planned BOP test pressure Liner Test Pressure (5.5-in) Production Interval 2 BOPE Maximum anticipated BHP Maximum surface pressure Kick tolerance and integrity Planned BOP test pressure Liner Test Pressure (3.5-in) Planned completion fluids . MPC-43 Permit 21.25-in Diverter 1 ,824-psi (8.35-lb/gal @ 4,200-ft TVD - top NA-sand) 1,404-psi (O.1-psi/ft gas gradient to surface) Will be drilled on diverter. Diverter will be function tested. 2,500-psi 13-3/8", 5M, Double ram with annular (Hydril - GL) 2,918-psi (8.35-lb/gal @ 6,720-ft TVD - THRZ) 2,246-psi (O.1-psi/ft gas gradient to surface) Infinite with 9.0-lb/gal mud, 11.5-lb/gal FIT at 10. 75-in casing and 150-psi surface pressure safety factor. Rams test to ~si/250-psi. f f""':!.Mt / Annular test to 2,500-psi/250-psi \..\SOE:J kJj.: 'V-( 4,500-psi 13-3/8", 5M, Double ram with annular (Hydril- GL) 2,966-psi (8.35-lb/gal @ 6,830-ft TVD - KLGM) 2,282-psi (O.1-psi/ft gas gradient to surface) Infinite with 10.0-lb/gal mud, 13.8-lb/gal FIT at 7.625-in casing and 150-psi surface pressure safety factor. Rams test to 3;SQQ:psi/250-psi. #f>.41I/J Annular test to 2,500-psi/250-psi '-l50é) ~'II"( 4,500-psi 13-3/8", 5M, Double ram with annular (Hydril - GL) 4,346-psi (12.0-lb/gal @ 6,965-ft TVD - TKUD) ./ 3,649-psi (O.1-psi/ft gas gradient to surface) ./ Infinite with 12.5-lb/gal mud, 13.8-lb/gal FIT at 5.5-in liner and 150-psi surface pressure safety factor. Rams test to ~250-psi. . --'CY::J ~ Annular test to 2,500-psi/250-psi "i. ~ ?S \, 4,500-psi 8.6-lb/gal seawater & 6.8-lb/gal diesel completion fluid 5 Version 1.0 23 Feb 2004 . . MPC-43 Permit Drilling Hazards & Contingencies: Hydrates · No drilling problems related to the hydrates were reported. / · Watch for deeper gravels below the Permafrost or gravels that calve off within the permafrost and will tend to drop out when the aerated hydrate gas cut mud is being circulated out. Maintain adequate viscosity. In the past several Milne Pt wells have experienced stuck pipe from this situation. Lost Circulation · Lost circulation is a possibility if the production hole open-hole LOT does not reach 13.8-lb/gal. In that event, a contingent liner will be run. · Offset wells encountered losses while running and cementing casing and only one well had losses while running a hole opener. Follow the LOST CIRCULATION DECISION MATRIX in the well plan if fluid losses occur while drilling. Break circulation slowly in all instances and get up to recommended circulating rate slowly prior to cementing. Expected Pressures · It is unlikely that there will be unexpected overpressure when drilling to the Schrader Bluff formation. Pressure is expected to be (8.35 Ib/gal EMW). In this well, the Schrader Bluff formation will be drilled with 9.3-lb/gal mud. / · Overpressure is not expected to the first intermediate casing point (7.625-in) in the/ Colville above the HRZ silts. Estimated pore pressures are 8.35-lb/gal EMW. · Overpressure up to 12.0-lb/gal is expected in the production interval. An open-hole / FIT to 13.8-lb/gal is planned just above the Kalubik. If it fails, then a contingent liner will ,/ be set at that point, then drill to TO with 12.5-lb/gal mud. If the FIT is successful, then the mud density will be increased to 12.5-lb/gal then drill to TO. _..~..---~-~.~".~ Pad Data Sheet ~, · Please Read the C-Pad Data Sheet thoroughly. Breathing · Low probability if ECD < 11.5-lb/gal in the Colville section. Hydrocarbons · Hydrocarbons will be encountered in the Ugnu through the Schrader Bluff. Faults · One fault is expected in the Colville at 13,1 OO-ft. 6 Version 1.0 23 Feb 2004 . . MPC-43 Permit Hydrogen Sulfide · MPC Pad is not designated as an H2S Pad. C-Pad wells <10-ppm H2S on the 2004 / report. Anti-collision Issues . MPC-43 passes the Major Risk Criteria. Distance to Nearest Property · MPC-43 is 5,780-ft from the nearest Milne Point property line. .I Distance to Nearest Well Within Pool · MPC-43 is 1 ,960-ft from the Kuparuk sand penetration in MPC-19. .I 7 Version 1.0 23 Feb 2004 . . MPC-43 Permit DRILL & COMPLETION PROCEDURE Pre-Rig Operations 1. Install starting head on 20-in conductor. Drilling 1. MIRU Doyon 14, NU diverter. 2. Drill 13.5-in hole to surface casing point as per directional plan. 3. Rig up and run 10.75-in casing and cement in place. 4. NO diverter. NU BOPE. 5. Drill 9.875-in hole to interval TO as per directional plan. 6. Rig up and run 7.625-in casing and cement in place. 7. Drill to 6.75-in hole to just above Kalubik as per directional plan. 8. Perform open hole FIT. 9. If FIT> 13.8-lb/gal, drill 6.75-in hole to TO, run 4.5 in liner and cement in place. 10. If FIT < 13.8-lb/gal, run 5.5-in liner and cement in place, then drill 4.75-in hole to TO, run 3.5-in liner and cement in place. 11. RU and run 4.5-in Completion. (Packer will be set -800-ft above injected zone to facilitate the drilling liner for the over-pressured Kalubik) Commission approval of packer> 200' above top perforations is sought. 12. NO BOP/NU tree. 13. Set packer, freeze protect. 14. ROMO Doyon 14. Post Rig 1. Run cement evaluation log. 2. Perforate. 8 Version 1.0 23 Feb 2004 MPa Proposed Base Case com.tion J I 112' I Conductor Casing 20-in K-55 92-lb/ft ~ Surface Casing 10.75-in L-80 BTC-M 45.5-lb/ft 9.875" Drift j 9.950" ID I 9,275-ft MDI 4-1/2" IBT 12.6 ppf, L-80 Intermediate 1 7.625-in L-80 BTC-M 29.7-lb/ft ~ 6. 75-i~ Drift 112 906-ft I .II 6.875-1n ID ' Drilling Liner 4.5-in L-80 BTC-M 12.6-lb/ft 3.833-in Drift 3.958-in I D 113,784-ft I I ... .. DATE 17 Feb 04 REV. BY COMMENTS MDG Proposed Base Case 4.5-in Monobore Desiç¡n . 2,OOO-ft TVO 4.5-in HES X-Nipple 13.5-in Hole , 4,701-ft TVO Set Below Schrader Bluff 5 to 6 Gas Lift Mandrels 9.875-in Hole 4.5-in HES XO sliding sleeve 4.5-in HES X-Nipple 7.625-in x 4.5-in Baker Premier Packer Top 4.5-in Liner 12,800-ft ZXP Flexlock Liner Top Packer 6-ft Tie-back extension 5.75-in ID 4.5-in HES XN-Nipple ~ 6,651-ft TVO WLEG - 5.5-in 00 Top Set HRZ and Fault #1 6.75-in Hole FIT to 13.8-lb/gal just above Kulubik If fails, top-set Kulubik If successful, drill to TD. 7526-ft TVO I ; M ILNF POINT UNIT WF.. No.: MPC-43 API: 50-0?9-XXXXX BP EXPLORATION (AK) MPcIt Proposed Contingency CO.letion J I 112-ftl Conductor Casing 20-in K-55 92-lb/ft Surface Casing 10.75-in L-80 BTC-M 45.5-lb/ft 9.875" Drift ~ 9.950" ID 9,275-ft MDI 4-1/2" IBT 12.6 ppf, L-80 ..... Intermediate Casing iii 7.625-in L-80 BTC-M 29.7-lb/ft i 6.75-in Drift 6.875-in ID I 12,906-ft I .. Contingency Drilling Liner 5-1/2" L -80 BTC-M 17. O-Ib/ft 4.76" Drift 4.892" ID I 13,120-ft I ~ Contingeny Production Liner 3.5-in L-80 IBT-M 9.3-lb/ft 2.867 -in Drift 2.992-in I D I 13,784-ft I .. ~ DATE REV. BY COMMENTS 17 Feb 2004 MDG Proposed Continç¡ency Desiç¡n . 2000-ft TVD 4.5" HES X-Nipple 13.5-in Hole Below Schrader Bluff , 4,701-ft TVD 5 to 6 Gas Lift Mandrels 9-7/8" Hole 4.5-in HES XD sliding sleeve 4.5" HES X-Nipple 7.625 x 4.5-in Baker Premier Packer 4.5" HES XN-Nipple 5.5" WLEG 6-ft Tie-back extension 5.75-in ID Top 3.5-in Liner 12,700-ft 3.5 x 5.5 x 7.625-in Liner Top Packer i Top 5.5-in Liner 12,800-ft ~ 5.5 x 7.625-in HMC Liner Hanger 6,651-ft TVD Top Set HRZ and Fault #1 6-3/4" Hole ~ 6,861-ftTVD I FIT to 13.8-lb/gal just above Kulubik 4-3/4" Hole If fails, top-set Kulubik If successful, drill to TD. ~ I 7526-ft TVD MI. NF POINT UNIT WF.. No.: MPC-43 API: 50-0?9-XXXXX BP EXPLORATION (AK) COMPANY DETAILS REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: Plan MPC-43 Ronaldo, True North ' Vertical (TVD) Reference: 5 I.(){Y 51.110 Section (\IS) Reference: Slot - (O.OON,O.OOE) Measured Depth Reference: 51.00' 51.00 Calculation Method Minimum Curvature 1IpEI"'I"'y-BlUn DI'IIIL~:.~:_.w~=,,~VI~1!"-.: ßP Amoco Calculation MelliCK!.: Minimum Curvature Error System: ISCWSA Scan Method: Trav Cylinder North Error Surface: Elliptical + Casing Waminµ Method: Rules Based CASING DETAILS No. TVD Name MD 4701.00 6651.00 7525.99 9275.22 103/4" 12905.73 75/8" 13784.15 41/2" 0- A FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1751.00 1942.01 BPRF 2 3791.00 6929.26 TUZC 3 4251.00 8115.13 SBF2-NA 4 4501.00 8759.62 SBA5 5 6771.00 13028.22 THRZ 6 6821.00 13078.72 BHRZ 7 6881.00 13139.03 KLGM 8 7016.00 13274.16 TKUD 9 7166.00 13424.16 TKUC 10 7171.00 13429.16 TKUB 11 7266.00 13524.16 TKUA 12 7271.00 13529.16 TKA3 13 7291.00 13549.16 TKAZ 14 7326.00 13584.16 TKAI 15 7376.00 13634.16 TMLV Start Dir2/100': 300' MD, 300'TVD / Start Dir 3/100': 400' MD. 399.98'TVD . % Start Dir 3.25/100': 500' MD, 499.78'TVD Y Start Dir3/100': 1494.II'MD,142J.63'TVD End Dir : 2568.39' MD. 2099.38'TVD Size SURVEY PROORAM Plan: MPC·43 wp07 (Plan MPC-43 Ronaldo/Plan MPC-43) Depth Fm Depth To Survey¡p¡m Tool Created By: Ken Allen Date: 1/]2/2004 34.00 lOOO.(J{) Planned: MPC43 wp07 V28 Cß-GYRO-SS Checked: Date lOOO.OO 13784.16 Plalllled: MPC-43 wp07 V28 MWD+I¡"'R,+MS Reviewed: Date WELL DETAILS N~ +N/-S +EI-W Northing Easting Latitude Longitude Slot Plan MPC-43 Ronalda 2272.32 108.23 602962059 558148.52 10"29'29.548N 149"31'28.6J7W N/A TARGET DETAILS N=, TVD +N/-S +EI-W Northing Easting Shape MPC-4J TlA 7266.(}{) 9622.75 _3468.71 6OJ9215.()() 554605.00 Polygon SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target I 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 400.00 2.00 290.00 399.98 0.60 -1.64 2.00 290.00 1.12 4 500.00 5.00 290.00 499.78 2.68 -7.38 3.00 0.00 5.03 5 1494.11 36.00 330.00 1421.63 277.85 -199.28 3.25 44.98 328.96 . 6 1868.38 47.23 330.00 1701.00 492.76 -323.36 3.00 0.00 573.22 7 2015.64 47.23 330.00 1801.00 586.38 -377.41 0.00 0.00 679.62 8 2567.27 67.18 341.36 2098.98 1007.82 -562.20 4.00 28.89 1138.75 9 11424.76 67.18 341.36 5534.81 8743.38 -3172.05 0.00 0.00 9300.98 10 12604.16 20.00 341.36 6365.14 9492.29 -3424.70 4.00 180.00 10091.19 II 12754.16 20.00 341.36 6506.09 9540.90 -3441.10 0.00 0.00 10142.48 12 13254.16 0.00 341.36 6996.00 9622.75 -3468.71 4.00 180.00 10228.85 13 13524.16 0.00 341.36 7266.00 9622.75 -3468.71 0.00 0.00 10228.85 MPC-43 Tl A 14 13634.16 0.00 341.36 7376.00 9622.75 -3468.71 0.00 341.36 10228.85 15 13784.16 0.00 341.36 7526.00 9622.75 -3468.71 0.00 341.36 10228.85 10.750 7.625 4.500 " ~ c o =. -'" õ. ð ~ " 1': ~ ~ f-< . Start Dir 4/100' : 11432.29' MD, 5530.82'TVD End Dir : 12722.9' MD, 6466.33' TVD , Start Dir4/100': 12872.9' MD, 661O.8'TVD 75/8" / Vertical Section at 340.18' [1400ft/in] , I ' 11200 I I I I I , , 12600 wp07 (Plan MPC-43 RonaldolPlan MPC-43) Date: 1/]2/2004 Datc_ Date'_ Created By: Ken Allen Checked: Reviewed: WELL DETAILS Plan: MPC-41 SURVEY PROGRAM Depth Fm Depth To SUlVeylPlan Tool 34,()() 1000,00 Planned: MPC-43 wpm V2 Cø-GYRO-S5 1000,00 13784,16 Planned: MPC-4J wp07 V21 MWD+IFR+M: REFERENCE INFORMATION Co-ordinate (N/E) Reference: Well Ceutre: Plan MPC-4J RonaJoo, True North Vertkal (1VD) Rerereo¡;e; 5 J.()(I' 5 ).00 Se¡;tir.m (V5) ReJereoo.:e: Slot - (OJKIN,ß.OOE) Meas~aJ~~a~~~~~ ~~¿~~~ure ~) COMPANY DETAILS BPAmoco Minimum Curvature I.SCWSA TravCylinderNorth EJliptical+Ca.>Îng RlIlesBased Calculation Method: ~r: ~~=; ErrorSurlace: Wamin~ Method: !IIipIBI'T'\,I-!I5I.S1 fil¡-r.tn;;J;;lij_~::.:W:!II:~Yf,;JlfM N"", +N/-5 +E/.W Northing Basting Latitude Lvngitude 5101 Plan MPC-43 Ronaldo 2272.32 108.23 602962059 558148.52 7()"29'29.548N J49"31'28.637W N/A TARGET DETAILS N"", 1VD +NI-S +FJ·W No(!hing EastÎt1g Shape MPC·43 TlA 7266.00 9622.75 -J468.71 6OJ9215.00 554605.00 Polygol Depth: 13784.16' MD, 7526' TVD 13254.16' MD, 6996' TVD 12754.16' MD, 6506.09'TVD 12604.16' MD, 6365.14' TVD 1424.76' MD, 5534.81 'TVD I I I . DLeg TF ace VSec Target 0.00 0.00 0.00 0.00 0.00 0.00 2.00 290.00 1.12 3.00 0.00 5.03 3.25 44.98 328.96 3.00 0.00 573.22 0.00 0.00 679.62 4.00 28.89 1138.75 0.00 0.00 9300.98 4.00 180.00 10091.19 0.00 0.00 10142.48 4.00 180.00 10228.85 0.00 0.00 J 0228.85 MPC-43 TIA 0.00 341.36 10228.85 0.00 341.36 10228.85 FORMATION TOP DETAILS No. TVDPath MDPath Formation 1 J751.00 1942.01 BPRF 2 3791.00 6929.26 TUZC 3 4251.00 8Jl5.13 SBF2-NA 4 4501.00 8759.62 SBA5 5 6771.00 13028.22 THRZ 6 6821.00 13078.72 BHRZ 7 6881.00 13139.03 KLGM 8 7016.00 13274.16 TKUD 9 7166.00 13424.16 TKUC 10 7171.00 13429.16 TKUB Jl 7266.00 13524.16 TKUA 12 7271.00 13529.16 TKA3 13 7291.00 13549.16 TKA2 14 7326.00 13584.16 TKAI IS 7376.00 13634.16 TMLV SECTION DETAILS Sec MD Inc Azi TVD +NI-S +EI-W I 34.00 0.00 0.00 34.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 3 400.00 2.00 290.00 399.98 0.60 -1.64 4 500.00 5.00 290.00 499.78 2.68 -7.38 5 1494.11 36.00 330.00 1421.63 277.85 -199.28 6 1868.38 47.23 330.00 1701.00 492.76 -323.36 7 2015.64 47.23 330.00 1801.00 586.38 -377.41 8 2567.27 67.18 341.36 2098.98 ] 007.82 -562.20 9 11424.76 67.18 341.36 5534.81 8743.38 -3172.05 10 12604.16 20.00 341.36 6365.14 9492.29 -3424.70 II 12754.16 20.00 341.36 6506.09 9540.90 -3441.10 12 13254.16 0.00 341.36 6996.00 9622.75 -3468.71 13 13524.16 0.00 341.36 7266.00 9622.75 -3468.71 14 13634.16 0.00 341.36 7376.00 9622.75 -3468.71 15 13784.16 0.00 341.36 7526.00 9622.75 -3468.71 CASING DETAILS Size 10.750 7.625 4.500 No. TVD MD Name 4701.00 9275.22 10314' 6651.00 12905.73 75/8" 7525.99 13784.15 41/2" íi' ~ o o .,., +' ~ ~ :a' 15 o '" . 2567.27' MD, 2098.98' TVD ~ BYe 4{\~~dY'~ß;' MS, 1\9PVD StartDir3I100': 1494.II'MD, 1421.63'TVD Start Dir 3.251100' : 500' MD, 499.78'TVD Start Dir 3/100' : 400' MD, 399.98'TVD Start Dir 211 00' : 300' MD, 300TVD I 500 500ft/in] I 500 West(-)/East(+) [ =ai-'= ''''y-sun DRIL.L.ING SSAVICE;$ . . Sperry-Sun - Draft Copy KW A Planning ...>I....I,MIlfJR111f<n..."........ Plan: MPC-43 wp07 Principal: Yes Field: Milne Point North Slope UNITED STATES Map SystenUS State Plane Coordinate System 1927 Geo DatumNAD27 (Clarke 1866) Sys Datum:Mean Sea Level Site: M PIC Pad TR-13-10 UNITED STATES: North Slope Site Position: Northing: 6027347.71 ft From: Map Easting: 558058.04 ft Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: Plan MPC-43 Ronaldo Well Position: +N/-S 2272.32 ft Northing: 6029620.59 ft +E/-W 108.23 ft Easting: 558148.52 ft Position Uncertainty: 0.00 ft WeIlpath: Plan MPC-43 Current Datum: 51.00' Magnetic Data: 5/7/2003 Field Strength: 57533 nT Vertical Section: Depth From (TVD) ft 34.00 Height 51.00 ft +N/-S ft 0.00 Casing Points Date Composed: Version: Tied-to: 1/8/2004 28 From Well Ref. Point Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Latitude: 70 29 Longitude: 149 31 North Reference: Grid Convergence: 7.200 N 31.821 W True 0.45 deg Slot Name: Latitude: Longitude: 70 29 29.548 N 149 31 28.637 W Well Ref. Point 34.00 ft Mean Sea Level 25.36 deg 80.88 deg Direction deg 340.18 Drilled From: Tie-on Depth: Above System Datum: Declin ation: Mag Dip Angle: +E/-W ft 0.00 9275.22 4701.00 10.750 12.250 10 3/4" 12905.73 6651.00 7.625 9.875 7 5/8" 13784.15 7525.99 4.500 6.125 41/2" Formations 1942.01 1751.00 BPRF 6929.26 3791.00 TUZC 8115.13 4251.00 SBF2-NA 8759.62 4501.00 SBA5 13028.22 6771.00 THRZ 13078.72 6821.00 BHRZ 13139.03 6881.00 KLGM 13274.16 7016.00 TKUD 13424.16 7166.00 TKUC 13429.16 7171.00 TKUB 13524.16 7266.00 TKUA 13529.16 7271.00 TKA3 13549.16 7291.00 TKA2 13584.16 7326.00 TKA1 13634.16 7376.00 TMLV 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 A .f.~!,I.,I"'J~ll){'< I:ttMl'_!>N'- . . Sperry-Sun - Draft Copy KW A Planning .....1:::1 ""'Y-5un DRILI..ING !UiRVIC;ræs Targets MPC-43 T1A 7266.00 9622.75 -3468.71 6039215.00 554605.00 70 31 4.177 N 149 33 10.845 W -Polygon 1 7266.00 9620.99 -3243.70 6039215.00 554830.00 70 31 4.161 N 149 33 4.215 W -Polygon 2 7266.00 9856.01 -3241.86 6039450.00 554830.00 70 31 6A72 N 149 33 4.163 W -Polygon 3 7266.00 9857.77 -3466.87 6039450.00 554605.00 70 31 6A88 N 149 33 10.794 W -Polygon 4 7266.00 9849.84 -3731.97 6039440.00 554340.00 70 31 6A09 N 149 33 18.605 W -Polygon 5 7266.00 9625.14 -3773.73 6039215.00 554300.00 70 31 4.199 N 149 33 19.833 W -Polygon 6 7266.00 9459.74 -3725.02 6039050.00 554350.00 70 31 2.573 N 149 33 18.395 W -Polygon 7 7266.00 9332.73 -3470.98 6038925.00 554605.00 70 31 1 .325 N 149 33 10.908 W -Polygon 8 7266.00 9481.30 -3284.80 6039075.00 554790.00 70 31 2.787 N 149 33 5A24 W -Plan hit target Plan Section Information 34.00 0.00 0.00 34.00 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0.00 400.00 2.00 290.00 399.98 0.60 -1.64 2.00 2.00 0.00 290.00 500.00 5.00 290.00 499.78 2.68 -7.38 3.00 3.00 0.00 0.00 1494.11 36.00 330.00 1421.63 277.85 -199.28 3.25 3.12 4.02 44.98 1868.38 47.23 330.00 1701.00 492.76 -323.36 3.00 3.00 0.00 0.00 2015.64 47.23 330.00 1801.00 586.38 -377.41 0.00 0.00 0.00 0.00 2567.27 67.18 341.36 2098.98 1007.82 -562.20 4.00 3.62 2.06 28.89 11424.76 67.18 341.36 5534.81 8743.38 -3172.05 0.00 0.00 0.00 0.00 12604.16 20.00 341.36 6365.14 9492.29 -3424.70 4.00 -4.00 0.00 180.00 12754.16 20.00 341.36 6506.09 9540.90 -3441.10 0.00 0.00 0.00 0.00 13254.16 0.00 341.36 6996.00 9622.75 -3468.71 4.00 -4.00 0.00 180.00 13524.16 0.00 341.36 7266.00 9622.75 -3468.71 0.00 0.00 0.00 0.00 MPC-43 T1A 13634.16 0.00 341.36 7376.00 9622.75 -3468.71 0.00 0.00 0.00 341.36 13784.16 0.00 341.36 7526.00 9622.75 -3468.71 0.00 0.00 0.00 341.36 Survey 34.00 0.00 0.00 34.00 -17.00 6029620.59 558148.52 0.00 0.00 0.00 CB-GYRO-SS 100.00 0.00 0.00 100.00 49.00 6029620.59 558148.52 0.00 0.00 0.00 CB-GYRO-SS 200.00 0.00 0.00 200.00 149.00 6029620.59 558148.52 0.00 0.00 0.00 CB-GYRO-SS 300.00 0.00 0.00 300.00 249.00 6029620.59 558148.52 0.00 0.00 0.00 CB-GYRO-SS 400.00 2.00 290.00 399.98 348.98 6029621.17 558146.88 1.12 2.00 0.00 CB-GYRO-SS 500.00 5.00 290.00 499.78 448.78 6029623.22 558141.12 5.03 3.00 0.00 CB-GYRO-SS 600.00 7.65 307.52 599.17 548.17 6029628.69 558131.70 13.42 3.25 44.98 CB-GYRO-SS 700.00 10.64 315.69 697.90 646.90 6029639.26 558119.89 27A3 3.25 27.57 CB-GYRO-SS 800.00 13.74 320.26 795.63 744.63 6029654.89 558105.72 47.01 3.25 19.50 CB-GYRO-SS 900.00 16.90 323.15 892.06 841.06 6029675.53 558089.25 72.08 3.25 15.03 CB-GYRO-SS 1000.00 20.09 325.16 986.89 935.89 6029701.12 558070.51 102.58 3.25 12.23 MWD+IFR+MS 1100.00 23.30 326.63 1079.79 1028.79 6029731.58 558049.58 138AO 3.25 10.33 MWD+IFR+MS 1200.00 26.51 327.77 1170A8 1119A8 6029766.79 558026.52 179A4 3.25 8.96 MWD+IFR+MS 1300.00 29.73 328.67 1258.67 1207.67 6029806.67 558001 AO 225.54 3.25 7.93 MWD+IFR+MS 1400.00 32.96 329A 1 1344.06 1293.06 6029851.06 557974.31 276.58 3.25 7.14 MWD+IFR+MS 1494.11 36.00 330.00 1421.63 1370.63 6029896.85 557947.10 328.96 3.25 6.50 MWD+IFR+MS 1500.00 36.18 330.00 1426.39 1375.39 6029899.84 557945.34 332.38 3.00 0.00 MWD+IFR+MS 1600.00 39.18 330.00 1505.53 1454.53 6029952.52 557914.37 392.53 3.00 0.00 MWD+IFR+MS 1700.00 42.18 330.00 1581.36 1530.36 6030008.70 557881.35 456.68 3.00 0.00 MWD+IFR+MS 1800.00 45.18 330.00 1653.67 1602.67 6030068.22 557846.36 524.64 3.00 0.00 MWD+IFR+MS 1868.38 47.23 330.00 1701.00 1650.00 6030110.76 557821.35 573.22 3.00 0.00 MWD+IFR+MS 1900.00 47.23 330.00 1722A7 1671A7 6030130.77 557809.59 596.06 0.00 180.00 MWD+IFR+MS 1942.01 47.23 330.00 1751.00 1700.00 6030157.35 557793.96 626A2 0.00 180.00 BPRF 2000.00 47.23 330.00 1790.38 1739.38 6030194.05 557772.39 668.32 0.00 180.00 MWD+IFR+MS ~ H,U.r.tItlJlHn" U_."'N'I; . . Sperry-Sun - Draft Copy KW A Planning !5pE!I'"T"y-sun DRILLING !UIRVICCU¡ Survey 2015.64 47.23 330.00 1801.00 1750.00 6030203.94 557766.58 679.62 0.00 180.00 MWD+IFR+MS 2100.00 50.20 332.12 1856.66 1805.66 6030259.17 557735.50 742.20 4.00 28.89 MWD+IFR+MS 2200.00 53.77 334.41 1918.23 1867.23 6030329.25 557699.56 820.40 4.00 27.49 MWD+IFR+MS 2300.00 57.39 336.50 1974.76 1923.76 6030404.00 557664.74 902.59 4.00 26.08 MWD+IFR+MS 2400.00 61.03 338.42 2025.94 1974.94 6030483.07 557631.22 988.37 4.00 24.90 MWD+IFR+MS 2500.00 64.70 340.21 2071.55 2020.55 6030566.05 557599.17 1077.34 4.00 23.91 MWD+IFR+MS 2567.27 67.18 341.36 2098.98 2047.98 6030623.89 557578.51 1138.75 4.00 23.10 MWD+IFR+MS 2600.00 67.18 341.36 2111.68 2060.68 6030652.39 557568.65 1168.91 0.00 0.00 MWD+IFR+MS 2700.00 67.18 341.36 2150.47 2099.47 6030739.48 557538.50 1261.06 0.00 0.00 MWD+IFR+MS 2800.00 67.18 341.36 2189.26 2138.26 6030826.58 557508.36 1353.21 0.00 0.00 MWD+IFR+MS 2900.00 67.18 341.36 2228.05 2177.05 6030913.67 557478.21 1445.36 0.00 0.00 MWD+IFR+MS 3000.00 67.18 341.36 2266.84 2215.84 6031000.76 557448.07 1537.51 0.00 0.00 MWD+IFR+MS 3100.00 67.18 341.36 2305.63 2254.63 6031087.85 557417.93 1629.66 0.00 0.00 MWD+IFR+MS 3200.00 67.18 341.36 2344.42 2293.42 6031174.94 557387.78 1721.81 0.00 0.00 MWD+IFR+MS 3300.00 67.18 341.36 2383.21 2332.21 6031262.04 557357.64 1813.97 0.00 0.00 MWD+IFR+MS 3400.00 67.18 341.36 2422.00 2371.00 6031349.13 557327.49 1906.12 0.00 0.00 MWD+IFR+MS 3500.00 67.18 341.36 2460.79 2409.79 6031436.22 557297.35 1998.27 0.00 0.00 MWD+IFR+MS 3600.00 67.18 341.36 2499.58 2448.58 6031523.31 557267.21 2090.42 0.00 0.00 MWD+IFR+MS 3700.00 67.18 341.36 2538.37 2487.37 6031610.40 557237.06 2182.57 0.00 0.00 MWD+IFR+MS 3800.00 67.18 341.36 2577.16 2526.16 6031697.50 557206.92 2274.72 0.00 0.00 MWD+IFR+MS 3900.00 67.18 341.36 2615.95 2564.95 6031784.59 557176.77 2366.87 0.00 0.00 MWD+IFR+MS 4000.00 67.18 341.36 2654.74 2603.74 6031871.68 557146.63 2459.02 0.00 0.00 MWD+IFR+MS 4100.00 67.18 341.36 2693.53 2642.53 6031958.77 557116.48 2551.17 0.00 0.00 MWD+IFR+MS 4200.00 67.18 341.36 2732.32 2681.32 6032045.86 557086.34 2643.32 0.00 0.00 MWD+IFR+MS 4300.00 67.18 341.36 2771.11 2720.11 6032132.96 557056.20 2735.47 0.00 0.00 MWD+IFR+MS 4400.00 67.18 341.36 2809.90 2758.90 6032220.05 557026.05 2827.62 0.00 0.00 MWD+IFR+MS 4500.00 67.18 341.36 2848.69 2797.69 6032307.14 556995.91 2919.77 0.00 0.00 MWD+IFR+MS 4600.00 67.18 341.36 2887.48 2836.48 6032394.23 556965.76 3011.92 0.00 0.00 MWD+IFR+MS 4700.00 67.18 341.36 2926.27 2875.27 6032481.32 556935.62 3104.07 0.00 0.00 MWD+IFR+MS 4800.00 67.18 341.36 2965.06 2914.06 6032568.42 556905.48 3196.22 0.00 0.00 MWD+IFR+MS 4900.00 67.18 341.36 3003.85 2952.85 6032655.51 556875.33 3288.37 0.00 0.00 MWD+IFR+MS 5000.00 67.18 341.36 3042.64 2991.64 6032742.60 556845.19 3380.53 0.00 0.00 MWD+IFR+MS 5100.00 67.18 341.36 3081.43 3030.43 6032829.69 556815.04 3472.68 0;00 0.00 MWD+IFR+MS 5200.00 67.18 341.36 3120.22 3069.22 6032916.78 556784.90 3564.83 0.00 0.00 MWD+IFR+MS 5300.00 67.18 341.36 3159.01 3108.01 6033003.88 556754.76 3656.98 0:00 0.00 MWD+IFR+MS 5400.00 67.18 341.36 3197.80 3146.80 6033090.97 556724.61 3749.13 0.00 0.00 MWD+IFR+MS 5500.00 67.18 341.36 3236.59 3185.59 6033178.06 556694.47 3841.28 0.00 0.00 MWD+IFR+MS 5600.00 67.18 341.36 3275.38 3224.38 6033265.15 556664.32 3933.43 0.00 0.00 MWD+IFR+MS 5700.00 67.18 341.36 3314.17 3263.17 6033352.24 556634.18 4025.58 0.00 0.00 MWD+IFR+MS 5800.00 67.18 341.36 3352.96 3301.96 6033439.34 556604.03 4117.73 0.00 0.00 MWD+IFR+MS 5900.00 67.18 341.36 3391.75 3340.75 6033526.43 556573.89 4209.88 0.00 0.00 MWD+IFR+MS 6000.00 67.18 341.36 3430.54 3379.54 6033613.52 556543.75 4302.03 0.00 0.00 MWD+IFR+MS 6100.00 67.18 341.36 3469.33 3418.33 6033700.61 556513.60 4394.18 0.00 0.00 MWD+IFR+MS 6200.00 67.18 341.36 3508.12 3457.12 6033787.71 556483.46 4486.33 0;00 0.00 MWD+IFR+MS 6300.00 67.18 341.36 3546.91 3495.91 6033874.80 556453.31 4578.48 0.00 0.00 MWD+IFR+MS 6400.00 67.18 341.36 3585.70 3534.70 6033961.89 556423.17 4670.63 0.00 0.00 MWD+IFR+MS 6500.00 67.18 341.36 3624.49 3573.49 6034048.98 556393.03 4762.78 0.00 0.00 MWD+IFR+MS 6600.00 67.18 341.36 3663.28 3612.28 6034136.07 556362.88 4854.93 0.00 0.00 MWD+IFR+MS 6700.00 67.18 341.36 3702.07 3651.07 6034223.17 556332.74 4947.09 0.00 0.00 MWD+IFR+MS 6800.00 67.18 341.36 3740.86 3689.86 6034310.26 556302.59 5039.24 0.00 0.00 MWD+IFR+MS 6900.00 67.18 341.36 3779.65 3728.65 6034397.35 556272.45 5131.39 0.00 0.00 MWD+IFR+MS 6929.26 67.18 341.36 3791.00 3740.00 6034422.83 556263.63 5158.35 0.00 0.00 ruze "JU..l,fJØlFI"""":i_.~N" . . Sperry-Sun - Draft Copy KW A Planning ~ .. 'y-sun DAII-I-ING SEiAVIC:SS Survey 7000.00 67.18 341.36 3818.44 3767.44 6034484.44 556242.31 5223.54 0.00 0.00 MWD+IFR+MS 7100.00 67.18 341.36 3857.23 3806.23 6034571.53 556212.16 5315.69 0.00 0.00 MWD+IFR+MS 7200.00 67.18 341.36 3896.02 3845.02 6034658.63 556182.02 5407.84 0.00 0.00 MWD+IFR+MS 7300.00 67.18 341.36 3934.81 3883.81 6034745.72 556151.87 5499.99 0.00 0.00 MWD+IFR+MS 7400.00 67.18 341.36 3973.60 3922.60 6034832.81 556121.73 5592.14 0.00 0.00 MWD+IFR+MS 7500.00 67.18 341.36 4012.39 3961.39 6034919.90 556091.58 5684.29 0.00 0.00 MWD+IFR+MS 7600.00 67.18 341.36 4051.18 4000.18 6035006.99 556061.44 5776.44 0.00 0.00 MWD+IFR+MS 7700.00 67.18 341.36 4089.97 4038.97 6035094.09 556031.30 5868.59 0.00 0.00 MWD+IFR+MS 7800.00 67.18 341.36 4128.76 4077.76 6035181.18 556001.15 5960.74 0.00 0.00 MWD+IFR+MS 7900.00 67.18 341.36 4167.55 4116.55 6035268.27 555971.01 6052.89 0.00 0.00 MWD+IFR+MS 8000.00 67.18 341.36 4206.34 4155.34 6035355.36 555940.86 6145.04 0.00 0.00 MWD+IFR+MS 8100.00 67.18 341.36 4245.13 4194.13 6035442.45 555910.72 6237.19 0.00 0.00 MWD+IFR+MS 8115.13 67.18 341.36 4251.00 4200.00 6035455.63 555906.16 6251.14 0.00 0.00 SBF2-NA 8200.00 67.18 341.36 4283.92 4232.92 6035529.55 555880.58 6329.34 0.00 0.00 MWD+IFR+MS 8300.00 67.18 341.36 4322.71 4271.71 6035616.64 555850.43 6421.49 0.00 0.00 MWD+IFR+MS 8400.00 67.18 341.36 4361.50 4310.50 6035703.73 555820.29 6513.65 0.00 0.00 MWD+IFR+MS 8500.00 67.18 341.36 4400.29 4349.29 6035790.82 555790.14 6605.80 0.00 0.00 MWD+IFR+MS 8600.00 67.18 341.36 4439.08 4388.08 6035877.91 555760.00 6697.95 0.00 0.00 MWD+IFR+MS 8700.00 67.18 341.36 4477.87 4426.87 6035965.01 555729.86 6790.10 0.00 0.00 MWD+IFR+MS 8759.62 67.18 341.36 4501.00 4450.00 6036016.93 555711.88 6845.04 0.00 0.00 SBA5 8800.00 67.18 341.36 4516.66 4465.66 6036052.10 555699.71 6882.25 0.00 0.00 MWD+IFR+MS 8900.00 67.18 341.36 4555.45 4504.45 6036139.19 555669.57 6974.40 0.00 0.00 MWD+IFR+MS 9000.00 67.18 341.36 4594.24 4543.24 6036226.28 555639.42 7066.55 0.00 0.00 MWD+IFR+MS 9100.00 67.18 341.36 4633.03 4582.03 6036313.38 555609.28 7158.70 0.00 0.00 MWD+IFR+MS 9200.00 67.18 341.36 4671.82 4620.82 6036400.47 555579.13 7250.85 0.00 0.00 MWD+IFR+MS 9275.22 67.18 341.36 4701.00 4650.00 6036465.98 555556.46 7320.17 0.00 0.00 103/4" 9300.00 67.18 341.36 4710.61 4659.61 6036487.56 555548.99 7343.00 0.00 0.00 MWD+IFR+MS 9400.00 67.18 341.36 4749.40 4698.40 6036574.65 555518.85 7435.15 0.00 0.00 MWD+IFR+MS 9500.00 67.18 341.36 4788.19 4737.19 6036661.74 555488.70 7527.30 0.00 0.00 MWD+IFR+MS 9600.00 67.18 341.36 4826.98 4775.98 6036748.84 555458.56 7619.45 0.00 0.00 MWD+IFR+MS 9700.00 67.18 341.36 4865.77 4814.77 6036835.93 555428.41 7711.60 0.00 0.00 MWD+IFR+MS 9800.00 67.18 341.36 4904.56 4853.56 6036923.02 555398.27 7803.75 0.00 0.00 MWD+IFR+MS 9900.00 67.18 341.36 4943.35 4892.35 6037010.11 555368.13 7895.90 0.00 0.00 MWD+IFR+MS 10000.00 67.18 341.36 4982.14 4931.14 6037097.20 555337.98 7988.06 0.00 0.00 MWD+IFR+MS 10100.00 67.18 341.36 5020.93 4969.93 6037184.30 555307.84 8080.21 0.00 0.00 MWD+IFR+MS 10200.00 67.18 341.36 5059.72 5008.72 6037271.39 555277.69 8172.36 0.00 0.00 MWD+IFR+MS 10300.00 67.18 341.36 5098.51 5047.51 6037358.48 555247.55 8264.51 0.00 0.00 MWD+IFR+MS 10400.00 67.18 341.36 5137.30 5086.30 6037445.57 555217.41 8356.66 0.00 0.00 MWD+IFR+MS 10500.00 67.18 341.36 5176.09 5125.09 6037532.66 555187.26 8448.81 0.00 0.00 MWD+IFR+MS 10600.00 67.18 341.36 5214.88 5163.88 6037619.76 555157.12 8540.96 0.00 0.00 MWD+IFR+MS 10700.00 67.18 341.36 5253.67 5202.67 6037706.85 555126.97 8633.11 0.00 0.00 MWD+IFR+MS 10800.00 67.18 341.36 5292.46 5241.46 6037793.94 555096.83 8725.26 0.00 0.00 MWD+IFR+MS 10900.00 67.18 341.36 5331.25 5280.25 6037881.03 555066.68 8817.41 0.00 0.00 MWD+IFR+MS 11000.00 67.18 341.36 5370.04 5319.04 6037968.12 555036.54 8909.56 0.00 0.00 MWD+IFR+MS 11100.00 67.18 341.36 5408.83 5357.83 6038055.22 555006.40 9001.71 0.00 0.00 MWD+IFR+MS 11200.00 67.18 341.36 5447.62 5396.62 6038142.31 554976.25 9093.86 0.00 0.00 MWD+IFR+MS 11300.00 67.18 341.36 5486.41 5435.41 6038229.40 554946.11 9186.01 0.00 0.00 MWD+IFR+MS 11400.00 67.18 341.36 5525.20 5474.20 6038316.49 554915.96 9278.16 0.00 0.00 MWD+IFR+MS 11424.76 67.18 341.36 5534.81 5483.81 6038338.05 554908.50 9300.98 0.00 0.00 MWD+IFR+MS 11500.00 64.17 341.36 5565.80 5514.80 6038402.83 554886.08 9369.52 4.00 180.00 MWD+IFR+MS 11600.00 60.17 341.36 5612.48 5561.48 6038486.37 554857.17 9457.91 4.00 180.00 MWD+IFR+MS 11700.00 56.17 341.36 5665.22 5614.22 6038566.63 554829.39 9542.83 4.00 180.00 MWD+IFR+MS 11800.00 52.17 341.36 5723.75 5672.75 6038643.22 554802.88 9623.87 4.00 180.00 MWD+IFR+MS '" 1:Yo.\,UIU'ICIUl\nlMl'-"NY . . Sperry-Sun - Draft Copy KW A Planning :::a¡....a= .. 'V-sun CRILI..ING SERVIc:es Survey 11900.00 48.17 341.36 5787.79 5736.79 6038715.77 554777.77 9700.63 4.00 180.00 MWDt/FR+MS 12000.00 44.17 341.36 5857.04 5806.04 6038783.92 554754.18 9772.74 4.00 180.00 MWDtIFR+MS 12100.00 40.17 341.36 5931.14 5880.14 6038847.33 554732.23 9839.84 4.00 180.00 MWDtIFR+MS 12200.00 36.17 341.36 6009.75 5958.75 6038905.71 554712.03 9901.60 4.00 180.00 MWDtIFR+MS 12300.00 32.17 341.36 6092.47 6041.47 6038958.77 554693.67 9957.74 4.00 180.00 MWDtIFR+MS 12400.00 28.17 341.36 6178.91 6127.91 6039006.24 554677.24 10007.97 4.00 180.00 MWDtIFR+MS 12500.00 24.17 341.36 6268.64 6217.64 6039047.90 554662.82 10052.05 4.00 180.00 MWDtIFR+MS 12604.16 20.00 341.36 6365.14 6314.14 6039084.90 554650.02 10091.19 4.00 180.00 MWDtIFR+MS 12700.00 20.00 341.36 6455.20 6404.20 6039115.87 554639.30 10123.97 0.00 0.00 MWDtIFR+MS 12754.16 20.00 341.36 6506.09 6455.09 6039133.37 554633.24 10142.48 0.00 0.00 MWDtIFR+MS 12800.00 18.17 341.36 6549.41 6498.41 6039147.53 554628.34 10157.47 4.00 180.00 MWDtIFR+MS 12900.00 14.17 341.36 6645.44 6594.44 6039173.84 554619.24 10185.30 4.00 180.00 MWDtIFR+MS 12905.73 13.94 341.36 6651.00 6600.00 6039175.15 554618.79 10186.69 4.00 180.00 75/8" 13000.00 10.17 341.36 6743.17 6692.17 6039193.75 554612.35 1 0206.37 4.00 180.00 MWDtIFR+MS 13028.22 9.04 341.36 6771.00 6720.00 6039198.20 554610.81 10211.07 4.00 180.00 THRZ 13078.72 7.02 341.36 6821.00 6770.00 6039204.86 554608.51 10218.12 4.00 180.00 BHRZ 13100.00 6.17 341.36 6842.14 6791.14 6039207.17 554607.71 10220.56 4.00 180.00 MWDtIFR+MS 13139.03 4.60 341.36 6881.00 6830.00 6039210.63 554606.51 10224.23 4.00 180.00 KLGM 13200.00 2.17 341.36 6941.86 6890.86 6039214.03 554605.33 10227.83 4.00 180.00 MWDtIFR+MS 13254.16 0.00 341.36 6996.00 6945.00 6039215.00 554605.00 10228.85 4.00 180.00 MWDtIFR+MS 13274.16 0.00 341.36 7016.00 6965.00 6039215.00 554605.00 10228.85 0.00 341.36 TKUD 13300.00 0.00 341.36 7041.84 6990.84 6039215.00 554605.00 10228.85 0.00 341.36 MWDtIFR+MS 13400.00 0.00 341.36 7141.84 7090.84 6039215.00 554605.00 10228.85 0.00 341.36 MWDtIFR+MS 13424.16 0.00 341.36 7166.00 7115.00 6039215.00 554605.00 10228.85 0.00 341.36 TKUC 13429.16 0.00 341.36 7171.00 7120.00 6039215.00 554605.00 10228.85 0.00 341.36 TKUB 13500.00 0.00 341.36 7241.84 7190.84 6039215.00 554605.00 10228.85 0.00 341.36 MWDtIFR+MS 13524.16 0.00 341.36 7266.00 7215.00 6039215.00 554605.00 10228.85 0.00 341.36 MPC-43 T1A 13529.16 0.00 341.36 7271.00 7220.00 6039215.00 554605.00 10228.85 0.00 341.36 TKA3 13549.16 0.00 341.36 7291.00 7240.00 6039215.00 554605.00 10228.85 0.00 341.36 TKA2 13584.16 0.00 341.36 7326.00 7275.00 6039215.00 554605.00 10228.85 0.00 341.36 TKA1 13600.00 0.00 341.36 7341.84 7290.84 6039215.00 554605.00 10228.85 0.00 341.36 MWDtIFR+MS 13634.16 0.00 341.36 7376.00 7325.00 6039215.00 554605.00 10228.85 0.00 341.36 TMLV 13700.00 0.00 341.36 7441.84 7390.84 6039215.00 554605.00 10228.85 0.00 341.36 MWDtIFR+MS 13784.16 0.00 341.36 7526.00 7475.00 6039215.00 554605.00 10228.85 0.00 341.36 41/2" MPU KUP \If RE: MPC-43 . . Subject: RE: MPC-43 From: "Green, Matt D" <GreenMD@BP.com> Date: Mon, 01 Mar 2004 11:45:32 -0900 To: Thomas Maunder <tom_maunder@admin.state.ak.us> CC: "Archey, Pat" <ArcheyPJ@BP.com> Tom, In answer to your questions: 1. The Halliburton ES Cementer stage }Ool will be.ze immediately below the permafrost at 2000-ft MD. ~ 2. The TOC for the 7.625-in casing should be 12,4 6-ft MD (not 7,818-ft - a carry-over from a previous w~ll permit). 3. The BOPE will be tested to 4,500-psi~The intermediate casing and the liner(s) and liner top hanger/packer will then all be tested to 4,500-psi using the rams. The results from drilling MPC-42 should not affect the way we plan to drill MPC-43. We will set the intermediate string high and perform an open hole FIT to determine whether or not we need to run the contingency drilling liner. Thankyou for picking up these errors and omissions. I hope that these comments answer your questions. If you have any more, please do not hesitate to call. Cheers, Màtt. -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Wednesday, 25 February 2004 3:36 PM To: Green, Matt D Subject: Re: MPC-43 Matt, I was reading further in th~ application. Since this well is not an injector, the 200' distance with regard to the packer does not apply. . Looks like you have gotten your contingencies in order in case there is over pressure. How will~the drilling of MPC-42 effect the plans for MPC-43?? , , Tom 10f2 3/1/2004 12:59 PM RE: MPC-43 . . Thomas Maunder wrote: Matt, I had a couple of questions after beginning my review of the permit. I also left you a voice mail. 1. What depth is your stage tool?? 2. On the cementing information page for the 7-5/8" intermediate string, what is the planned TOC?? The value of 7818 doesn't fit TD minus 500'. 3. On the well control page, it is stated that the BOP will be tested to 3500 psi however it is also stated that the casing and liner test pressures will be 4500 psi. Will you be closing the rams to effect these test pressures?? If so, it would seem appropriate to test the BOP to 4500 psi if you are expecting it to hold that pressure. I look forward to your replies. Tom Maunder, PE AOGCC 20f2 3/1/2004 12:59 PM p055222 DATE 1/6/2004 INVOICE I CREDIT MEMO PR010504F DESCRIPTION PERMIT TO DRILL THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE:, AK99519-6612 PAY: TO THE ORDER OF: Y;' ."... !iiI! ;;.'1 I' ,I .. .:Adl.. . tIll' O~ALfX81<A AOGCC<i:i> . 333 WESTqT~ÔVENYE SUITE100 ANCHORAGE. AK 99501-3539 GROSS NATIONAL CITY BANK Ashland, Ohio DATE I 1/6/2004 CHECK NO. 055222 VENDOR DISCOUNT NET 56-389 412 No.P 055222 CONSOLIDATED COMMERCIAL ACCOUNT II' 0 5 5 2 2 2 II' I: 0... * 20 j B ~ 5 I: O. 2 ? B ~ b II' AMOUNT *******$100.00******1 NOrYAI.II;\;AFT¡¡¡¡U')'\f\~Y<¡¡._ "'.' , . ,.--." :f.~·:·.;:'<:: ~:::::: ::::::: ::::~::::::i::'i?;;' ,,' .;::;.~~:}~~:' }:~:.! :\:.:~':.:~ '.. ".. ,¢P;t ...r,"'~1:···~_H""""'''d .' .' p.'.., .... ", ... h..., ¡ L{"g~Ç. .~::f,:¡)~£;~¡~~~;;~ :;:;'8 H . . . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIA TELETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME /77 Pu (J.- c/ 3 PTD# 2öc/--O-3Î ~velopment Service CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LA TERAL (If API number last two (2) digits are between 60-69) Exploration Stratigraphic "CLUE" Tbe permit is for a new weUboresegment of existing well Permit No, API No. Production. sbould continue to be reported as a function' of tbe original API Dumber. stated above. BOLE In accordance witb 20 AAC 25.005(f), aJI records, data and logs acquired for tbe pilot bole must be clearly differentiated In both name (name on permit plus Pß) and API Dumber (SO 70/80) from records, data and logs acquired for we)) (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject ·to fuD compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Companv Name) assumes tbe liability of any protest to tbe spacing . exception tbat may occur. An dry ditcb sample sets submitted to tbe Commission must be in no greater than 30' sample intervals from below tbe permafrost or from wbere samples are first caught and 10' sample intervals through target zones. o o Well bore seg Annular Disposal On Program DEV On/Off Shore 11328 Unit Well Name: MILNE PT UNIT KR C-43 DEV I PEND GeoArea 890 InteJ\lal & TD jnADL 0355017. Surta~ location in ADL0047~34; Top Prod MPU KupaJukRi\ler POo.l,.CQ 43.2B. . Yes _Y.es Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes Yes NA NA .NA NA Initial ClasslType MILNE POINT, KUPARUK RIVER OIL - 525100 NC Company BP EXPLORATION (ALASKA) PeUl} it fee <!ttacheß Field & Pool .Le<!senumber .apprOPJiate narne _aod lJumb_er WelUo.cated in.a. clefineß pooL Well Io.cated proper .distance. from driJling uni Well Io.cated proper _distance_ from o.tber wells b9undary. .S.utficient acreage available in.drillilJg unjt js weJlbo.re plaUncJuded Itdevi<!ted 2 3 4 5 6 7 8 9 PTD#: 2040390 Administration _U.nique well 9perator only <!ffeçted party .Oper.ator bas_appropriate. bond inJorce 10 11 Permit C<l11 be issued wjtbo.ut co_nservation order Permit can be issued witbo.ut ad.ministrati"lle. approval 15-day wait in.comrn.ents). (For be approved before Wel AJI wells.witninJl4Juile_area_of review idelJtified (For5-ervj~weIlOf!ly) Pre-produced iojeÇÌQJ; ßuratio.n_of pre-proßuGtionles5- than.:3 montbs (For_service well onJy) 10# Order # (put I1jectiolJ Can permit Io.cated within <!rea <!Ild_strata .authorized by_ 12 13 14 15 16 17 Date 2/25/2004 Appr SFD fro.m exjstil1g pa.d, WelJ drilled ,11.11 aquifers ex.ernpted,AØCFR 1~7.j02(b)(3) Wa.st to .alJ apPJoved dispoß<!1 wet No. f!:1seJ\le_pjtplanlJed, Rig js.equippedwith ßteelpits. Well screenec! byJW and passes major nst< çritena, . 12.0 EMW io several zones. Planned MW.upjo 12.6 PP-9. Maximum expected BHP ~5QOpßiBQ~ test. TubuJar teßts plaoned jo 4500 psi. M8SP calculate.dat 3649 psi Yes NA Yes No_ Yes Yes Yes NA _Yes Yes _Y.es Yes Yes Yes Yes No_ NA Consißtency.h.as been issued_ fortbis pr.oiect A.CMP F.indingof C.ooduclor _S_urface .casing_pJotects al stri ng. provided & surf Cßg known USDWs .CMT. v.ol adequ.ate_ to çirclllale.on.cond_uctor .CMT. vol adeQuate_ to tie-iJlJo.ng _string to surf csg. .CMT. will cover.all !<lJown.productive borizons C,.T~ B.&.p.ermafrost for reserye pit _C_asing de.sigl1s <!d.equate oJ has.a. 10-403 fo.r abandonmeJlt beel1 OIPPJoved tan.kage_ Adequate Ita. re-drilt Aßequate wellbore separOltjo_n .proposed tmeet regulations. lisLadequate Jtdiverter Jequired, does _DrillilJg tlujd. program schematic.& eq.uip 18 19 20 21 22 23 24 25 26 27 28 29 30 Engineering Appr Date TEM 3/1/2004 151tM '\, psig in_comments) 84) (put to C.hokemanjfold complies w/API RP-53 Work will occur without .BOPEs,.dothey meet regulation _SOPEpJess ratiog appropriate; test (May 31 32 33 34 operation.shutdown Hjg is equjpped with s.enSOJS and .alarms. MPU C-? & MPU _L-6. h_ave meas.urad Jow lev.elsof H2S; .both are_within Jmileof MPU C~3, Expected pressure-9radientiSlJo.rmaldown toHRZ, then 12.0 PP-9pressure lse¡cpected.. Mud program Mud sh.ould preclude_ H2.S o.n.tbe rig~ No Yes NA NA NA wells within 80R verified (for s.ervi~ welJ only) c.al1 be issued wlo. hydrogen s.ulfide me<!s.ures Permit .Data. PJeseoted on. pote_ntial oveJpres.sure .zones .Selsl11icana1ysjs of sballow g<!s.zol1es. off-sh9(e) Is presence o.f H2S gas_ prOQable MecbanlcOlI.CPlJditiol1 of 35 36 37 38 39 Geology desi.gned. accordil1gly. .(if .Seabedconditiol1 survey Co.nta.ct Date 2/25/2004 Appr SFD ;¡~f Date weekly progress Engineering Commissioner namelphone.for ~ Date: 3Je Geologic Commissioner: [)ì~ e e Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding infonnation, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Dr~ing Services LIS Scan Utility e ;<'0 '1- 03 cr /25 7Ji $Revision: 3 $ LisLib $Revision: 4 $ Fri May 28 12:00:12 2004 Reel Header Service name............ .LISTPE Date. . . . .. . . . . . . . . . . . . . . .04/05/28 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. . . . . . . . . . . . . . . . . . . . .04/05/28 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 MPC-43 500292320000 B.P.Exploration (Alaska) Inc. Sperry Sun 28-MAY-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002979490 T. MCGUIRE D. GREENE MWD RUN 2 MW0002979490 T. MCGUIRE D. GREENE MWD RUN 3 MW0002979490 T. MCGUIRE D. GREENE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002979490 R. FRENCH D. GREENE MWD RUN 5 MW0002979490 J. STRAHAN E. VAUGHN MWD RUN 6 MW0002979490 J. STRAHAN E. VAUGHN # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) 10 UN 10E RECE\\JED \\ \\; 0 9 2.ßû4 vVJ .. ~OU& GaSCoos.eomm\ss\Qr AnCbOf896 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 7 MW0002979490 J. STRAHAN E. VAUGHN 1344 2290 KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: e .00 51.10 16.40 e # 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) 112.0 9363.0 12883.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 - 4 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. MWD RUNS 5 - 7 COMPRISED DIRECTIONAL WITH DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4) ¡ AND PRESSURE WHILE DRILLING (PWD). 5. DEPTH SHIFTING/CORRECTION OF MWD DATA WAS WAIVED PER E-MAIL FROM K. COONEY (SIS/BP), DATED 5/27/04, QUOTING AUTHORIZATION FROM MIKIE SMITH (BP GEOLOGIST). MWD DATA ARE CONSIDERED PDC. 6. MWD RUNS 1 - 7 REPRESENT WELL MPC-43 WITH API#: 50-029-23200-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13817'MD/7547'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. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation...... .04/05/28 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: # 1 and clipped curves¡ all bit runs merged. .5000 FILE SUMMARY PBU TOOL CODE GR ROP FET RPD RPM RPS RPX $ e e START DEPTH 68.0 112.5 9331.0 9331.0 9331. 0 9331.0 9331.0 STOP DEPTH 13775.5 13817.0 13768.5 13768.5 13768.5 13768.5 13768.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 68.0 2100.0 MWD 2 2100.0 5607.0 MWD 3 5607.0 7590.0 MWD 4 7590.0 9376.0 MWD 5 9376.0 12895.0 MWD 6 12895.0 13165.0 MWD 7 13165.0 13817.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.............. ....0 Data Specification Block Type.. ...0 Logging Direction..... ....... ... ..Down Optical log depth units...... .....Feet Data Reference Point......... ... ..Undefined Frame Spacing................ .....60 .1IN Max frames per record.......... ...Undefined Absent value.................. ....-999 Depth Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68 13817 6942.5 27499 68 13817 ROP MWD FT/H 0.27 3191.41 239.407 27410 112.5 13817 GR MWD API 12.71 251. 82 80.5129 27416 68 13775.5 RPX MWD OHMM 0.58 1336.54 2.98307 8876 9331 13768.5 RPS MWD OHMM 0.24 1336.41 3.0553 8876 9331 13768.5 RPM MWD OHMM 0.55 2000 8.2457 8876 9331 13768.5 RPD MWD OHMM 0.1 2000 22.6123 8876 9331 13768.5 FET MWD HOUR 0.13 153.76 3.18145 8876 9331 13768.5 First Reading For Entire File......... .68 , ,,- Last Readlng For Entlre Flle.......... .13817 e File Trailer Service name....... ......STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/28 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...... .04/05/28 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: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR SROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 68.0 112.5 STOP DEPTH 2055.0 2100.0 # 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: 20-MAR-04 Insite 66.37 Memory 2100.0 112.0 2100.0 .6 45.2 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 132478 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): SPUD MUD 9.30 160.0 8.0 750 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: e 11.6 e .000 .0 .000 60.8 .000 .0 .000 .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.....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 ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP GR MWD010 MWD010 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 68 2100 1084 4065 68 2100 ROP MWD010 FT/H 4.63 3191.41 182.201 3976 112.5 2100 GR MWD010 API 17.85 124.18 65.842 3975 68 2055 First Reading For Entire File........ ..68 Last Reading For Entire File....... ... .2100 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/28 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...... .04/05/28 Maximum Physical Record. .65535 File Type............... .LO e 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 ROP $ 3 e header data for each bit run in separate files. 2 .5000 START DEPTH 2055.5 2100.5 STOP DEPTH 5561. 5 5607.0 # 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... ..0 Logging Direction........... .... ..Down Optical log depth units... ....... .Feet 21-MAR-04 Insite 66.37 Memory 5607.0 2100.0 5607.0 52.4 69.3 TOOL NUMBER 132478 13.500 112.0 SPUD MUD 9.50 90.0 8.0 520 10.0 .000 .000 .000 .000 .0 95.0 .0 .0 Data Reference Point... .~...... . Undefined Frame Spacing...... .............. .60 .1IN Max frames per record............ . Undefined Absent value................. .... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP SGRB MWD020 MWD020 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 2055.5 5607 3831.25 7104 2055.5 5607 ROP MWD020 FT/H 8.38 1028.99 360.667 7014 2100.5 5607 SGRB MWD020 API 12.71 131.62 68.578 7013 2055.5 5561. 5 First Reading For Entire File......... .2055.5 Last Reading For Entire File.......... .5607 File Trailer Service name..... ....... .STSLIB.003 Service Sub Level Name. . . Version Number..... ......1.0.0 Date of Generation...... .04/05/28 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.. .....04/05/28 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 GR ROP $ 4 header data for each bit run in separate files. 3 .5000 START DEPTH 5562.0 5607.5 STOP DEPTH 7545.0 7590.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): 22-MAR-04 Insite 66.37 Memory 7590.0 e 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 Service Order DEPT ROP MWD030 SGRB MWD030 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 5607.0 7590.0 65.0 69.8 TOOL NUMBER 132478 13.500 112.0 SPUD MUD 9.40 130.0 8.0 550 10.0 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 95.0 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 5562 7590 6576 4057 5562 7590 ROP MWD030 FT/H 0.71 2175.47 279.169 3966 5607.5 7590 SGRB MWD030 API 19.16 139.97 70.3623 3967 5562 7545 First Reading For Entire File......... .5562 Last Reading For Entire File.......... .7590 e e File Trailer Service name............ .STSLIB.004 service Sub Level Name... Version Number..... ..... .1.0.0 Date of Generation...... .04/05/28 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.. .... .04/05/28 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 GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 7545.5 7590.5 STOP DEPTH 9332.5 9376.0 # 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: 24-MAR-04 Insite 66.37 Memory 9376.0 7590.0 9376.0 63.7 68.6 # TOOL STRING (TOP TO VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY TOOL NUMBER 132478 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 13.500 112.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): SPUD MUD 9.50 55.0 8.0 700 6.3 e RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: e .000 .000 .000 .000 .0 95.0 .0 .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.....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 ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Service Order Units FT FT/H API Size 4 4 4 Nsam 1 1 1 Code Offset o 4 8 Channel 1 2 3 Name DEPT ROP SGRB MWD040 MWD040 Rep 68 68 68 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7545.5 9376 8460.75 3662 7545.5 9376 ROP MWD040 FT/H 0.36 1088.59 151. 294 3572 7590.5 9376 SGRB MWD040 API 23.04 133.97 82.7868 3575 7545.5 9332.5 First Reading For Entire File......... .7545.5 Last Reading For Entire File.......... .9376 File Trailer Service name. ........... .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ....04/05/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name......... ..STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/05/28 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name..... ..STSLIB.005 e Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPS RPX GR ROP $ 6 e header data for each bit run in separate files. 5 .5000 START DEPTH 9331.0 9331.0 9331.0 9331.0 9331. 0 9333.0 9376.5 STOP DEPTH 12849.5 12849.5 12849.5 12849.5 12849.5 12857.0 12895.0 # 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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: $ # 29-MAR-04 Insite 66.37 Memory 12895.0 9376.0 12895.0 21.3 68.6 TOOL NUMBER 124725 134760 9.875 9363.0 LSND 9.50 54.0 8.5 780 4.6 1.100 .620 2.300 1.750 68.0 126.5 63.0 60.0 'f' . e d Data Format Specl lcatlon Recor 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 ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O e Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9331 12895 11113 7129 9331 12895 ROP MWD050 FT/H 7.36 458.7 207.824 7038 9376.5 12895 GR MWD050 API 38.19 139.46 96.039 7049 9333 12857 RPX MWD050 OHMM 1.12 1336.54 3.06912 7038 9331 12849.5 RPS MWD050 OHMM 1.15 1336.41 3.14363 7038 9331 12849.5 RPM MWD050 OHMM 1.1 1853.25 3.74638 7038 9331 12849.5 RPD MWD050 OHMM 0.1 2000 8.58958 7038 9331 12849.5 FET MWD050 HOUR 0.13 80.7 1.49456 7038 9331 12849.5 First Reading For Entire File......... .9331 Last Reading For Entire File......... ..12895 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation..... ..04/05/28 Maximum Physical Record..65535 File Type.. ... .......... .LO Next File Name......... ..STSLIB.007 Physical EOF File Header Service name........... ..STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..04/05/28 Maximum Physical Record. .65535 File Type............. ...LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: 7 header data for each bit run in separate files. 6 DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPX RPS RPD RPM GR ROP $ e .5000 START DEPTH 12850.0 12850.0 12850.0 12850.0 12850.0 12857.5 12895.5 STOP DEPTH 13143.5 13143.5 13143.5 13143.5 13143.5 13150.5 13165.0 # 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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 e 04 -APR-04 Insite 66.37 Memory 13165.0 12895.0 13165.0 19.4 20.0 TOOL NUMBER 160788 148574 6.750 12883.0 LSND 10.10 48.0 10.0 600 3.8 .750 .390 .850 1.100 68.0 136.6 70.0 60.0 e . e Max frames per record............ .Undeflned Absent value... .................. .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12850 13165 13007.5 631 12850 13165 ROP MWD060 FT/H 3.42 292.84 146.97 540 12895.5 13165 GR MWD060 API 42.39 251. 82 140.143 587 12857.5 13150.5 RPX MWD060 OHMM 0.58 3.89 1.69961 588 12850 13143.5 RPS MWD060 OHMM 0.24 58.9 1.99949 588 12850 13143.5 RPM MWD060 OHMM 0.55 2000 73.341 588 12850 13143.5 RPD MWD060 OHMM 0.59 2000 232.191 588 12850 13143.5 FET MWD060 HOUR 0.14 153.76 24.6431 588 12850 13143 .5 First Reading For Entire File......... .12850 Last Reading For Entire File.......... .13165 File Trailer Service name....... ... ...STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... .., .04/05/28 Maximum Physical Record..65535 File Type....... ........ .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name... ......... .STSLIB.008 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .04/05/28 Maximum Physical Record. .65535 File Type............. ...LO Previous File Name. .... ..STSLIB.007 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPD RPM RPS 8 header data for each bit run in separate files. 7 .5000 START DEPTH 13117.0 13117.0 13117.0 STOP DEPTH 13768.5 13768.5 13768.5 RPX FET GR ROP $ e 13117.0 13144.0 13151.0 13165.5 13768.5 13768.5 13775.5 13817.0 # 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 EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY 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..................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 Uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT e 06-APR-04 Insite 66.37 Memory 13817.0 13165.0 13817.0 5.8 18.0 TOOL NUMBER 160796 148574 6.750 12883.0 LSND 12.30 51.0 9.0 1000 3.4 1. 700 .800 1. 200 3.500 65.0 145.4 65.0 65.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 ROP MWD070 FT/H tt 1 68 4 2 e GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 13117 13817 13467 1401 13117 13817 ROP MWD070 FT/H 0.27 225.23 90.7719 1304 13165.5 13817 GR MWD070 API 28.18 165.41 104.28 1250 13151 13775.5 RPX MWD070 OHMM 0.92 38.72 3.04945 1303 13117 13768.5 RPS MWD070 OHMM 0.91 38.27 3.00236 1303 13117 13768.5 RPM MWD070 OHMM 0.9 31.67 2.90645 1303 13117 13768.5 RPD MWD070 OHMM 0.91 28.36 2.92569 1303 13117 13768.5 FET MWD070 HOUR 0.41 22.02 2.5837 1250 13144 13768.5 First Reading For Entire File. .... .....13117 Last Reading For Entire File..... ..... .13817 File Trailer Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .04/05/28 Maximum Physical Record. .65535 File Type............... .LO Next File Name........ ...STSLIB.009 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .04/05/28 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. . . . . . . . . . . . . . . . . . . . .04/05/28 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