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Home My WebLink About203-165 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. a 0 3 - L ~ 5 Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN DI~AL DATA 'Ø"'Oiskettes, No. f o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Color Items: o Greyscale Items: o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: NOTES: o Other:: BY: ~ Date: to :)0 D~ 151 YY\f Project Proofing BY: C Maria) "-.- 11I11111111111 "III rY\f Date: {O ðD / D(P , -:3 X 30 = q 0 Date 0/ a.õ ;o~ 151 Scanning Preparation BY: ~ + Lf = TOTAL PAGES 2/j (Count does not i~~~ude cover 5 eetffi r Production Scanning Stage 1 Page Count from Scanned File: c¡ S- (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YES BY: ~ Date:~/áO/D~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES 11111111111111 "III NO ') 151 ~' NO BY: Maria Date: 151 11111111111I1111111 Scanning is complete at this point unless rescanning is required. ReScanned III 11111111I11 ,,11/ BY: Maria Date: 151 Comments about this file: Quality Checked 11111111111I 1111111 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N REPO OF SUNDRY WELL OPERA ONS 1. Operations Performed: ^ Abandon ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Alter Casing ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To,Drill Number. BP Exploration (Alaska) Inc. ^ Development ^ Exploratory ~ 203-165 3. Address: ®Service ^ Stratigraphic .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23180-00-00 7. Property Designation: 8. Well Name and Number: ADL 028263 PBU W-400 9. Field /Pool(s): Prudhoe Bay Field / Ugnu 10. Present well condition summary Total depth: measured 5285 feet true vertical 4391 feet Plugs (measured) None Effective depth: measured 5186 feet Junk (measured) 5186' true vertical 4306 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' _ ..1.490 470 Surface 3001' 13-3/8" 3030' 2673' 4930 2270 Intermediate Production 5246' 9-5/8" 5272' 4380' 6870 4760 Liner ~Rj~P ~ ~ ~ . ~ ~j,R ~1 S~ ~ . .~3,~ {~ } Al w~ WY' JW+~ W Y Perforation Depth: Measured Depth: 4167' - 4597' True Vertical Depth: 3436' - 3803' Tubing (size, grade, measured and true vertical depth): 5-1/2", 17# L-80 3447' 2922' Packers and SSSV (type, measured and true vertical depth): Gravel Pack Assembly: 5-1/2", 17#, L-80 with Baker'SC-1' packer and Baker'D' 4027' & 4602' 3319' & 3807' packer 11. Stimulation or cement squeeze summary: Intervals treated (measured): a~.~~~ o ~ zoo Treatment description including volumes used and final pressure: ~11~~k~ ~~ Gas Gene. G~'ssif~n 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 15,289 -0- 1,160 Subsequent to operation: 20,624 -0- 885 13. Attachments: ^ Copies of Logs and Surveys run 14. Well Class after work: ^ Exploratory ^ Development ®Service Re ort of Well O erations ® Dail y p p ® Well Schematic Diagram 15. Well Status after work: ^ Oil ^ Gas ^ WDSP~ ^ GSTOR ~'1{~Lt'tiQ~- JCIr,,~L~ wLJ~^ WAG ^ GINJ ^ WINJ ^ SPLUG 16. 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 Hank Baca, 564-5444 310-170 Printed Name Terrie Hubble Title Drilling Technologist ~ ~~~ ~~ Prepared By Name/Number: Date 0~ I ¢ Ph Signature (~(,, one 564-4628 erne Hubble, 564-4628 f Form 10-404 Revised 07/2009 Su mit Original Only RBDMS AUG Q'6 ZO ~ ~-~ -~~ ~/,-~ • • North America -ALASKA - BP P.~yE~ ~ of 2 Operation Summary Report .............._ __ _ _ Common Well Name: W-400 DIMS AFE No Event Type: MOBILIZATION (MOB) Start Date: 7/1/2010 End Date: 7/5/2010 X4-OOR4K-E (370,000.00 ) ~ _ _ _ Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To I Hrs Task Code NPT i NPT Depth Phase Description of Operations 7/1/2010 00:00 - 23:59 23.98 MOB P PRE DOYON 16 FINALIZING COMPLETION OF ' _ CONOCOPHILLIPS 3N-16A. 7/2/2010 00:00 - 16:00 16.00 MOB ~ P ___ PRE --DOYON 16 WAS RELEASED FROM COP AT ( MIDNIGHT (2400-hrs) ON 7-1-2010. --BP ACCEPTED THE RIG FOR RDMO TO W-PAD AT 0000-HOURS ON 7-2-2010. THE MUD PUMP AND THE AUXILIARY POWER PLANT MODULES '1NERE TRANSPORTED TO W-PAD ON 7-1-2010. j --RDMO REQUIRED PAD WORK TO ALLOW THE i RIG CAMP TO GET AROUND THE RIG. I I I ~ --0100-hrs TO 1600-hrs:. REMOVE BUILD-UP I, ~I j i GRAVEL FROM PAD. PAD IS EXTREMELY SOFT, i SO FRONT-END LOADER WAS REQUIRED TO COMPACT AREAS ON THE PAD. MOVE ULSD TRAILER AND CREW CHANGE TRAILER OUT OF THE WAY. MOVE-EXTERNAL MUD-PITS MODULE TO STAGINGAREA. PREPARE CAMP TO MOVE AROUND RIG. --T600-hr to 2200-hrs: MOVE RIG CAMP TO ~ ~ MOBiLE PAD. - 7/3/2010 00:00 - 12:00 12.00 MOB P PRE °MOVING CAMP, TRUCK SHOP TO MOBILE PAD 12:00 - 00:00 ~ 12.00 .MOB P PRE' SPOT CAMP, TRUCK SHOP AT MOBILE PAD i f -PREPARE SUB FOR MOVE _ 7/4/2010 i 00:00 - 11:00 11.00 ~ MOB P' PRE MOVING RIG; i i i 1100-HRS--RIG AT Y INTERSECTION SOUTH OF i KOC - - - 11:00 - 12:30 1.50 - MOB P _ PRE 1230-HRS--RIG AT KOC 12:30 - 78:30 6.00 MOB P PRE 1830-HRS--RIG AT MILNE POINT TURNOFF INTERSECTION 18:30 - 00:00 5.50 MOB P PRE 2359-HRS--RIG AT Z PAD ACCESS ROAD 7/5/2010 00:00 - 03:00 I 3.00 MOB P PRE RIG TURNING ONTO W-PAD ACCESS ROAD 03:00 - 05:30 2.50 MOB P PRE RIG MOVING DOWN W-PAD ACCESS ROAD. 0530-HRS--RIG REACHED W-PAD. THERE WERE i ~ ~ NO INCIDENTS, INJURIES, OR ENVIRONMENTAL i ' i RELEASES DURING THE ENTIRE RIG MOVE. TOOL SERVICES PERSONNEL WERE EXTREMELY t SAFE AND EFFICIENT IN HANDLING THE BP END OF THIS RIG MOVE. - GAVE AOGCC 24 HR NOTICE OF UPCOMING i BOP TEST Printed 8/4/2010 2:23:34PM r~ r North America -ALASKA - BP Page 2 of 2. Operation Summary Report _ ___ __-- Common Well Name: W-400 DIMS ~ AFE No Event Type: MOBILIZATION (MOB) Start Date: 7/1/2010 End Date: 7/5/2010 X4-OOR4K-E (370,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task Code i NPT NPT Depth Phase Description of Operations (hr) 05:30 - 16:00 I 10.50 MOB ~ P (ft) PRE ~ -- --REMOVE BOOSTERS. PREPARE BOP STACK ( i I PEDESTAL AND MOVE BOP STACK FROM ~ ~ TRAVEL CRADLE TO PEDESTAL. ' ( ~ --0800 TO 1200--HAVE GRADER SMOOTH PAD. ~ REMOVE WELLS SUPPORT SCAFFOLD FROM '' TREE WITH FORKLIFT. L/D DOUBLE RIG MATS TO ~ ~ RROVIDE CLEARANCE FOR 4-PREVENTER BOP STACK: ~ --PREPARE TO RAISE DERRICK AND SWING '~ ( AROUND TO CRAWL UP ONTO RIG MATS. - AOGCC REP JEFF JONES CALLEDAT 0630 AND WAIVED WITNESS TO BOP TEST CONTINUE PREPARING RIG FOR OPERATIONS --' R-IG ON MATS AT 1500 HRS _ 16:00 - 19:00 I 3.00 MOB P PRE ; ~ qKE ON 8.g PPG NaCI INTO PITS, CHECK LINES T ' -ACCEPT RIG AT 1900 HRS Printed 8/4/2010 2:23:34PM • C~ North America -ALASKA - BP F'ayE ~ of s Operation Summary Report ___ _ _ -- _ _ _ _ __ _ _ _ __ Common Well Name: W-400 DIMS AFE No Event Type: WORKOVER (WO) i Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To ~ Hrs Task Code NPT NPT Depth Phase Description of Operations ____ ____ (hr) _ (ft) _ _ 7/5/2010 19:00 - 20:00 1.00 WHSUR P WHDTRE FINISHED TAKING ON FLUIDS AND TESTING ( LINES; RIG ACCEPTED AT 1900 ( - DHD CONDUCTS FLUID LEVEL CHECK; CANNOT .DETERMINE FLUID LEVEL 20:00 - 21:00 1.00 WHSUR P __ WHDTRE RU.DSM LUBRICATOR -PRESSURE TEST TO 500 PSI -GOOD TEST 21:00 _ - 21:30 0.50 WHSUR P _ WHDTRE PULL BPV 21:30 - 23:00 1.50 WHSUR P WHDTRE ~ RD DSM LUBRICATOR 23:00 - 23:30 ~ 0.50 WHSUR P WHDTRE ' RU LINES TO TREE PRESSURE TEST LINES TO 2500 PSI -GOOD ' TEST ' _ 23:30 - 00:00 0.50 KILLW P INTERN BEGIN-0ISPLACING OUT 9:8 PPG FREEZE PROTECT WITH 8:9 PPG NaCI ' 7/8/2010 y~ 00:00 - 02:00 j 2.00 KILLW P INTERN - 210 GPM,.350 PSI __ DISPLACE WELL FROM 9.8 PP IESEL FREEZE PROTECT TO 8.9 PPG NaCI BRINE AT 210 GPM, 350 PSI -TOTAL CIRCULATION OF 575 BBLS 02:00 - 02:30 I 0.50 KILLW P INTERN MONITOR WELL FOR PRESSURES--WELL ON ~ ~ VACUUM. - RIG DOWN FROM DISPLACEMENT ____ 02:30 - 07:00 4.50 ' 'WHSUR P ~ WHDTRE DRY ROD IN TWC -PRESSURE TEST FROM ABOVE TO 3500 PSI FOR 10 MIN -USING CONSTANT HOLE FILL OF 40-BPH OF j 8.9 PPG BRINE AFTER STOPPING CIRCULATION ' -WAITING ON FLUID BEFORE PRESSURE TESTING FROM BELOW TO 500 PSI FOR 10 MIN -CONCURRENT OPS: SPOTTING CENTRIIIFT SPOOLING UNIT. FORKLIFT OPERATOR AND CENTRILIFT PERSONNEL SET UP EMPTY SPOOL I IN SPOOLER. i -FILL IA WITH 60 BBLS OF FLUID. ~ -TEST TWC WITH ROLLING TEST FOR 10 MIN. AT 9.5 BPM AND 520 PSI. PUMPED 30 BBLS TO CATCH PSI. 07:00 - 07:30 0.50 WHSUR P WHDTRE BLOW DOWN CHOKE AND CEMENT LINE. I -RD EQUIPMENT. _ - _ } 07:30 - 13:30 6.00 I WHSUR P I WHDTRE p,JSM FOR N/D TREE. -GATHER TOOLS AND N/D TREE, ADAPTER SPOOL. -REMOVE WING VALVE AS INOPERABLE. -SECURE TREE IN CELLAR. -CAP I-WIRE. -CHECK HANGER THREADS WITH 7 TURNS. 13:30 - 19:30 6.00 BOPSUR P DECOMP N/U BOPE. ~ -CHANGE RAM CONFIGURATION. I i -DRESSED WITH 2-7/8" X 5" VBR ON BOTTOM, ~ BLIND SHEARS, 3-1/2" X 6" VBRS. Printed 8/4/2010 2:24:31 PM il~ North America -ALASKA - BP Face z of~~ Operation Summary Report - _ _ __ __ - Common Well Name: W-400 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations --- - 19:30 - 20:30 ~- (hr) 1.00 BOPSUR _ P (ft) DECOMP R/U TO TEST BOPE. -BRING UP TEST JTS. i ~ -R/U TEST CHART AND EQUIPMENT. __ ___ _ 20:30 - 00:00 __ 3.50 BOPSUR P DECOMP TEST BOPE PER AOGCC REGS, PERMIT TO DRILL, AND WELL PLAN TEST TO 250 PSI LOW AND 3,500 PSI HIGH. -TEST LOWER VBRS WITH 2-7/8" AND 4" TEST .JOINTS: -TEST UPPER VBRS WITH 4" AND 5-1/2"TEST JOINTS:. -TEST ANNULAR WITH 2-7/8"TEST JOINT. TEST WITNESS WAIVED BY JEFF JONES OF AOGCC. -WITNESSED BY BP WSL JOHN WILLOUGHBY, DOYON TOUR PUSHER GLEN HERMAN. I -MAINTAIN CONSTANT HOLE FILL OF 40 BPH OF i ~ - 8.9 PPG BRINE. 7/7/2010 00:00 - 06:30 6.50 BOPSUR P DECOMP TEST$OPE PER AOGCC REGS, PERMIT TO DRILL,_AND WELL PLAN .TEST TO 250 PSI LOW AND 3,500 PSI HIGH. -TEST LOWER VBRS WITH 2-7/8" AND 4" TEST JOINTS. -TEST UPPER VBRS WITH 4" AND 5-1/2" TEST JOINTS. -TEST ANNULAR WITH 2-7/8" TEST JOINT. I -KILL HCR SERVICED, RETESTED GOOD. I, TEST WITNESS WAIVED BY JEFF JONES OF AOGCC. ~ -WITNESSED BY BP WSL JOHN WILLOUGHBY, I I DOYON TOURPUSHER GLEN HERMAN. -MAINTAIN CONSTANT HOLE FILL OF 40 BPH OF ~ 8.9 PPG BRINE THROUGHOUT ALL OPERATIONS. _ 06:30 - 07:30 1.00 BOPSUR P DECOMP SERVICE TOP DRIVEgND DRAWWORKS. 1 07:30 - 11:00 3.50 BOPSUR N SFAL DECOMP CHANGE OUT UPPER IBOP -STEM PACKING ~ __ LEAKING. - 11:00 - 11:30 0.50 BOPSUR j _ P DECOMP TEST IBOP TO 250-PSI LOW AND 3500-PSI FOR 5-CHARTED MINUTES EACH TEST. j -TEST WITNESSED BY BP WSL ABBIE BARKER I AND DOYON TOOLPUSHER SAM DYE. -I 11:30 - 12:00 ------- __ 0.50 ~ BOPSUR - - __ P i DECOMP RD TEST EQUIPMENT. - 1 12:00 - 13:00 1.00 DHB P DECOMP pU DUTCH RISER AND RUN IN DUTCH RISER LDS. I -PU DSM LUBRICATOR AND PRESSURE TEST TO i j ! ~ i ~ 500-PSI. GOOD TEST. -LUBRICATE OUT TWC. WELL ON VAC. -LD LUBRICATOR AND TWC. -LD DUTCH RISER SYSTEM. a~ Printed 8/4/2010 2:24:31 PM North America -ALASKA - BP Page a or r Operation Summary Report Common Well Name: W-400 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task ~ Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 13:00 - 14:30 1.50 KILLW P DECOMP CLOSE BLIND RAMS AND BULLHEAD 300-BBLS OF 8.5-PPG SEAWATER DOWN TUBING AND IA SIMULTANEOUSLY. -PUMP AT 5.0-BPM WITH INITIAL BULLHEAD PRESSURE OF 240-PSI. FINAL BULL HEAD PSI AT 450. ~ =BIM OPS -INSTALL SPINNERS ON IRON _ 1 _ _ ROUGHNECK. __ 1 14:30 - 15:30 1.00 ~ KILLW P DECOMP MONITOR WELL. ~ -INITIAL,FIOW DECREASING TO STATIC. -OPEN BLINDS AND CONTINUE TO MONITOR WELL. VERY SLIGHT-FLOW NOTED. -DISCUSS SITUATION WITH RWO ENGINEER AND DECIDE TO CBU X 2. 15:30 - 16:30 1.00 KILLW P DECOMP . LINE UP AND CIRCULATE THE LONG WAY. -PUMP AT 7 BPM-AND 810 PSI. -LOSSES WHILE PUMPING ARE - 200 BPH. __ 16:30 - 17:30 1.00 KILLW ~ P DECOMP MONITOR,WELL. -WELL_FLOWED BACK @ -20 BPH. 17:30 - 18:30 ~ 1.00 KILLW P DECOMP SHUT IN THE WELL AND MONITOR PRESSURE. -0 PSI PRESSURE BUILD__UP. 18:30 - 19:00 0.50 KILLW - P DECOMP MONITOR WELL. -WELL FLOWING BACK AT - 15 BPH. -SPOKE WITH TOWN ENGINEER AND DECIDED TO INCREASE WT TO 8.6 PPG AND CIRCULATE AROUND AT A SLOW RATE. THIS WILL INCREASE BOTTOM HOLE BY 38 PSI. 19:00 - 20:00 __ 1.00 KILLW ' - P _ DECOMP WEIGHT UP BRINE FROM 8.4 PPG TO 8.6 PPG IN THE PITS. 20:00 - 22:00 2.00 KILLW P DECOMP CIRCULATE WELL AT 3 BPM WITH 120 PSI WITH 8.6 PPG IN AND 8.4 PPG OUT. -AT TUBING VOLUME, 76 BBLS AWAY PRESSURE DECREASED TO 90 PSI AT THE SAME RATE LOBBING - 36 BPH. -AT 180 BBLS AWAY PRESSURE INCREASED TO 120 PSI. -AT 297 BBLS AWAY SEEING AND INCREASE IN BRINE WEIGHT. 8.5 PPG. -AT 300 BBLS AWAY SEEING AND INCREASE TO 8.6 PPG IN FLUID OUT. ~ -BRING RETURNS BACK TO PITS AND GET DYNAMIC LOSS RATE OF 60 BPH AT 3 BPM AND 120 PSI. ~ I -SHUT DOWN PUMPS. ~ ~ _ -TOTAL LOSSES WHILE PUMPING IS 68 BBLS.. Printed 8/4/2010 2:24:31 PM r~ North America -ALASKA - BP Page 4 of 8 Operation Summary Report Common Well Name: W-400 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) __ 22:00 - 23:00 1.00 KILLW P DECOMP MONITOR WELL FOR RETURNS WITH PUMPS j OFF. -WELL IS STATIC SO OPEN BLINDS AND VISUAL MONITOR. WELL TAKING SMALL AMOUNT OF ~ FLUID VISUALLY. I -CIRCULATE OVER TOP OF THE HOLE AND MONITOR WELL FOR 30 MIN. -LOSS RATE STATIC OF -30 BBLS/HR. -SIM OPS -PJSM FOR R/U CENTRILIFT. -R/U CENTRILIFT EQUIPMENT. 23:00 - 00:00 1.00 CLEAN P DECOMP M/U LANDING JOINT. -M/U X-OVER AND SPACE OUT THROUGH FLOOR. -SCREW X-OVER INTO HANGER WITH 7 TURNS. -MAINTAIN CONSTANT HOLE FILL. 7/8/2010 _____ _ 00:00 - 00:30 ~ 0.50 PULL ~ P DECOMP PJSM WITH CREW, HALLIBURTON, CENTRILIFT GUYS. DISCUSSING WELL CONTROL, DROP OBJECTS. KEEPING FOCUS AND COMMUNICATION THROUGHOUT THE JOB. -BACK OUT LOCK DOWN SCREWS. -PULL HANGER TO FLOOR. i -PULLED HANGER AT 110K AND COMPLETION ~ j AT 107K UP WEIGHT. j -NOTICED PENETRATE WAS BURNED AND CUT - ESP CABLE AND TESTED DOWN TESTING GOOD. j -HALLIBURTON GAUGES TESTED GOOD. -DISCUSSED WITH TOWN ENGINEER AND I ' DECIDED TO MOVE FORWARD AS PLANNED. _ - _ --- -- 00:30 - 02:00 1.50 PULL _ P DECOMP CIRCULATE WELL AT 3.0 BPM AND 80 PSI WITH -18 BPH LOSSES. -INCREASE RATE TO 3.5 BPH AND 110 PSI WITH ~ _ ~ _ __ 9 BPH LOSS RATE. -CONTINUE TO CIRCULATE BOTTOMS UP. 02:00 - 03:30 1.50 PULL P DECOMP MONITOR WELL VISUALLY FOR 15 MINS. -SLOWLY ON A VAC. -MONITOR WELL VIA TRIP TANK. STATIC LOSS RATE 12 BPH. j ~ -tJD HANGER ON FLOOR. i -R/U TO PULL 5-1/2" TUBING. -MAINTAIN CONSTANT HOLE FILL. 03:30 - 10:00 6.50 PULL P ___ DECOMP POH L/D 5-1/2" 17# IBT TUBING. -SPOOL ESP AND I-WIRE CABLES. ~ -STRAPPING TUBING AS WE L/D IN THE PIPE SHED. -USING THREAD PROTECTORS WHILE UD. j -MAINTAIN CONSTANT HOLE FILL AND LOSING 12 BPH. 10:00 - 10:15 0.25 PULL P __ DECOMP MONITOR WELL -FLUID LEVEL DROPPING. X ~ 10:15 - 13:30 3.25 PULL P i DECOMP BREAK OUT AND LD ESP. -ONE PROTECTROLIZER MISSING A STANDOFF I i SECTION. j . -LOSS RATE = 10-BPH. j -MAINTAIN CONTINUOUS HOLE FILL. Printed 8/4/2010 2:24:31PM r~ North America -ALASKA - BP Page 5 of E Operation Summary Report ----__ Common Well Name: W-400 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations 13:30 - 14:30 1.00 j PULL P ~ DECOMP CLEAN AND CLEAR RIG FLOOR. ~ ' -RD CENTRILIFT TRUNK AND SHEAVE. -MAINTAIN CONSTANT HOLE FILL AT 15 BPH. j 14:30 - 16:00 1.50 ____ ~ PULL _ P DECOMP GATHER UP SWS TOOL AND EQUIPMENT. ~ BRING TOOLS AND EQUIPMENT TO RIG FLOOR 16:00 - 17:30 1.50 _ _ PULL P _ DECOMP R/U SWS SLICKLINE PRESSURE CONTROL SYSTEM AND TEST. '-CHANGE OUT CABLE SPOOLS IN SPOOLING UNIT. j -PRESSURE TEST -GOOD TEST. ~ 17:30 - 18:00 0.50 _ _ ___ PULL ___ P -0ECOMP RIH WITH SWS SLICKLINE. -DRIFT WELL WITH.3" OD SAMPLE BAILER AND . j 3-1/2" OD CENTRALIZER. i ~ -RIH WITH NO OBSTRUCTIONS TO TAG FILL AT ~ 5069'. _ _ 18:00 - 18:30 j -_ 0.50 ___ PULL P DECOMP pOH WITH SWS SLICKLINE. I -POH WITH NO OBSTRUCTIONS FROM 5069' __ 18:30 - 19:30 1.00 PULL P OECOMP RIG DOWN SWS SLICKLINE TOOLS AND EQUIPMENT. -L/D DUTCH RISER. 19:30 - 20:30 1.00 RUNCMM P RUNCMP R/U TUBING HANDLING EQUIPMENT. -HANG AND STRING ROPE THROUGH CENTRILIFT SHEAVE. __ ~ -- --- 20:30 - 21:00 0.50 RUNCMM P' RUNCMP GATHER TOOL FOR CENTRILIFT EQUIPMENT. -BRING UP CLAMPS FOR ESP PUMP LINES. --- C -------------------- 21:00 - 00:00 ------ 3.00 RUNCMM P - RUNCMP - PJSM FOR RUNNING ESP. -P/U LOWER TANDEM MOTOR AND VAC FILL ~ WITH OIL. -P/U UPPER TANDEM MOTOR AND VAC FILL WITH OIL. 7/9/2010 00:00 - 09:30 9.50 RUNCMM P __ RUNCMP CONTINUE TO FILL UPPER AND LOWER MOTORS. -PICK UPAND M/U UPPER AND LOWER SEALS. i ~ -PICK UP AND M/U UPPER AND LOWER PUMPS AND DISCHARGE HEAD. -CENTRILIFT MAKE MLE SPLICE AND TEST. GOOD TESTS. j -RU HES I-WIRE SPOOLING UNIT AND SHEAVE ON RIG FLOOR. ~ -MAINTAINING CONSTANT HOLE FILL AT 7.5 BPH. 09:30 - 11:30 2.00 RUNCOM P RUNCMP f~H WITH ESP ON 5:1/2" 17# IBT-M TUBING TO 606'. -MU EACH IBT-M CONNECTION TO THE MARK -USE BEST O LIFE 2000 THREAD COMPOUND ON ALL CONNECTIONS. -INSTALL CANNON CLAMPS ON ALL CONNECTIONS. -MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF -8-BPH. _ _ 11:30 - 12:00 0.50 _ _ RUNCOM~ P i RUNCMP MU HES GAUGE CARRIER TO STRING. -HES INSTALL AND TEST GAUGE. GOOD TEST. Printed 8/4/2010 2:24:31PM ~~ North America -ALASKA - BP Page 6 of 8 Operation Summary Report Common Well Name: W-400 DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) i __ _ _ __ 12:00 - 15:00 3.00 RUNCOM __ P _____ _____ RUNCMP CONTINUE TO RIH WITH ESP ON 5-1/2" 17# L80 j IBT-M TUBING WITH ESP CABLE AND I-WIRE FROM 606' TO 1780'. -MU EACH IBT-M TO THE MARK. -USE BEST O LIFE 2000 THREAD COMPOUND ON ALL CONNECTIONS. INSTALL CANNON CLAMP ON ALL CONNECTIONS. -MAINTAIN CONTINUOUS HOLE FILL WITH LOSS _ _ ~ _ _ _ _ . RATE OF -7-BPH. 15:00 - 16:00 i 1.00 RUNCOM P RUNCMP RU AND CIRCULATE A TBG VOLUME (42-BBLS) i TO FLUSH THE ESP. I ~ =CIRCULATE AT 3-BPM WITH 110-PSI. -CHECKED CONDUCTIVITY OF MOTOR LEADS AND CHECKED I-WIRE TO GAUGES. i -LOSS RATE WHILE CIRCULATING -5-BPH. -RD CIRCULATING EQUIPMENT. 16:00 - 18:00 ~ 2.00 RUNCMM P RUNCMP CONTINUE TO RIH WITH ESP ON 5-1/2" 17# L80 IBT-M TUBING WITH ESP CABLE AND I-WIRE FROM 1780'. -MU EACH IBT-M TO THE MARK. ~~ i -USE BEST O LIFE 2000 THREAD COMPOUND ON ALL CONNECTIONS. i -INSTALL CANNON CLAMP ON ALL CONNECTIONS. -MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE OF -5 BPH _ 18:00 - 19:00 1.00 RUNCMM P RUNCMP TEST ESP AND I-WIRE. -ALL GOOD TESTS. _ 19:00 - 20:00 1.00 RUNCMM P _ RUNCMP CONTINUE TO RIH TO 341 T. -UP WT IS 103K, DOWN WT IS 93K. -MAINTAIN CONTINUOUS HOLE FILL OF -5 BPH. _ _ 20:00 - 21:00 ___ 1.00 I _ RUNCMM P RUNCMP R/U TO CIRCULATE. -BREAK CIRCULATION AT 3 BPM AND 120 PSI. _ _ _ _ -FLUSH PUMP 80 BBLS WHILE CIRCULATING 21:00 - 22:00 1.00 RUNCMM P RUNCMP RIG UP 5-1/2" HANGER. , -M/U_LANDING JOINT FOR WELL CONTROL. _ ___ _ ~ 22:00 - 00:00 2.00 RUNCMM P ____ ~ RUNCMP RUN PENETRATOR THROUGH HANGER. ~ -SPLICE ESP CABLE AND TIE IN. TEST TO 5000 ~ PSI -GOOD TEST. -RUN I-WIRE THROUGH HANGER. LEAVING i i ENOUGH SLACK TO TEST I-WIRE AFTER I HANGER IS IN SEAT. ~ -TEST ESP CABLE AND I-WIRE -GOOD TEST. ESP = 3.45 G-OHMS, 1.8 OHMS EACH PHASE. -TOTAL CLAMPS = 86, PROTECTOLIZERS = 5, i FLAT GUARDS = 2, SS BANDS = 2 -{ -- 7/10/2010 00:00 - 01:00 1.00 RUNCOM P i ~ RUNCMP LAND TUBING HANGER 22' IN ON LANDING JOINT. -RILDS. i -RETEST I-WIRE ON FLOOR. TEST GOT AT I 1159.5 PSI AND 57.4 TEMP. -BREAK OUT LANDING JOINT. -MAINTAIN CONSTANT HOLE FILL AT 6.5 BPH. Printed 8/4/2010 2:24:31PM North America -ALASKA - BP P~~ye ~ of ~ Operation Summary Report _ _ _ ___ Common Well Name: W-400_DIMS AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad I Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM ! Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. j UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) 01:00 - 03:00 2.00 RUNCMM P ___ RUNCMP __ SET TWC_ -RU LINES TO TEST TWC, R/U CHART RECORDER. -TEST TWC FROM ABOVE TO 3500 PSI FOR 10 MIN. GOOD TEST. -ROLLING TEST TWC AT 7.5 BPM FROM BELOW ,~ TO 500 PSI FOR 5 MIN. GOOD TEST. PUMPED 25 ~ I BBLS AWAY TO FORMATION. ___ ' _ _ ___ ~03 00 - 08:00 _ 5.00 ___ BOPSUR P RUNCMP -RDTESTEQUIPMENT. pJSM FOR N/D BOPE. -N/D BOPS. -PULL RAMS OUT OFDOUBLE GATES. -MAKE BOPE BREAKS FOR REMOVING DOUBLE GATES. -MAINTAINING CONTINUOUS HOLE FILL OF 10 08:00 - 12:00 4.00 WHSUR P RUNCMP BPH. ___ PJSM FOR N/U TREE. ~ -N/U ADAPTER FLANGE. -N/U 7-1/16 5K CAMERON TREE. j I _ -OBTAIN FINAL TEST ON ESP CABLE -GOOD TEST. ~ -INSTALL WING VALVE. -PRESSURE TEST HANGER VOID TO 5000 P~ i FOR 30 MIN. -GOOD TEST 12:00 - 14:30 j 2.50 WHSUR P RUNCMP FINISH I-WIRE HOOK UP AND TEST. -GOOD TEST -FINISH INSTALLING WING VALVE. __ 14:30 - 15:30 __ 1.00 WHSUR P RUNCMP R/U AND FILL TREE WITH DIESEL. -TEST TREE TO 5000 PSI FOR 5 MIN. - NO LEAKS -DRAIN TREE_OF DIESEL. _____ 15:30 - 16:00 _ 0.50 WHSUR P RUNCMP R/U DSM LUBRICATOR. -TEST LUBRICATOR TO 500 PSI. -GOOD TEST. -PULL TWC. ___ _ __ 16:00 - 17:30 1.50 WHSUR P RUNCMP R/U CIRCULATION EQUIPMENT. -TEST SURFACE LINES TO 2500 PSI. -GOOD TEST. ~ -LINE UP TO REVERSE CIRCULATE 240 BBLS OF j 9.8 PPG NACL BRINE. -AT 4.5 BPM THE INITIAL CIRCULATING PRESSURE WAS 160 PSI. -AT 4.5 BPM THE FINAL CIRCULATING _ __ _ ___ _ 0 ___ _ __ _ PRESSURE WAS 60 PSI. _ _ 17:30 18:30 1 0 WHSUR i P , RUNCMP R/D CIRCULATION EQUIPMENT. ~ -SET BPV. ~ -PERFORM ROLLING TEST UNDER BPV AT 6 BPM ~ , AND 300 PSI FOR 5 MIN. WITH 9.8 PPG NACL _ _ ~ _-- ~--_ ____ ____ BRINE. -GOOD TEST -R/D LUBRICATOR. _ 18:30 - 19:30 i 1.00 WHSUR P RUNCMP R/D AND BLOW DOWN CIRCULATION LINES -REMOVE DOUBLE ANNULAR VALVE. -SECURE TREE. -WING VALVE ON TREE WAS FOUND TO BE __ ~___ - LOCKED. Printed 8/4/2010 2:24:31PM ~~ r North America -ALASKA - BP Page ~ or ~I Operation Summary Report Common Well Name: W-400_DIMS __ - __ AFE No Event Type: WORKOVER (WO) Start Date: 7/5/2010 End Date: 7/10/2010 X4-OOR4K-E (510,000.00 ) Project: Prudhoe Bay Site: PB W Pad Rig Name/No.: DOYON 16 Spud Date/Time: 10/21/2003 12:0O:OOAM !, Rig Release: 7/10/2010 Rig Contractor: DOYON DRILLING INC. ~ UWI: Active Datum: W-400 @83.2ft (above Mean Sea Level) Date I From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ 19:30 - 00:00 4.50 WHSUR P RUNCMP CLEAN PITS. -R/D FLOOR CIRCULATION LINES. -PREP FOR RIG MOVE. ~ -DSM CAME OUT AND REPAIRED WING VALVE. ~ _ -RELEASE RIG AT MIDNIGHT. Printed 8/4/2010 2:24:31 PM TREE = CNV 7" 5M WELL~-IEAD = INLAY FMC ACTUATOR = KB. ELEV - 83.17 BF. ELEV - KOP= Max Angle= 55 @ 2791' Datum MD = Datum TVD = 88 ~ W-400 ~~ PRINCE CREEK WATER SOURCE WELL 00' SS 20" CSG, 91.1 #, H-40 100 13-3/8" CSG, 88#, L-80 BTC, ID = 12.415" ~~ 3030' 5-1/2" TBG, 17#, L-80, .0232 pbf, ID = 4.892" 3343' #1 ESP POWER CABLE W/ TECH WIRE IN ARMOR WRAP i 1023' 13-3/8" TAM PORT COLLAR 2837' 5-1/2" HES SYMPHONY GAUGE CARRIER w /I-WIRE 3352' -1 DISCHARGE HEAD, 7.25" OD (31 LBS) 3353' BP (#HPHVM AR 1:1) PUMP, is.75" OD (860 LBS) i 3367' BP(#HPHVLT1:1) PUMP, Minimum Gravel Pack Restriction = 3.875" ° ° s.75° OD (860 LBS) ' Safety Shear Sub @ 4064 3390' CENTRILIFTTANDEMSEAL, OD=s.75" ~ (954 LBS) 339T ~PPER MOTOR, 7.25" OD 500 H.P, MODEL HMI UT (3542 LBS) 3421' LOWER MOTOR, 7.25" OD 500 H. P, MODEL HMI LT (3542 LBS) 3445' s-FIN CENTRILIZER, OD = 8.0" (15 LBS) 4027' ~ BKR SG 1 GRAVEL PACK PKR, ID = 4.75" 4033' BKR GPEXTENSION w / SLD SLV, ID = 4.75" 4061' s-5/8" X 5-1/2" XO, ID = 4.95" PERFORATION SUMMARY ~ I REF LOG: ?? 4064' 5-1/2" BLANK PIPEw/ CNTRLZR, ID = 4.892" ANGLE AT TOP PERF: 32° @ 41 s7' Note: Refer to Production DB for historical pert data 4149 BKR 5-1/2" EXCLUDER SCREEN SIZE SPF INTERVAL Opn/Sqz DATE MEDIUM, 17# / FT, 37', ID = 4.892" " 7 18 4167 - 4205 O 05/13/04 4600' 5-1/2" X 4-1/2" XO IBP PIN, ID = 3.990" 7" 18 4331 - 4597 O 05/13/04 FISH - SS BANDS FROM RWO (10/10/04) PBTD 9-5/8" CSG, 47#, L-80, ID = 8.s81" C 4601' BKR E-22 SNAP LATCH SEAL ASSY, ID = 3.875" 4602' BKR "D" PKR, ID = 4.75" 4606' 7" MILL OUT IXTENSION, ID = s.25" 4616' 7" WLEG, ID = 6.180" DATE REV BY COMMENTS DATE REV BY COMMENTS 10/29/03 D-141 SUSPENDED 05/20/04 NOES FINAL COMPLETION 10/10/04 N4ES RWO -ESP C/O 04/24/05 N93S RWO -ESP C/O 07/10/10 D-16 RWO -ESP C/O 07/13/10 HB/SV FINAL DRFT PRINCE CREEK WELL: W-400 PERMff No: 2031 s50 API No: 50-029-23180-00 SEC21, T11N, R12E, 3749' NSL & 1455' WEL BP Exploration (Alaska) • • ~u~us OG~ ~LtQ~~(Q /,~...,~,.~o....~. David Reem Engineering Team Leader BP Ex loration Alaska Inc. P.O. Box 196612 Anchorage, AK 99519-6612 ~s, C~ ~ ' ' Re: Prudhoe Bay Field, Ugnu Pool, PBU W-400 Sundry Number: 310-170 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. 'ncerely, Daniel T. Seamount, Jr. ~j ~ Chair DATED this `day of June, 2010. Encl. ~~,, o ~ ~~'~- o ~ ~.~ r STATE OF ALASKA ALASK~•L AND GAS CONSERVATION COMMIS APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 R~C~IVED~,~~r ~u-~ o ~ zo~o6r~~a 1. Type of Request: AIBSI(8 OtI $t ~8i t!liS. QI11~1'118Sron ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ~ ®Repair Well ^ Change Approved Pr~g~CB~ ^ Suspend ^ Plug Pertorations ^ Perforate -® Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 203-165 , 3. Address: ®Service - ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23180-00-00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: pBU W-400 - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): _ ADL 028263 Prudhoe Bay Field / Ugnu 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (tt): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 5285 - 4391 - 5186 - 4306 - None 5186' Casin Len th Size MD TVD Burst Colla e Structural Conductor 1 8' 2 1 1 8' 149 47 Surface 30 1' 13- /8" 3030' 2673' 4930 2270 Intermediate Production 4 ' - / " 72' 4 6 47 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 4167' - 4597' 3436' - 3803' S-1/2", 17# L-80 3447' Packers and SSSV Type: Gravel Pack Assembly: 5-1/2", 17#, L-80 with Baker'SC-1' Packers and SSSV 4027' & 4602' packer and Baker'D' packer MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 9, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned '}"r ~""«' ^ WAG ^ SPLUG ^ Suspended Commission Representative: ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name David Reem Title Engineering Team Leader Prepared By Name/Number: Signature ~ "~ ~ (~C ~ Phone 564-5743 Date ~ ~ ~ Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: No ity Commission so that a representative may witness ~ ~~ O ~~ Sundry Number: ~~ ^ Plug Integrity IIdBOP Test ^ Mechanical Integrity Test ^ Location Clearance ,~ Soo 8 o P les ~ S ~ . Other: ~ s~ ~nn.+~~~ ~~sf"~~~~ zs'Qo ~ ~ Subsequent Form Required: l0 ~`(0`'{ APPROVED BY ~ / ~ ~ ~ Q Approved By: COMMISSIONER THE COMMISSION Date /// Form 10-403 Revised 01/2010 RBDAAS JUN 1` 01010 ORIGINAL _ ~ /~ Submit In Duplicate ~~, • by ~'~Ga'13a1rr.8~v W-400 Rig Workover (ESP swap) Scope of Work: Pull 5.5" L-80 ESP completion. Replace ESP and re-run completion. It is possible fill will be cleaned out. Engineer: Hank Baca MASP: 1180 psi Well Type: Prince Creek water source Estimated Start Date: June 10"', 2010 W 1 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 2 Set a BPV in the tubin han er. O 3 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. NU and test BOPE to 250 psi low/ 3500si high. Three preventer stack consists of annular, blinds, and 3-1/2" x 6" variable rams. Circulate well out with seawater. ' 2. Pull and LD 5.5" tubing and ESP. 3. PU new ESP and I-wire for gauges while re-running tubing. 4. Ensure Wells Group ready to freeze protect. ' S. RDMO ITS-iL- S.+IV4 / ~IVI W~~~i~A?,J= INL,4Y AMC ~~ ~ ~ ~~T "„~y~ g~1~VfRDITIAL {$3~$93~J''~ ~,4?/TiJA~t = +c~s.~v= $3.17 ~~ZI~~ IC~Z~~K 1~1Ip-TE~ SOUR~~ W~P .. $~. ~ _ Datr,m rvm = - Datum TVD = ~$DD' 2D" SSG, 91.1#, i-#4D ,: `I DD' -1/2"'l~G, 17#,L~3D, .DZ32~~f, ID=4.t~"' ' !I~I~rrnu~ ~~ ~z~ ~t~sfrictimr~ = 3.87" .2639' ~ 33~®' ~ ~3~5SYMPHONYuAU~=~P"i~21S3 f w /CA$L~ TD 8l1}~A~ IN IA ~DISGHA~G~ t~4D, 7.23"' DD (31 LA'S) L3D = $.D"' (~ Lam) 4'h1CL~ATI-DP~F: 82° ~4'1~E7' Nate: }fifer to production I7B figr tttstorical data B>Z'~i $PF ~ INT3=F2VAL Dpn/~cR DATA 7" f 18 ~ 41~/ - 42D3 D 43/13/D4 7" j 18 ~ 4331 - 4397 D ~ D3/13/D4 ~ 4D27' ~-j~ ~~~ r~v~L ~a~K ~, m=a.73"' 4p~~,~$K~2 Z~P~Xr~NSIC3N w / sLD SLV, ID=a.73"' 4D61 ~3-3/8"' x 3-1/2" xD, ID= 4:93" 4D64' 3-1/2" $L~1 NK t~ w / GNTf~LZ~t, :~ = 4.892" a6zro' 4601' 17# / 3T, 37', ID = 4.$92" 4-1/2" BCD ~~IN, ID= 3:99D"' = 3.873" ~ ID = 4.73" 55 9-~!$" DSO, 47#, L-~D, 'ID = 8_~i81"' 4~6D6' ~7" MILL DUTIDCTft~151DN, ID=823" 4616' 7" wt~, ID = 3.1 BD'° ~iBNlC~ WALL: w-4DD ~Mff 'No: "sLD3"I~i3D AEI Nfl: 3D-D28-2313D-DD ~ 53=C 21, T11 N, ~Z12~, 3748' N5L & 1433' w~L BP ~xplnrratinn (Altska) '~i +C$`~V = 83.17 Datum NID= DatumTVD= 8$DD' SS 2D" CSD, 91.1.#, +x-40 ~ 1~DD~' 13-3/8" CSG, 88#, L-$D $TD, ID= 12.41•' ~-1/2"' Tf3G, 17#, L-BD, .D232 ~bfi, m=4.$92" "~~m~sm ~Grav~il ~a~k i~estrct~on = x,.878" { Saxe Saar Sub @ 40f4' ~#"1 ~SP~DWH2 DA$L~ W/ T~Cti UVIf~ tN ~1i21WIDi31Ni:iA~ 11113' 13-3/B"' ?A M ~I3RT CDLLAi~ 1839' '-~5 SYMPHONY G~UG~ CAAFi~t 334' ~--~DfSC+iA~2~+{~D, 7.2~"' DD 336' $P (#HPHV IVl A~2C 1:1) ~1JMP, 338' ~ C~NTftIL1FTT;4NDFN1 SQL, DD= 8.78" ~+IDTDFt, 7.2b" DD ', ~ffi tiN91 UT (Z ;'MOTOR, 7.28'" DD ~, MODEL i-IAi11 LT {Z Gi~4 VEL ~;4 CK ~, ID = 4.78" KTENSCDN w / SLD 5LV , iD = 4.78"' ~2FDR,~,TdDN ~lllWtt~li2Y ~ LDD: ?? ?1'AiC~ l ~ ,4T TDP i~E: 32° ~ 4187' Notes: Rafter to ~'r-otiuction DB iDr t~istori~al ~2rf data 51ZE; 5PF INTERVAL ; Dpn/5qz DATE 7"' ! 1$ 4187 - 42D8 ~i D D8/13/D4 7" i 1$ 4331 - 4897 D D3/13/D4 '( 4DS?I" ?J--~s-~r$° x~-1r2~' xD, ID=a.s~„ ',I ' ' 3-1 /2" $LA NK PIPE w / LNTf~LZR, ID = 4.892"' ~1~' $KR 8-1/2" 3DCrLLlDff? BC~V 17# / ET, 37', ID = 4.$92"' 4-1/2" XD tBRF'IN. ID = 3.99D" ~ID = 3.$78" IFIS+i - 55 SANDS r'-RDM F2WD (1D/10/04) J-~/8°' D51;, 47#, L-$D, ID = $.fi$1„ ~'},~' ~ $KR ,.D.. , ID = 4.78„ i'~,~' 7" MILL DUT ~KTENSiDN, iD = 8.23„ RRiNCE C~K UU~LL: 1~DD ~i21WIT'No: "2D3188D ARI 'Nn: 8D-D29-231$D-DD B~ 21, T11 i~l, R'12E, 3748' ~NSL 8 14~' 1'hFEL ~3P ~inrativn {Aiaska) • • ~..~ MICROFILMED 03/01/2008 DO NOT PLACE .u., ,, ~~ ANY NEW MATERIAL UNDER THIS PAGE F:~L.aserFichelCvrPgs_Inserts\Micrafilm Marker.doc ;2.~ J~ ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2031650 Well Name/No. PRUDHOE BAY UN UGN W-400 Operator BP EXPLORATION (ALASKA) INC .> ¡tt.ti Â I 0 è:i A.t:J Ð ') API No. 50-029-23180-00-00 MD 5285'~ TVD 4391 Y Completion Date 5/20/2004 ~ Completion Status WTRSP Current Status WTRSP 'CUlc3 REQUIRED INFORMATION Mud Log No Samples No Directional surv~ DATA INFORMATION Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: . Log/ Electr Data Digital Dataset Log Log Run Interval OH/ Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ~. Sonic 25 Blu 1 3028 5285 Open 11/3/2004 BOREHOLE COMPENSATED SONIC ¿D LOG/GRlCALlPER Directional Survey 210 5285 12/5/2003 Y Directional Survey 210 5285 12/5/2003 , Log Sonic 25 Blu 3028 5285 Open 11/3/2004 BOREHOLE COMPENSATED SONIC LOG/GR/CALlPER ~ Induction/Resistivity 5 Blu 3028 5285 Open 1 0/22/2004 QUAD COMBO LOG/PLATFORM ¿ EXPRESS & BHC SONIC MAX TEMP 98F. Induction/Resistivity 2 Blu 3028 5285 Open 10/22/2004 INDUCTION LOG/PLATFORM EXPRESS/MAX TEMP . 98F. µs( Rate of Penetration 2 Blu 300 5285 Open 11/3/2004 MD/REAL TIME LOG/FINAL PRINT/GR ~og Rate of Penetration 2 Blu 300 5285 Open 11/3/2004 TVD/REAL TIME LOG/FINAL PRINT/GR A Induction/Resistivity 2 Blu 3028 5285 Open 1 0/22/2004 TVD/PLA TFORM EXPRESS & BHC SONIC/SP/HCAUGRlTEN S/RHOZ/NPHIIMAX TEMP 98F. I ~ Density 5 Blu 3028 5285 Open 10/22/2004 DENSITY & NEUTRON POROSITY LOG/PLATFORM EXPRESS DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2031650 Well Name/No. PRUDHOE BAY UN UGN W-400 Operator BP EXPLORATION (ALASKA) INC MD 5285 TVD 4391 Completion Date 5/20/2004 Completion Status WTRSP Current Status WTRSP I.~ Caliper log 5 Blu 3028 5285 1 0/22/2004 ~C Tf 12834 Rate of Penetration 298 5284 Open 10/22/2004 ~ C Pds 12835 Gamma Ray 2872 5285 Open 1 0/22/2004 ~ Gamma Ray 5 Col 60 5170 Case 10/22/2004 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? yW - Daily History Received? ~N fÓ/N Formation Tops Analysis Received? ~ Comments: Compliance Reviewed By: fJ-o Date: ~'l)J~..~'o -- API No. 50-029-23180-00-00 UIC Y SIX ARM CALIPER/BOREHOLE PROFILE/MAX TEMP 98F. GRAPHIC IMAGES, LDWG. MWD, DSN 12834 GRAPHIC IMAGES, LDWG EDIT FOR AIT/BHC/PEXl6 ARM . CALIPER, DSN 12835 USIT/AMS/GR/CCUMAX TEMP 80F . - STATE OF ALASKA R ALASKIta. AND GAS CONSERVATION CcelSSION . ECE/VED R~PORT OF SUNDRY WELL OP~ATIONS MAY 042005 Æaska Oil & G88 Conâ c,, . Oml'RlSSIlW D o~,!çhor&ge -" 1. Operations Performed: D Abandon D Alter Casing D Change Approved Program !HI Repair Well D Pull Tubing D Operation Shutdown D Time Extension 2. Operator Name: BP Exploration (Alaska) Inc. . 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 83.17' 8. Property Designation: ADL 028263 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical 5285 4391 5186 4306 Casing Structural Conductor Surface Intermediate Production Liner Length 108' 3001' 5246' Perforation Depth MD (ft): Perforation Depth TVD (ft): D Plug Perforations D Perforate New Pool D Perforate D Stimulate D Waiver D Re-Enter Suspended Well 4. Current Well Class: D Development D Exploratory D Stratigraphic !HI Service 5. Permit To Drill Number: 203-165 6. API Number: 50-029-23180-00-00 99519-6612 9. Well Name and Number: PBU W-400 10. Field I Pool(s): Prudhoe Bay Field I Ugnu feet feet Plugs (measured) None feet Junk (measured) 5186' feet Size MD TVD Burst Collapse 20" 108' 108' 1490 470 13-318" 3030' 2673' 4930 2270 9-5/8· 5272' 4380' 6870 4760 4167' - 4597' 3436' - 3803' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): 5-1/2·, 17# L-80 3447' Gravel Pack Assembly: 5-1/2·, 17#, L-80 with Baker 'SC-1' 4027' & 4602' packer and Baker Mdel'F' Sump packer Treatment description including volumes used and final pressure: RBDMS 8Ft MAYO 9 2005 13. Oil-Bbl Prior to well operation: Subsequent to operation: 14. Attachments: Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casina Pressure Tubina Pressure 15. Well Class after proposed work: D Exploratory D Development !HI Service 16. Well Status after proposed work: DOil DGas DWAG DGINJ DWINJ DWDSPL 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 Paul Chan, 564-5254 NIA D Copies of Logs and Surveys run !HI Daily Report of Well Operations !HI Well Schematic Diagram Printed Name Terrie Hubble Signature ~Itto ¢{,.~ Form 10-404 Revised'6'4/200'4 Title Technical Assistant o KTG i [\jAL Date bSþ'1/o.S Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W -400 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES Start: 4/20/2005 Rig Release: 4/24/2005 Rig Number: Spud Date: 10/21/2003 End: 4/24/2005 4/20/2005 00:00 - 09:30 9.50 MOB P PRE Blow down pits steam system. Pull out the pit complex. Move pits and camp to W pad. RD rig floor, unpin the top drive and bridle up the blocks. Ready the derrick and pull sub out from over L-212i. Lay derrick over and ready the sub to move to W pad. 09:30 - 16:00 6.50 MOB P PRE Move the sub from L pad to W pad -8.3 miles. 16:00 - 19:00 3.00 RIGU P PRE Lay rig mats and herculite. Spot the sub. Move in and RU the pit complex. Spot the camp. 19:00 - 20:30 1.50 RIGU P PRE PJSM. Inspect and raise the derrick 20:30 - 22:00 1.50 RIGU P PRE Bridle down the blocks and prepare rig floor for workover operations. 22:00 - 00:00 2.00 RIGU P DECOMP Rig up circulation system on tree and take on 8.9 brine in pits. 4/21/2005 00:00 - 01 :30 1.50 PULL P DECOMP PU DSM lubricator and pull BPV. RU circulation lines. 01 :30 - 04:00 2.50 KILL P DECOMP Test lines to 3,500 psi. Open the well up to closed choke. IA- 170 psi, Tbg - 110 psi. Circulate out freeze protection fluid pumping down the tubing and taking returns from the annulus with 8.9 ppg heated brine - 6 bpm, 220 psi. Pumped 540 bbls of 8.9 brine and lost 290 bbls of fluid to the well. 04:00 - 07:30 3.50 WHSUR P DECOMP RD circulaton lines. Well on vacuum. Dry rod in TWC. NO tree and adapter flange. Verify TCII threads on the hanger. 07:30 - 15:00 7.50 BOPSUF P DECOMP NU BOP's. Remove the 13-5/8" x 11" crossovers and make up 13-5/8" x 13-5/8" spacer spool. Install riser and RU turn buckles. Change bottom rams from 2-3/8" x 5" to 5.5". MU test joint, xo, TIW valve and dart valve 15:00 - 20:30 5.50 BOPSUF P DECOMP Test the BOP's, the choke manifold and all related valves to 250 psi/3,500 psi. Test was witnessed by Jeff Jones of the AOGCC, Alan Madsen/James Franks for BP, and Chris Clemens/Kelly Cozby for Nabors. All valves tested satisfactorily. During the test, two leaks required repair - one on the test hose and the other on the pump in sub. 20:30 - 22:00 1.50 WHSUR P DECOMP RD test joint and equipment. Blow down all surface lines. RU and pull TWC with DSM lubricator 22:00 - 23:00 1.00 PULL P DECOMP MU landing joint to hanger and back out the lock down screws. Pull the hanger to the rig floor, PU - 100K. Pump 8.8 ppg brine down the back side. Pipe full after 55 bbls of fluid pumped. Shut in the pump and monitor the well - fluid level dropping. 23:00 - 23:45 0.75 PULL P DECOMP PJSM for rigging up Centrilift and pulling ESP completion. 23:45 - 00:00 0.25 PULL P DECOMP Circulate down the tubing taking returns up the back side with 8.8 ppg brine @ 6 bpm, 200 psi. Saw returns after 35 bbls pumped. Fluid returning weighed 8.9 ppg 4/22/2005 00:00 - 01 :00 1.00 PULL P DECOMP RU Centrilift equipment. Line up with the hole fill pump on the back side. Unable to keep up with the dropping fluid level> 120 bbls/hour. Called Engineer and agreed to pump twice the fluid volume in for the pipe volume removed from the well to keep the hole balanced down hole and not at surface - 2.5 bbls / 5 joints removed. 01 :00 - 10:30 9.50 PULL P DECOMP Pull 5-1/2" 17# L-80 IBT ESP completion with Cable and heat trace. Recovered 80 Cannon clamps, 335 6' flat guards, 5 3' flat guards. Missing 10 steel bands. 10:30 - 12:00 1.50 PULL P DECOMP Pull the ESP to the surface. Found the lead to the motor to be damaged. Drain the mineral oil from the motor, cut the cable and lower to the spooling unit. 12:00 - 15:00 3.00 PULL P DECOMP PJSM with Centrilift personnel and rig team. LD ESP. LD Printed: 4/25/2005 10:06: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 WORKOVER NABORS ALASKA DRILLING I NABORS 9ES Start: 4/20/2005 Rig Release: 4/24/2005 Rig Number: Spud Date: 10/21/2003 End: 4/24/2005 4/22/2005 12:00 - 15:00 15:00 - 16:00 16:00 - 17:00 17:00 - 18:30 18:30 - 20:00 20:00 - 22:30 4/23/2005 22:30 - 00:00 00:00 - 00:30 00:30 - 03:45 03:45 - 06:00 06:00 - 08:30 08:30 - 10:00 10:00 - 11 :30 11 :30 - 16:00 16:00 - 17:00 17:00 - 00:00 4/24/2005 00:00 - 03:30 03:30 - 07:00 07:00 - 10:30 10:30 - 15:30 15:30 - 18:30 18:30 - 19:30 3.00 PULL P 1.00 FISH P 1.00 FISH P DECOMP tools and clear the floor. DECOMP RU slickline for GR/JB run to fish bands. DECOMP Run #1: RIH with 8.5" GR/JB. Tag up at 1,480'. POH. Recovered 3 bands. DECOMP Run #2: RIH with 8.5" GR/JB to 4,000'. POH. Recovered 2 bands. DECOMP Run #3: RIH with 8.5" GR/JB to 4,000'. POH. Recovered 1 band. DECOMP Run #4: RIH with 8.5" GR/JB to 4,000'. POH. Recovered 2 bands. DECOMP Run #5: RIH with 8.5" GR/JB to 4,033'. POH. DECOMP Continue POH with Run #5: No bands recovered. DECOMP Run #6: RIH with 4.5" GR/JB and tag up at 4,610' SLM. POH. Recovered 1 band. DECOMP Run #7: RIH with 4.5" GR/JB. Tag up @ 4,610'. POH. No bands recovered. DECOMP Run #8: RIH with 8.5" GR/JB to the top of the liner. POH. Recovered 1/2 band. DECOMP Run #9: RIH with 8.5" GR/JS to the top of the liner. POH. No bands recovered. Total of 9.5 bands recovered. RD slickline. RUNCMP RU the rig floor to run ESP. Hold PJSM with Centrilift and all rig personnel. RUNCMP MU ESP assembly - 6 fin centralizer, 2 x motors, tandem seals, 2 x pumps, discharge head. RUNCMP Bring HES spooler to the rig floor. RU I-wire sheave and ESP cable sheave. Plug in and clamp ESP cable to motor. RUNCMP RIH with ESP assembly with cable and I-wire on 5-1/2" 17# L-80 IBT tubing to 1,984'. RUNCMP RIH with ESP assembly with cable and I-wire on 5-1/2" 17# L-80 1ST tubing to 3,421 '. Ran 84 Cannon clamps, 5 "protectolizers" and 2 flat guards (3.5' each on each of the pumps). RUNCMP MU tubing hanger. Cut ESP electric cable and LD double sheave. Spool up excess cable. Cut I-wire and MU to the tubing hanger. MU landing joint to the hanger. MU penetrator to the hanger. Splice the electric line to the penetrator. PU- 95K, SO - 77K. Verify continuity. Land tubing hanger. RILDS - 450 ftlbs. Set TWC. WHDTRE Change out lower pipe rams. ND BOPE. WHDTRE NU tree and confirm ESP continuity. Test hanger, ESP penetrator to 5,000 psi - good test. WHDTRE Pull TWC with DSM lubricator. RU LRHOS and freeze protect the well. Pump 50 bbld diesel down the tubing @ 3.5 bpm, 500 psi. Pump 95 bbls diesel down the annulus @ 4 bpm, 500 psi. Install BPV with DSM lubricator. RD LRHOS. WHDTRE Remove the outer working valve and install flange. Secure the well. Rig released @ 1930 hours 4/24/2005 to L-124. 1.50 FISH P 1.50 FISH P 2.50 FISH P 1.50 FISH P 0.50 FISH P 3.25 FISH P 2.25 FISH P 2.50 FISH P 1.50 FISH P 1.50 RUNCOMP 4.50 RUNCOMP 1.00 RUNCOMP 7.00 RUNCOMP 3.50 RUNCOMP 3.50 RUNCOMP 3.50 BOPSUP P 5.00 WHSUR P 3.00 WHSUR P 1.00 WHSUR P Printed: 4/25/2005 10:06: 16 AM W-4. 9ES Re-Com_ete PRINCE CREEK WATER SUPPLYWELL FROM DRLG - DRAFT 'TREE = . WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = CrN 7" 5M INLAY FMC M82j' 55.6' MaxÅnQle"" Datum MD = u~, == Datum 1VD = 55 @ 2791' , """ --..... ,~, 8800' SS 120" CSG, 91.1#, H-40 H I~ 100' - 113-3/8" CSG, 68#, L-80, 10 = 12.415" H ~ 3030' Minimum Gravel Pack Restriction = 3.875" Safety Shear Sub @ 4064' 15-1/2" TBG, 17#, L-80. .0232 pbf, 10 = 4.892" H 3354' ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 7" 18 4167 - 4205 0 05/13/04 7" 18 4331 - 4597 0 05/13/04 ~ I I ~ 5 ~ z ~ I I PBTD H 5186' 'r 19-518" CSG, 47#, L-80, 10 = 8.681" H 5272' I TO H 5285' OA TE REV BY COMMENTS 11/25/03 JDMITLH SUSPENDED (11/01/03) 05120104 DAV/KAK FINAL COMPLETION 10/06/02 DCRlTLH RWO· ESP CIO 10/18/04 DCR/TLH PUMP ORA WING CORRECTION 04/04/05 JRA/TLH TBG PUNCH 04/25/05 9ES RWO - ESP C/O OA TE REV BY ... ... ... " " " , ... " ... " " ... " " " ... " ... " ... " " ... " ... , " ... " ... " " " I SAFETY NOTES: ~ 1#1 ESP POWER CABLE WI TECH WIRE IN ARMOR WRAP - - 1023' H 13-3/8" TAM PORT COLLAR I 2841' '1HES SYMPHONY GAUGE WITH I- I WIRE,00=0.25" ~ H CENTRILlFT DISCH HEA 0, 00 = 6.75" I H CENTRILIFT HPHV PUMPS, 00 = 6.75" I HCENTRILlFTTANDEM SEALS, 00 = 6.75" I I 3354' I 3355' I 3385' I 3399' l-i CENTRILFrT HMI MOTORS (2), 00=7.25" 3445'-3447 -6-FINCENTRILIZER. 00=8.0" I ~ ---j 4027' HBKRSG-1 GRAVEL PACK PKR 1 4033' H BKR MODEL S SLIDING SL V I I 4064' H BKR GPR-24 SHEAR OUT JOINT û: 4149' H5-1/2" BLANK PlÆ, L-80, SLHT I ~ 1 4602' '1 BKR 5-1/2" EXCLUDER SCREEN ~ MEDIUM, 17# 1 FT, 37', 10 = 4.892" :g----i BKR MODEL F SUMP PKR I 4606' H MILL OUT EXTENSION ~ 4616' H WLEG I ??? H FISH (SS BANDS, 4 EA) FROM RWO 10/10/04 I COMMENTS PRINCE CREEK WELL: W-400 ÆRMrT No: '2031650 API No: 50-029-23180-00 SEC 21, T11 N, R12E, 3749' NSL & 1455' WEL BP Exploration (Alaska) a STATE OF ALASKA . ALASKAWL AND GAS CONSERVATION CO ..~ISSION REPORT OF SUNDRY WELL OPERATIONS 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 028263 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Length Perforation Depth MD (ft): Perforation Depth TVD (ft): v o Repair Well 181 Pull Tubing o Operation Shutdown o Plug Perforations o Perforate New Pool o Perforate o Stimulate o Waiver o Re-Enter Suspended Well DOttier o Time Extension 83.17' 5285 4391 5186 4306 108' 3001' 5246' 4. Current Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 5. Permit To Drill Number: 203-165 6, API Number: 50-029-23180-00-00 99519-6612 9. Well Name and Number: PBU W-400 10. Field I Pool(s): Prudhoe Bay Field I Ugnu feet feet Plugs (measured) None feet Junk (measured) 5186' feet Size MD TVD Burst Collapse 20" 108' 108' 1490 470 13-3/8" 3030' 2673' 4930 2270 9-5/8" 5272' 4380' 6870 4760 4167' - 4597' 3436' - 3803' 5-1/2", 17#, L-80 3445' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Gravel Pack Assembly: 5-1/2",17#, L-80 with Baker 'SC-1' 4027' & 4602' packer and Baker Mdel 'F' Sump packer Treatment description including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: RBDMS 8Fl NOV - 8 2DD4 Oil-Bbl Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casinq Pressure Tubinq Pressure 15. Well Class after proposed work: o Exploratory 0 Development 181 Service 16. Well Status after proposed work: Wtt+u ~l.4.PtL~ 'Il.(..ll o 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 Paul Chan, 564-5254 N/A o Copies of Logs and Surveys run 181 Daily Report of Well Operations 181 Well Schematic Diagram Printed Name Terrie Hubble Signature ~/u '¿, (/,~ Form 10-404 Revised 04/2004 Title Technical Assistant o Rl°G i ¡~5Ã-L4 Date \\/Ot.f./Dl./ Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W -400 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/5/2004 1 0/9/2004 Spud Date: 10/21/2003 End: 10/9/2004 10/5/2004 10:00 - 00:00 14.00 MOB P PRE Move Rig and Equipment from DS-07 to W-Pad. Exceptional Rig Move due to slick Roads. Using two Sand Trucks, Blade, and Cat to support Rig Move. 00:00 - 04:30 4.50 MOB P PRE Continue with Exceptional Rig Move. 04:30 - 06:00 1.50 RIGD P PRE Rig arrived on W-400 Well Slot. Spot Rig, Pits, Pipe Shed, and Camp. 10/6/2004 00:00 - 04:30 4.50 MOB P PRE Continue with Exceptional Rig Move. 04:30 - 06:00 1.50 RIGU P PRE Rig arrived on Location. Remove snow and sand Rig foot print. 06:00 - 07:30 1.50 RIGU P PRE Spot Sub Base, Pits, and Pipe Shed. Spot Camp. Move in Shop. 07:30 - 09:00 1.50 RIGU P PRE Raise and scope Derrick. 2% KCL arrives on location. Accept Rig at 09:00 hrs. 09:00 - 10:30 1.50 KILL P DECOMP Build berm for PE Open Top Tank (Tiger Tank in shop for cleaning and internal "Gas Buster" line mods). Spot Tank. Lay Lines. 10:30 - 11 :30 1.00 KILL P DECOMP Pick-up Lubricator. Pull BPV. Lay down same. Tbg = 180 psi. IA = 240 psi. OA = 100 psi. 11 :30 - 12:30 1.00 KILL P DECOMP Test lines. Small Leak. Re-test at 3,500 psi. Good. 12:30 - 13:00 0.50 KILL P DECOMP PJSM with all. 13:00 - 17:00 4.00 KILL P DECOMP Displace diesel freeze protection from well bore & circulate well with 2% KCL (8.43 Ib/gal). Pumped 320 bbls @ 3 BPM, 150 psi. S/D. 17:00 - 00:00 7.00 KILL P DECOMP Monitor well. TP 0 psi. Cp 10 psi. wait 30 min & check pressures. pressure still 1 0 psi on annulus. Call for 8.8 ppg fluid. Wait on fluid. Hang double sheave. perform rig service & maintenance. Take on 8.8 ppg kill fluid (10% KCL). 1017/2004 00:00 - 01 :00 1.00 KILL P DECOMP Finish taking on 400 bbls 8.8 ppg KCI water. 01 :00 - 02:00 1.00 KILL P DECOMP Open well, circulate & kill well w/ 8.8 ppg KCI water. Pumped 250 bbls @ 5 BPM, 225 psi. SID. 02:00 - 02:30 0.50 KILL P DECOMP Monitor well, Well dead. Well on slight vacum. R/D lines to tree. 02:30 - 03:00 0.50 WHSUR P DECOMP R/U T-bar & install TWC. Test same. 03:00 - 04:00 1.00 WHSUR P DECOMP Bleed off hanger void. N/D X-mas tree. 04:00 - 08:00 4.00 BOPSUF P DECOMP N/U BOPE. Change out rams for 3 1/2" x 6" variables. 08:00 - 12:00 4.00 BOPSUF P DECOMP Rig up Test Equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. State's right to witness Test waived by J, Chrisp. Blow down lines and rig down Test Equipment. 12:00 - 14:00 2.00 WHSUR P DECOMP Pick-up Lubricator Extention and Hyd Lubricator. Pull TWC. Lay down same. 14:00 - 14:30 0.50 PULL P DECOMP Pick-up Landing Joint. BOLDS. Pull Hanger at 72K to Rig Floor with no problems. Lay down Landing Joint. Visual on static fluid level at -50'. 14:30 - 23:00 8.50 PULL P DECOMP POOH wI ESP & heat trace. UD each jt of 51/2" tubing. RID elephant trunck. 23:00 - 00:00 1.00 PULL P DECOMP Inspect, drain & UD ESP. 10/8/2004 00:00 - 03:30 3.50 PULL P DECOMP Con't to inspect, & UD ESP. Left 9 SS bands in hole. Had some damage to ESP Cable (Armor) from SS bands while POOH. Bottom motor burned up, had water& burnt oil In motor. 03:30 - 04:00 0.50 PULL P DECOMP Clear & clean rig floor. 04:00 - 05:00 1.00 PULL P DECOMP Break out & UD kelly for inspection. 05:00 - 11 :00 6.00 CLEAN P CLEAN Rig up SWS S-Line Unit. RIH w/8.50" GRlJB to 3,800'. Printed: 10/11/20049:28:15 AM e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W -400 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/5/2004 10/9/2004 Spud Date: 10/21/2003 End: 10/9/2004 10/8/2004 05:00 - 11 :00 6.00 CLEAN P CLEAN POOH. Empty Junk Basket. Recovered 1 SS Band and a 3" piece from another Band.. 2 nd RIH down to top of Pkr at 4,027'. POOH. Recovered 3 more SS Bands. 3 rd and final RIH to top of Pkr. POOH recovered 1 more SS Band. Total Bands recovered 5...4 Bands remain below Pkr. Rig down S-Line Unit. 11 :00 - 21 :00 10.00 RUNCOrvP RUNCMP Pick-up assemble and service ESP Assembly. Plug in & test cable. 21 :00 - 23:00 2.00 RUNCOrvP RUNCMP P/U & RIH w/19 jts 51/2" 1-80 IBT tubing. 23:00 - 00:00 1.00 RUNCOMP RUNCMP R/U for heat trace. Con't to RIH w/ tubing & heat trace. 10/9/2004 00:00 - 10:30 10.50 RUNCOrvP RUNCMP Continue RIH with 51/2", 171blft, L-80, IBT ESP/HT Completion. 10:30 - 11 :00 0.50 RUNCOMP RUNCMP Pick-up Landing Jt. Make up Tubing Hanger. Install Penetrators for ESP and Heat Trace Cabes. Test Penetrators. 11 :00 - 14:30 3.50 RUNCOrvP RUNCMP Make ESP and Heat Trace Cable splices. Attatch Cables to Penetrators. Test Cables. Good. 14:30 - 15:30 1.00 BOPSUF P RUNCMP Land Hanger. RILDS. Drain Lines and BOP stack. 15:30 - 17:00 1.50 BOPSUP P RUNCMP Set TWC and test. Nipple down BOP Stack. 17:00 - 19:30 2.50 WHSUR P RUNCMP Nipple up Adaptor Flange and Tree. 19:30 - 21 :00 1.50 WHSUR P RUNCMP Test Adaptor Flange and Tree to 5K. Good. Perform final ESP and Heat Trace Cable checks. Good. 21 :00 - 00:00 3.00 WHSUR P RUNCMP Pick-up Lubricator. Pull TWC and install BPV. Rig up Hot Oil and Freeze Protect Well with Diesel down to 2,100'. Rig down Hot Oil. Secure Cellar. Release Rig at Midnight. Printed: 10/11/2004 9:28:15 AM TREE = CrN 7" 5M WELLHEA 0·= INLA Y FMC -~--.~.=_....~.-.-.-,=.~-~.. A C1UA TOR = KB. ELEV = 83.17' BF ELEV = e W-400 ~NOTES: PRINCE CREEK WATER SUPPLY WELL Max Angle = 55 @ 2791' Datum MD = Datum TVD = 8800' SS 120" CSG, 91.1#, H-40 H 100' I~ q - - 113-3/8" CSG, 68#, L-80, 10= 12.415" H 3030' ~ Minimum Gravel Pack Restriction = 3.875" Safety Shear Sub @ 4064' (] 15-1/2" TBG, 17#, L-80, .0232 pbf, 10 = 4.892" H 3348' ÆRFORA TION SUMMARY REF LOG: ANGLE AT TOP ÆRF: Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 7" 18 4167 - 4205 0 05/13/04 7" 18 4331 - 4597 0 05/13/04 z z I I PBTO H 5186' 19-5/8" CSG, 47#, L-80, 10 = 8.681" H 5272' I TO H 5285' DA TE REV BY COMMENTS 11/25/03 JDMITLH SUSPENDED (11/01/03) OS/20/04 DAV/KAK FINAL COMPLETION 10/06/02 DCRlTLH RWO - ESP C/O 10/18/04 DCRlTLH PUMP ORA WING CORRECTION DATE REV BY I I ~ ~ ~ z ~ z , .... .... .... , " " " " " " " " " " " " " " " "- " , , , , " " " ~ 1#1 ESP POWER CABLE W/ TECH WIRE IN ARMOR WRAP - 1023' H 13-3/8" TAM PORT COLLAR I 2529' H CENTRILlFT HEA T TRACE CABLE I ~ " " " " r 3348' HTOP OF CENTRILlFT PUMP, 00 = 6.75" I l 3378' H TOP OF CENTRILlFT SEAL, 00 = 6 75" I I 3393' H CENTRILlFT TANDEM PUMP, OD = 7.25" I I 3439' H CENTRILlFT PHOENIX MS-1 GAUGE, 00 = 4.5" 13443'.3445 H6-FINCENTRILIZER,OD=8.0" I Z ----1 4027' H BKR SC-1 GRAVEL PACK PKR I 4033' I 4064' il---J 4149' ~ U i 4602' ~ ~ :z H BKR MODEL S SLIDING SL V I H BKR GPR-24 SHEAR OUT JOINT H5-1/2" BLANK PlÆ, L-80, SLHT , '1 BKR 5-1/2" EXCLUDER SCREEN MEDIUM, 17# / FT, 37', ID = 4.892" z----i BKR MODEL F SUMP PKR 4606' H MILL OUT EXTENSION ~ 4616' H WLEG , 117 H FISH (SS BANDS, 4 EA) FROM RWO 10/10/04 I COMMENTS PRINCE CREEK WELL: W-400 ÆRMIT No: 2031650 API No: 50-029-23180-00 SEC21, T11N, R12E, 3749' NSL & 1455' WEL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth Well \f ~12. 15-13A '(/__ E-20 9'1/-D Ð18-33A ?:;~~SI-05 \L2_32 7 ... L2-32 '!I7 ~2-32 L2-32 :¡J ...<;-400 fA W-400 -400 r Job # 10913854 10866600 10861918 10830793 10687661 10672377 10912982 10687650 40009731 10621738 10621779 - --- ZD3 ·-(CJ ) 10/21/04 NO. 3238 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 10/04/08 1 10/01/04 1 06/21/04 1 1 04/25/04 1 1 01/02/04 1 1 04/28/04 1 1 09/06/04 1 1 09/22/03 1 1 10/21-26/03 2 1 10/28/03 6 1 05/05/04 1 SCMT USIT MCNL RST-SIGMA RST-SIGMA RST-SIGMA RST -SIGMA RST-SIGMA OH EDIT MWD DATA OH EDIT AITIBHC/PEXl6 ARM CALIPER US IT PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 :;~"'::~ '/.7;: I / r R"e;ve~ .~ /~z)' Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ffl_,~.,DS 15-13A I VI,. E-20 ~~"I-O £9I8-33A l£l:rlJPfSI-05 <L2-32 '61" L2-32 rH L2-32 L2-32 1J!JI"<]' W-400 IfA W-400 400 Well Job# 10913854 10866600 10861918 10830793 10687661 10672377 10912982 10687650 40009731 10621738 10621779 10/21/04 NO. 3238 ¡;J~~ Company: State of Alaska Alaska Oif & Gas Cons Comm Attn: Robin Deason 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay tþr Log Description Color Date Blueline Prints CD 10/04/08 1 10/01/04 1 06/21/04 1 1 04/25/04 1 1 01/02/04 1 1 04/28/04 1 1 09/06/04 1 1 09/22/03 1 1 10/21-26/03 2 1 10/28/03 6 1 05/05/04 SCMT USIT MCNL RST-SIGMA RST-SIGMA RST-SIGMA RST -SIGMA RST-SIGMA OH EDIT MWD DATA OH EDIT AIT/BHC/PEX/6 ARM CALIPER US IT ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: /of-z4-¡ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Be~ ~ / r R"ei"~¡~ I STATE OF ALASKA .. ALASKA L AND GAS CONSERVATION COMtJI!'SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 21. Logs Run: MWD I GR, MWD I GR I RES, PEX I Sonic. US IT CASING, liNER AND CEMENTING RECORD $errlNGDeFrTHMo SrnINGDeÞTH1"VD I OF! BOTTOM BOTTOM Surface 108' Surface 108' 29' 3030' 29' 2673' 26' 5272' 26' 4380' 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: 3819' NSL, 1454' WEL. SEC. 21. T11N, R12E. UM Top of Productive Horizon: 2201' NSL, 614' WEL, SEC. 21. T11 N, R12E. UM Total Depth: 1682' NSL, 345' WEL, SEC. 21, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 611789 y- _ 5958792 Zone- ASP4 TPI: x- 612657 y- 5957187 Zone- ASP4 Total Depth: x- 612935 y- 5956672 Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. CASING SIZE 20" 13-3/8" 9-518" 91.5# 68# 47# H-40 L-80 L-80 23. Perforations 0Ren to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7" Gun Diameter, 18 spf MD TVD MD TVD 4167' - 4205' 3436' - 3468' 4331' - 4597' 3575' - 3803' 26. Date First Production: September 11, 2004 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ....... Press. 24-HoUR RATE""" One Other Water Source Well 5. Date Comp., Susp., or Aband. 5/20/2004 6. Date Spudded 10/21/2003 7. Date T.D. Reached 10/26/2003 8. KB Elevation (ft): 83.17' 9. Plug Back Depth (MD+ TVD) 5186 + 4306 10. Total Depth (MD+ TVD) 5285 + 4391 11. Depth where SSSV set N/A MD 19. Water depth. if offshore NIA MSL Revised 09/16/04: Put on Production 1 b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 203-168 13, API Number 50- 029-23180-00-00 14. Well Name and Number: PBU W-400 15. Field I Pool(s): Prudhoe Bay Field I Ugnu Ft Ft 16. Property Designation: ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) AMOUNT PULLED 36" 260 sx Arctic Set (Approx.) 16" 741 sx Articset Lite, 408 sX 'G' 12-1/4" 618 sx Class 'G' SIZE 5-112", 17#, L-80 Gravel Pack Assy: 5-1/2-.17#. L-80 DEPTH INTERVAL (MO) 4064' - 4602' DEPTH SET (MD) 3436' 4027' - 4616' PACKER SET (MD) None 4027' & 4602" AMOUNT & KIND OF MATERIAL USED Placed 12.674# of 16/20 Carbolite Behind Pipe Freeze Protect with 138 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing OIL-Bel GAs-McF WATER-BeL CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil. gas or water (attach separate sheet, if necessary). Submit core chips; ¡fnone, state "none". RECEIVED SEP 1 62004 OIL-BeL 27. None S.' L.!l '2: i.ii '~. \·.·,~W~ . ¡{:t :p;.:, t., }"'!'~'J9 (QjM~-Ji'3 ~,.;¡;¡;'.J!!!!!"!''¡¡'. Form 1 0-407 Revised 12/2003 GAs-McF WATER-BeL ORIGINAL CONTINUED ON REVERSE SIDE CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) ,r t \/ G Alaska Oil & Gas Cons. Commissior Anchorage ,,* e GEOLOGIC MARKERS 29. e FORMATION TESTS 28. , NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". SV1 3688' 3069' None Ugnu 4 Ugnu 4A Ugnu 3 Ugnu 1 4157' 3427' 4209' 3471' 4606' 3811' 5151' 4276' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ew4. \'VtM&- Title Technical Assistant Date m../ to -Ot[ PBU W-400 203-165 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. I Approval No. Drilling Engineer.' Nei/ Magee, 564-5119 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 Submit Original Only · STATE OF ALASKA . ALASKA~IL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 0 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20MC 25.105 20MC 25.110 21. Logs Run: MWD I GR, MWD I GR I RES, PEX I Sonic, USIT CASING, liNER AND CEMENTING RECORD SETTINGDePtHMD SeTtINGDEPii-f TVO lOP BOTTOM loÞ BOTTOM Surface 108' Surface 108' 29' 3030' 29' 2673' 26' 5272' 26' 4380' 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: 3819' NSL, 1454' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 2201' NSL, 614' WEL, SEC, 21, T11N, R12E, UM Total Depth: 1682' NSL, 345'WEL, SEC. 21, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 611789 y- 5958792 Zone- ASP4 TPI: x- 612657 y- 5957187 Zone- ASP4 - . Total Depth: x- 612935 y- 5956672 Zone- ASP4 18. Directional Survey 181 Yes 0 No 22. 20" 91.5# 68# 47# H-40 L-80 L-80 13-3/8" 9-518" - 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 7" Gun Diameter, 18 spf MD TVD MD TVD 4167' - 4205' 3436' - 3468' 4331' - 4597' 3575' - 3803' 26, Date First Production: Not on Production Yet Date of Test Hours Tested PRODUCTION FOR TEST PERIOD .. Flow Tubing Casing Pressure CALCULATED ...... Press. 24-HoUR RATE7 One Other Water Source Well 5. Date Comp., Susp., or Aband. 5/20/2004 6. Date Spudded 10/21/2003 7. Date T.o. Reached 10/26/2003 8. KB Elevation (ft): 83.17' 9. Plug Back Depth (MD+ TVD) 5186 + 4306 10. Total Depth (MD+TVD) 5285 + 4391 11. Depth where SSSV set N/A MD 19. Water depth, if offshore N/A MSL 36" 16" 12-1/4" SIZE 5-112", 17#, L-80 Gravel Pack Assy: 5-1/2", 17#. L-80 1b. Well Class: o Development 0 Exploratory o Stratigraphic 181 Service 12. Permit to Drill Number 20~165 13. API Number 50- 029-23180-00-00 14. Well Name and Number: PBU W-400 15. Field 1 Pool(s): Prudhoe Bay Field 1 Ugnu Ft Ft 16. Property Designation: ADL 028263 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) ~ k' r:: """1, r- L.l, L.;,¥''\·~/I- n - &..JJ\MOUNT 2'Ja PULLED 260 sx A\'~~~.fAtJ~PProX.)" tf 741 sXArtcset'i.1t~4œ~·ì~ G " .r. ' 618 sx Class 'G' D"/(,, .'is!l::ii DEPTH SET (MD) 3436' 4027' - 4616' PACKER SET (MD) None 4027' & 4602" DEPTH INTERVAL (MD) 4064'- 4602' AMOUNT & KIND OF MATERIAL USED Placed 12,674# of 16/20 Carbolite Behind Pipe Freeze Protect with 138 Bbls of Diesel PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): NIA OIL-BsL GAs-McF WATER-BsL OIL-BsL GAs-McF WATER-BsL CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". '~i;;t"t~~t~~~:~: ~- -:¿;~¡-t ~l~'~~¡h~ .r~~~,; ,/'fIC"- -' CONTINUED ON REVERSE SIDE None Form 10-407 Revised 12/2003 ~SBfL ..n 14 'X't'~ GP ~ 28. e GEOLOGIC MARKERS 29. e FORMATION TESTS NAME MD rvD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None", SV1 3688' 3069' None Ugnu 4 Ugnu 4A Ugnu 3 Ugnu 1 4157' 3427' 3471' 4209' 4606' 3811' 5151' 4276' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble ~ J\1\I ~() . ~ Title Technical Assistant Date rJ.o .;l.., L/.. DC( PBU W-400 203-165 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number Drilling Engineer: Neil Magee, 564-5119 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). 'TEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 1212003 Submit Original Only W-400 W-400 Legal Name: Common Name: 12.52 (ppg) 739 (psi 420 (psi) 9.50 (ppg) 2,673.0 (ft) 3,030.0 (ft) LOT 0/25/2003 e - 1/3/2003 92805 AM Printed: e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 10/20/2003 10/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 10/18/2003 06:00 - 00:00 18.00 MOB P PRE Rig Relesaed at 06:00 Hrs 10-18-03 from PSI-07, RD Rig Floor, Pipe Shed and Rock Washer, LD Top Drive Torque Tube and Top drive, LD Windwalls and V-Door section, LD Derrick 10/19/2003 00:00 - 08:00 8.00 MOB P PRE Cont RD on PSI-07, Secured Blocks, folded derrick board and secured, blow down rig, moved boilers, motors, mud pumps and pit modules and staged on PSI pad, loaded derrick on trucks and secured 08:00 - 09:00 1.00 MOB P PRE Moved sub base off PSI-07 09:00 - 09: 15 0.25 MOB P PRE Held PJSM on electrical high line height restrictions 09:15 - 14:30 5.25 MOB P PRE Moved derrick, sub base, motor and pit modules and cranes 38 miles from East Dock to W-Pad 14:30 - 16:00 1.50 MOB P PRE Spotted sub, pits and motors to PU derrick 16:00 - 22:30 6.50 RIGU P PRE Hook up power and air, spool drlg line, inspect and prepare to PU derrick 22:30 - 23:00 0.50 RIGU P PRE Held PJSM on raising derrick 23:00 - 00:00 1.00 RIGU P PRE Raised and pinned derrick 10/20/2003 00:00 - 06:00 6.00 RIGU P PRE Strung up air tuggers and set in V-door side windwalls. Set in drilling line spool, unbridle derrick and set in "C" section 06:00 - 06: 15 0.25 RIGU P PRE Held PJSM on PU top drive and spotting sub base 06:15 - 08:30 2.25 RIGU P PRE PU top drive with crane and hooked to blocks, moved out pits and motors away from sub 08:30 - 10:30 2.00 RIGU P PRE Moved sub base 1125' down pad, spot & level sub base over well W-400 10:30 - 15:30 5.00 RIGU P PRE Lay matting boards and spot pits, mud pumps, motors, boilers, rock washer and pipe sheds. Hooked up electric, steam and air to rig modules 15:30 - 00:00 8.50 RIGU P PRE Install top doghouse in derrick, PU & hung top drive torque tube, prepared mud pits to take on spud mud 10/21/2003 00:00 - 04:00 4.00 RIGU P PRE RU Pipe skate and mud pumps, hooked up top drive service loops, kelly hose and mud manifold, slipped 160' of excess drlg line, PU & RU 5" rotary tools and completed rig acceptance list NOTE: Accepted Rig at 00:01 Hrs 10/21/03 04:00 - 06:00 2.00 RIGU P PRE Loaded pipe shed with 5" DP & HWDP, took on spud mud in pits 06:00 - 07:00 1.00 RIGU P PRE Installed riser on divertor and strapped DP in shed 07:00 - 10:30 3.50 RIGU P PRE PU & stood back 78 jts of 5" DP, 23 jts Of 5" HWDP and jars 10:30 - 11 :00 0.50 BOPSURP PRE Function test 21-1/4" Diverter, Witnessing of test waived by AOGCC Lou Grimaldi 11:00-11:45 0.75 RIGU P PRE PU BHA tools to rig floor 11:45-13:00 1.25 RIGU P PRE Began MU stand of 8" NMDC's and tagged ice at 45', LD NMDC's 13:00 - 14:15 1.25 RIGU P PRE MU 16" Bit #1 on mud motor and XO to HWDP 14:15 - 14:30 0.25 RIGU P PRE Filled mud lines and conductor checking for leaks. 14:30 - 15:00 0.50 DRILL P SURF Cleaned out ice in conductor from 45' to 108' 15:00 - 17:00 2.00 DRILL P SURF Spud Well and drill 16" hole from 108' to 299' (191') ART 1.77 hrs 17:00 - 18:00 1.00 DRILL P SURF Circ and condition hole to insure 300 plus vis. prior to TOH to P/U remaining BHA. 18:00 - 18:30 0.50 DRILL P SURF POOH & stood back 3 stds HWDP 18:30 - 21:30 3.00 DRILL P SURF MU BHA #1 with MWD and orient same, RIH to 189' 21 :30 - 22:00 0.50 DRILL P SURF Washed 90' to btm and surveyed, no fill 22:00 - 00:00 2.00 DRILL P SURF Drill, slide & survey 16" hole from 299' to 459' MO/ 459' TVO, Printed: 11/3/2003 9:28: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 1 0/20/2003 1 0/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 1 0/21/2003 22:00 - 00:00 2.00 DRILL P SURF (160'), ART 0.81 hrs, AST 0.9 hrs, 5-10K wob, 40 rpm's, 600 gpm at 600 psi, ROT wt 70K, PU wt 70K, DN wt 70K, on/off btm torque 1 K ft-Ibs, 8.9 ppg mw with 300 vis 1 0/22/2003 00:00 - 14:45 14.75 DRILL P SURF Drill, Slide & Survey 16" surface hole from 459' to 1,841' MD/ 1,805' TVD (1,382') ART 6.7 Hrs, AST 5.4 Hrs (12.1 Hrs ADT) 1 0-45K wob, 40 rpm,s 180 spm, 800 gpm, off btm pressure 1700 psi, on btm 1,900 psi, off btm torque 6K ft-Ibs, on btm 9K ft-Ibs, Rot wt 102K, Up wt 106K, Dn wt 96K, 9.1 ppg mw with 340 vis 14:45 - 16:00 1.25 DRILL P SURF Circ 3X btms up for bit trip, circ clean at 800 gpm at 1,800 psi, monitored well-static 16:00 - 19:00 3.00 DRILL P SURF Began POOH on elevators from 1,841' to 1,563', well not taking calc fill, pumped out at 460 gpm at 700 psi from 1,563' and Pulled Tight at 940', backreamed thru spot at 940' to 910 at 800 gpm, pumped out from 910' to 643', cont POOH on elevators standing back HWDP to 189' Note: Hole pulled 5 to 10K over after the first 3 stands and began to swab slightly. Pumped out until hitting 940 which required backreaming with high torque, stalling string. There was a slide from 913 to 953 which yielded a 2.95 degree dogleg and had not been backreamed. This may have contributed, but formation related problems have been seen in this area in other wells. 19:00 - 22:15 3.25 DRILL P SURF POOH from 189' with BHA #1, LD Bit #1 & MU Bit #2, adjusted mud motor from 2.12 bend to 1.83 and moved btm stab up in string, cleared rig floor 22:15 - 23:15 1.00 DRILL P SURF TIH slow, set 10K down on spot at 940', PU and went thru, no other problems TIH 23:15 - 00:00 0.75 DRILL P SURF Washed 95' to btm with no problems, circ btms up staging pump up to 800 gpm at 1,800 psi 10/23/2003 00:00 - 10:30 10.50 DRILL P SURF Drill, slide & survey 16" surface hole from 1,841' to 3,045' MD/ 2,683' TVD (1,204'), (13 3/8" Csg pt) ART 3.4 hrs, AST 3.9 hrs, (7.3 hrs ADT), 20-40K wob, 80 rpm's, 200 spm, 850 gpm, off btm pressure 2,200 psi, on btm 2,400 psi, off btm torque 6k ft-Ibs, on btm 8K ft-Ibs, Rot wt 112K, PU wt 125K, DN wt 105K, 9.5 ppg mw with 200 vis, Note: No gas hydrates were drilled on surface hole 10:30 - 12:00 1.50 DRILL P SURF Circ hole clean at 850 gpm at 2,400 psi and 100 rpm's 12:00 - 14:00 2.00 DRILL P SURF Precautionary pumped out of hole from 3,045' to 2,491', backreamed out from 2,491' to 1,800', pumped and back reamed out at 700 gpm at 1,600 psi, backreamed at 80 rpm's 14:00 - 14:30 0.50 DRILL P SURF TIH to btm with no problems 14:30 - 16:00 1.50 DRILL P SURF Circ hole clean, circ 2.5X btms up, circ at 800 gpm at 2,000 psi at 100 rpm's 16:00 - 18:30 2.50 DRILL P SURF POOH and stood back HWDP & jars with no problems POOH 18:30 - 21 :30 3.00 DRILL P SURF LD 16" stab's, stood back 8" NMDC's and LD MWD and mud mtr, cleared rig floor 21 :30 - 22:45 1.25 CASE P SURF Made dummy run with 13 3/8" landing jt and hanger, marked same, RU Doyon's 13 3/8" 350 ton csg handling tools, MU franks fill up tool and changed out elevator bales. 22:45 - 23:00 0.25 CASE P SURF Held PJSM with Doyon csg hand and rig crew on running 13 3/8" csg Printed: 11/3/2003 9:28:16AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 10/20/2003 10/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 1 0/23/2003 23:00 - 00:00 1.00 CASE P SURF MU HES 13 3/8" float shoe, 2 jts of 13 3/8" 68#, L-80 BTC csg and HES float collar, thread locked conn below float collar and filled pipe & check float equip, ck ok, RIH to 125' 10/24/2003 00:00 - 05:00 5.00 CASE P SURF Fin running 133/8" 68#, L-80, BTC Csg to 3,030', had 50K drag from 1,800' to 1,975', with minor bumps around 2,500 (directional work in both places) no other problems RIH, ran HES 133/8" float shoe, 2 jts 133/8" csg, HES 133/8" float collar, ran 46 jts 13 3/8" csg, MU Tam port collar with pup jt above & below, then ran 24 add jts of 13 3/8" csg, MU Hanger & Landed csg with float shoe at 3,030' and float collar at 2,946', ran a total of 72 jts of 13 3/8" csg, 2 pup jts, Tam port collar, float equip and hanger = 3,001.50', ran 27 Bow spring centralizers per program, no mud loss while RIH with csg 05:00 - 06:30 1.50 CASE P SURF Circ & cond mud thru Franks fill up tool, staged pump rate up to 10 bpm at 700 psi, NOTE: only able to reciprocate pipe 4' due to 13 3/8" csg collar hanging up on btm of 20" conductor, circ 1 csg cap with full returns, String wt up 230K, Dn 155K 06:30 - 07:00 0.50 CASE P SURF LD Franks fill up tool & MU Dowell cement head 07:00 - 10:30 3.50 CASE P SURF Cont to circ & cond mud for cementing, staged pump rate up to 12 bpm, 950 psi, after circ 1,250 bbls of 9.6 ppg mud around lost full returns, was able to cont reciprocating pipe, lost approx 40 bbls of mud before shutting pumps down, checked fluid level on well and unable to see mud in hole, reciprocated pipe 4' while building 9.6 ppg mud volume in pits to displace cement, Held PJSM on cementing 133/8" csg with Dowell and rig crew Note: When returns were lost, the mud returns at the shakers was thick, dehydrated spud mud which had come free from a washed zone in the upper section on the hole. These returns were with sand laden with very small pea gravel. There was app. 100 bbls. of this type of mud. 10:30 - 13:00 2.50 CEMT P SURF Turned over to Dowell and pumped 5 bbls of 10.1 ppg Mudpush, pressure tested lines to 3,500 psi, then Pumped 70 bbls of 10.1 ppg Mud Push II (75 bbls total), NOTE: regained full returns while pumping Mud Push, shut down and dropped btm plug, mixed & pumped 565 bbls, 740 sxs of Arctic set Lite at 10.7 ppg and 4.28 yield with additives, pumped at an ave of 6.5 bpm at 225 psi, followed with 85 bbls, 409 sxs of class "G" tail cmt with additives at 15.8 ppg and 1.17 yield, pumped at ave 5 bpm at 300 psi, had full returns and reciprocated pipe, Shut down. 13:00 - 14:30 1.50 CEMT P SURF Dropped top plug and Dowell pumped 10 bbls FW behind plug, turned over to rig and displaced cement with 9.6 ppg mud, max rate of 8 bpm and ave 6 bpm while displacing cmt, initial pressure 450 psi and max pressure while displacing cmt was 1,000 psi, slowed rate and bumped plug on calc displacement, pressured up on plugs to 2,000 psi, checked floats and held, had good returns during displacement with 290 bbls of 10.7 ppg cement back at surface, CIP at 14:25 hrs 14:30 - 16:30 2.00 CEMT P SURF RD cement head & csg equipment, LD landing jt and flushed out divertor & lines 16:30 - 18:30 2.00 BOPSUR.P SURF ND 21 1/4" Divertor and flushed out bag 18:30 - 19:30 1.00 WHSUR P SURF NU 13 5/8" 5M FMC split speed wellhead, tested seals to 1,000 Printed: 1113/2003 9:28: 16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 10/20/2003 10/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 10/24/2003 18:30 - 19:30 1.00 WHSUR P SURF psi, good test 19:30 - 21:30 2.00 BOPSURP SURF NU 135/8" 5M BOP stack with 3 1/2" x 6" VBR's on top and 5" rams on btm 21 :30 - 00:00 2.50 BOPSUR P SURF RU & began testing BOP's, tested top set of pipe rams, manual kill and lower IBOP to 250 psi low and 4,000 psi high NOTE: Lou Grimaldi with AOGCC waived witnessing of test 10/25/2003 00:00 - 02: 15 2.25 BOPSUR P SURF Fin testing BOP's, tested rams, valves and manifold to 250 psi low and 4,000 psi high, tested annular to 250/2,500 psi. Note Lou Grimaldi with AOGCC waived witnessing test. Had 1 failure, upper IBOP on Top Drive Failed 02:15 - 05:30 3.25 BOPSURP SURF Changed out Upper IBOP on top drive and re-tested to 250/4,000 psi, good test 05:30 - 06:45 1.25 BOPSUR P SURF Pulled test plug and installed wear bushing, RU Riser & Elevator bales 06:45 - 09:45 3.00 DRILL P PROD1 PU & MU 12 1/4" BHA #3 with MWD and Orient same, TIH with HWDP & jars then tested MWD 09:45 - 12:00 2.25 DRILL P PROD1 RIH with BHA #3 PU 63 jts of 5" DP from pipe shed, RIH to 2,863' 12:00 - 13:30 1.50 DRILL P PROD1 Slip & cut 56' of drlg line and serviced top drive 13:30 -14:00 0.50 DRILL P PROD1 Washed down from 2,863' to 2,922' for csg test 14:00 -15:00 1.00 CASE P PROD1 RU and tested 13 3/8" csg to 1,800 psi for 35 min, good test 15:00 - 17:00 2.00 CEMT P PROD1 Drilled up plugs, float collar at 2,946', med cement in shoe track and float shoe at 3,030', began displacing out spud mud with 9.5 ppg LSND mud, pumped 60 bbls spacer ahead of new mud, cont to clean out to btm and drilled 20' of new formation to 3,065', drilled with 5-10K wob and 600 gpm at 1,600 psi 17:00 - 17:30 0.50 DRILL P PROD1 Fin displacing out spud mud with 9.5 ppg LSND mud 17:30 - 18:00 0.50 DRILL P PROD1 RU & performed LOT to 12.5 ppg EMW, formation broke at 420 psi with 9.5 ppg MW at 2,683' TVD 18:00 - 00:00 6.00 DRILL P PROD1 Drill 12 1/4" hole from 3,065' to 3,789' MD/3,132' TVD, (724') ART 2.5 hrs, AST .85 hrs, 1 0-30K wob, 110 rpm's, 189 spm, 800 gpm, off btm pressure 2,050 psi, on btm 2,100 psi, off btm torque 4K ft-Ibs, on btm 6K ft-Ibs, Rot wt 117K, Up wt 125K, Dn wt 107K. Backreaming connections at full drilling pump rate and reducing to 75% on down stroke. Pump sweeps every 300 ft. to start and then as hole dictates. App. 10-20% increase in cuttings back when pumping at 300 ft. Reduced frequency to every 400 ft.. 10/26/2003 00:00 - 12:00 12.00 DRILL P PROD1 Drill 12 1/4" hole from 3,789' to 5,285' MD/4,391' TVD, (1,496') ART 6.7 hrs, AST 1.3 hrs, 5-45K wob, 110 rpm's, 189 spm, 800 gpm, off btm pressure 2,200 psi, on btm 2,300 psi, off btm torque 11 K ft-Ibs, on btm 11 K ft-Ibs, Rot wt 150K, Up wt 180K, Dn wt 129K. Backreaming connections at full drilling pump rate and reducing to 75% on down stroke. Pumped weighted high vis sweeps every 400 ft. App. 10-20% increase in cuttings back 12:00 - 12:30 0.50 DRILL P PROD1 Fin circ out weighted high vis sweep in hole & circ clean at 800 gpm at 2,300 psi and 120 rpm's 12:30-15:15 2.75 DRILL P PROD1 Precautionary pumped out of hole to shoe to 3,000' (Shoe at 3,030'), pumped out at 800 gpm initial pressure 2,300 psi, final pressure at shoe 1,900 psi, no problems pumping out 15:15 -16:45 1.50 DRILL P PROD1 Circ btms up at shoe and had large amount of baseball size clay balls back, circ at 800 gpm at 1,900 psi Printed: 11/3/2003 9:28:16 AM - e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 10/20/2003 10/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 1 0/26/2003 16:45 - 17:30 0.75 DRILL P PROD1 TIH to btm with no problems 17:30 - 20:00 2.50 DRILL P PROD1 Circ btms up and cont to get clay balls back, pumped weighted high vis sweep and circ out, clay balls decreased, cont to circ hole clean at 800 gpm at 2,300 psi and 120 rpm's, circ a total of 4x btms up with no clay balls back on last btms up 20:00 - 23:00 3.00 DRILL P PROD1 Monitored well-static, POOH wet 10 stds to 4,350' with no problems, pumped dry job and dropped 2 3/16" rabbit on wire, Cont to POOH to shoe with no problems, monitored well at shoe- static, POOH and stood back HWDP & jars, recovered rabbit at jars 23:00 - 00:00 1.00 DRILL P PROD1 Began LD 12 1/4" BHA #3, POOH LD 2- 8" NMDC's and 1- 12 1/4" stab to 118'. BHA clean, no clay or cuttings around stabilizers. 10/27/2003 00:00 - 01 :30 1.50 DRILL P PROD1 Fin POOH LD 12 1/4" BHA #3, LD stab's, MWD & mud motor, cleaned rig floor 01 :30 - 01:45 0.25 EVAL P PROD1 Held PJSM with Schlumberger and rig crew on RU and running logs 01:45 - 03:15 1.50 EVAL P PROD1 RU SWS E- line and MU 3 3/8" Platform Express/Sonic/6 Arm Caliper logging tool, over alllenght 86' 03:15 - 05:30 2.25 EVAL P PROD1 RIH with logging tools, tool set down at 2,826' inside 13 3/8" csg, attempted to go deeper with no success, POOH and found 9 1/2" rubber centering guides loaded with clay, changed out guides to 6 1/2" teflon guides 05:30 - 07:00 1.50 EVAL P PROD1 RIH with logging tools, once in open hole determined Induction tool had failed, RIH to 4,460' attempting to get tool to work with no success, POOH 07:00 - 08:00 1.00 EVAL N PROD1 Changed out Induction tool. 08:00 - 10:00 2.00 EVAL P PROD1 RIH, tagged TD at 5,285', logged up to shoe at 3,030', POOH 10:00 - 11 :00 1.00 EVAL P PROD1 RD SWS logging tools and E-line 11:00-11:30 0.50 BOPSURP PROD1 Pulled wear bushing and installed test plug 11 :30 - 13:00 1.50 CASE P PROD1 Changed out top set of VBR rams over to 9 5/8" csg rams and tested door seals. 13:00 - 14:15 1.25 CASE P PROD1 RU Doyon's 9 5/8" 350 ton csg equipment with Franks fill up tool 14:15 - 14:30 0.25 CASE P PROD1 Held PJSM with csg and rig crews on running 9 5/8" csg 14:30 - 18:30 4.00 CASE P PROD1 Ran 9 5/8" 47#, L-80, BTC-M csg to 3,014', (csg shoe at 3,030'), MU HES 9 5/8" float shoe, 2 jts csg and HES float collar, thread locked conn below float collar, pumped thru and checked fit equip, cont RIH with 9 5/8" csg, ran 3 add. jts of csg, 1-20' pup jt with RA tag, 23 jts of 95/8" csg, 1-20' pup jt with RA tag, then ran 44 jts of csg (72 jts total) to 3,015', ran 56 centralizers per well program 18:30 - 19:30 1.00 CASE P PROD1 Circ 1 csg cap at shoe, staged pump rate up to 8 bpm at 550 psi with full returns, hole clean while eire, string up wt 155k, down wt 135K 19:30 - 22:30 3.00 CASE P PROD1 Cont RIH with 9 5/8" csg, washed down slow from 4,091' to 4,210' to move mud up hole, cont RIH and MU landing jt and hanger and landed 95/8" csg, RIH with a total of 126 jts of 9 5/8" 47# L-80 BTC-m csg, 2-20' pup jts, total including float equipment and hanger 5,245.42', landed csg with float shoe at 5,271' and float collar at 5,186', had good returns and no problems RIH 22:30 - 00:00 1.50 CEMT P PROD1 Circ and cond mud thru Franks fill up tool, staged pump rate up Printed: 11/3/2003 9:28:16 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 10/20/2003 10/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 10/27/2003 22:30 - 00:00 1.50 CEMT P PROD1 to 12 bpm at 1,100 psi, reciprocated pipe with no problems or mud loss, St Up wt 240K, Dn wt 175K, Circ 1.5 annular volume, at btms up no increase incuttings 10/28/2003 00:00 - 00:30 0.50 CEMT P PROD1 Lay down Franks fill up tool and make up Dowell cement head. 00:30 - 02:45 2.25 CEMT P PROD1 Cont. to circulate and condition mud for cementing, initial mw 9.6+,73 vis, 24 PV, 35 YP, lowered to 9.5 ppg, 43 vis, 13 PV, and 13 YP, Held PJSM with rig crew and Dowell, batch mix cement circ. & condo mud, reciprocated pipe with 235K UP and 180K DN wt. 02:45 - 04:00 1.25 CEMT P PROD1 Turned over to Dowell, pumped 5 bbls CW 100 at 8.3 ppg, pressure test lines to 400 psi, pumped additional 20 bbls (25 total) of CW 100, pumped 50 bbls of MudPUSH II spacer at 10.4 ppg at 6 bpm at 150 psi, shut down & drop btm plug, pumped 132 bbls 616 sxs Class "G" cmt at 15.8 ppg and 1.2 yield with additives, ave 6.25 bpm at 250 psi, reciprocate pipe, UP 235K, DN 180K, shut down and wash lines. 04:00 - 05:00 1.00 CEMT P PROD1 Dowell flushed lines to rig floor, turned over to rig, dropped top plug and displasced cement with 9.5 ppg mud, initial rate of 12 bpm at 750 psi, appeared to be loosing mud slowed to 8 bpm at 400 psi, losses appeared to stop, increased rate to 10 bpm at 550 psi, when MudPUSH was out of shoe lost returns, after cmt went out of shoe regained returns, max pressure while displacing cmt was 900 psi, slowed rate to 3 bpm and bumped plug on calc. displacement, pressured up on plugs to 1400 psi, checked floats- OK, had good returns during job, reciprocate pipe till CW 100 was at shoe, after cement was past shoe, cont. to recip. pipe, stopped reciprocating pipe at 04:45 hrs, CIP at 04:50 hrs, est TOe at 3,663'. 05:00 - 05:30 0.50 CEMT P PROD1 Rig down Dowell cement head, Lay down landing joint. 05:30 - 06:30 1.00 WHSUR P PROD1 Set 9-5/8" Pack off & test same to 5000 psi for 10 min. 06:30 - 08:15 1.75 WHSUR P PROD1 Set test plug, Change btm pipe rams to 5", Change bails on top drive, Pull test plug, Set wear ring. 08: 15 - 08:45 0.50 DRILL P PROD1 Rig & perform injectivity test down 9-5/8" x 13-3/8" annulas = 3 bpm at 900 psi. 08:45 - 12:00 3.25 CLEAN P COMP Make up 8-1/2" bit & 9-5/8" casing scraper, attempt to RIH- No good, unable to get scaper in hole, Pull wear bushing and retry with same results, Remove scraper and run bit in hole with no problem, Pick up new 9-5/8" scraper, Install wear bushing, RIH- OK. 12:00 - 14:30 2.50 CLEAN P COMP RIH w/ bit & scraper to 5,186'. Note; Rigged up Little Red Service to 9-5/8" x 13-3/8" annulas and freezed protected annulas with 134 bbls dead crude oil at 2.5 bpm @ 1450 psi. 14:30 - 15:00 0.50 CLEAN P COMP Circ btm's up at 590 gpm @ 1000 psi. 15:00 - 17:00 2.00 CLEAN P COMP Change over to clean seawater. 17:00 -18:00 1.00 CLEAN P COMP Rig & test 9-5/8" casing to 3500 psi for 30 min.- OK 18:00 - 21 :00 3.00 CLEAN P COMP POOH & lay down 5" drill pipe and HWDP. 21:00-22:15 1.25 CASE P COMP Pull wear bushing, PJSM, Rig to run 7" kill string. 22:15 - 00:00 1.75 CASE P COMP Run 7" 26# L-80 BTC kill string to 1,378'. 10/29/2003 00:00 - 01 :00 1.00 CASE P COMP Run a total of 57 joints 7" 26# L-80 BTC kill string with a mule shoe at 2343'. 01 :00 - 02:00 1.00 CASE P COMP Land 7" casing on hanger, install two way check. Run in lock down screws. Test hanger to 2700 psi. Lay down landing joint. Printed: 11/3/2003 9:28:16 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 DRILL +COMPLETE DOYON DOYON 141 Start: Rig Release: Rig Number: 10/20/2003 1 0/29/2003 Spud Date: 10/21/2003 End: 10/29/2003 10/29/2003 02:00 - 03:30 03:30 - 08:30 1.50 BOPSUR P 5.00 WHSUR P COMP COMP Nipple down BOP. Install adapter flange and tree. Test void to 5000 psi. Attempt to test tree. Servce master valve and swab valves. Attempt to test again found small leak in OTIS surface safety valve. Valve will be changde out after rig move. Rig up lubricator. Pull two way check valve. Rig up hot oil unit and test lines. Pump 150 bbl diesel at 2.5 bpm holding 270 psi back pressure on choke to avoid premature "U" tube. Freeze protect 7" casing kill string and 7" X 9 5/8" annulus to 2343' Install back pressure valve and test to 1000 psi from below. Install blind flange on tree. Secure well. Pump out cellar. 08:30 - 09:30 09:30 - 12:00 1.00 WHSUR P 2.50 WHSUR P COMP COMP 12:00 - 12:30 12:30 - 14:00 0.50 WHSUR P 1.50 WHSUR P COMP COMP Release rig at 14:00 hrs 29 October 2003 Printed: 11/3/2003 9:28: 16 AM e e W -400 Prudhoe Bay Unit 50-029-23180-00-00 203-165 10/21/03 10/21/03 1 0/29/03 141 Accept: Spud: Release: POST DRILL SUMMARY 05/05/04 RAN USIT FOR CEMENT EVALUATION ON WATER WELL. FOUND TOP OF CLASS G CEMENT AT 3257' WITH GOOD CEMENT OVER All OF lOWER INTERVAL. DID NOT TAG TD. WEll KillED. e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W-400 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/9/2004 5/20/2004 Spud Date: 10/21/2003 End: 5/20/2004 5/9/2004 19:00 - 00:00 5.00 MOB P PRE PJSM. Scope down & layover derrick. Commence moving rig components from MPU L Pad to GPB W Pad. 24 mile move. 5/10/2004 00:00 - 13:00 13.00 MOB P PRE Continue moving rig componenets from MP L PAd to GPB W Pad. 13:00 - 14:30 1.50 MOB P PRE Lay herculite & matting boards. Spot rig in over wellhead. Berm around rig. 14:30 - 16:00 1.50 RIGU P DECOMP Raise & scope up derrick. ACCEPTED RIG @ 1600 Hrs.. 16:00 - 18:00 2.00 RIGU P DECOMP Spot in tiger tank. R/U lines to tiger tank. Install 2nd annular valve & R/U HCR. Clean pits. 18:00 - 22:30 4.50 KILL P DECOMP M/U lines to tree. Con't to clean & jet pits. 22:30 - 23:00 0.50 KILL P DECOMP Pressure test lines to 3500 psi. 23:00 - 23:30 0.50 WHSUR P DECOMP P/U lubricator & pull BPV. UD lubricator. 23:30 - 00:00 0.50 KILL P DECOMP Hold PJSM & Pre-Spud meeting w/ entire crew & mud engineer. 5/11/2004 00:00 - 02:00 2.00 KILL P DECOMP Open well. SITP 0 psi, SlAP 0 psi. Circulate out diesel freeze protection fluid. Pump 6 BPM @ 400 psi & diplace diesel. Pumped 165 Bbls. SID & allow any remaining freeze protect to gunbarrel to surf. Wait 45 min. Pumped 1 additional csg volume ( 175 bbls). Well bore returns appear to be clean. 02:00 - 02:30 0.50 KILL P DECOMP Blow down & disconnect kill lines. 02:30 - 03:00 0.50 WHSUR P DECOMP Install TWC. 03:00 - 04:30 1.50 WHSUR P DECOMP Bleed void & N/D tree. Check hanger threads. Ok. 04:30 - 06:00 1.50 BOPSUP P DECOMP N/U BOPE & spacer spool. 06:00 - 11 :30 5.50 BOPSUP P DECOMP Change pipe rams and finish R/U to test BOPE. Test BOPE to 250/3500 psi, test witness waived by Chuck Sheve. 11:30 -12:30 1.00 BOPSUF P DECOMP P/U Kelly and stack washing tool; clean stack; B/D and lay down same. 12:30 - 13:30 1.00 PULL P DECOMP P/U lubricator and extension; pull TWC; lay down same. 13:30 - 15:00 1.50 PULL P DECOMP M/U landing jt, BOLDS, and pull hanger free w/70K. Fill hole w/ 6 Bbls and receive clean returns to pits. UD landing jt and hanger. 15:00 - 16:00 1.00 PULL P DECOMP RlU to lay down 7", 26#, L-80 tubing. 16:00 - 16:30 0.50 PULL P DECOMP POH and UD 7" tubing. 16:30 - 17:00 0.50 CLEAN P DECOMP Reverse circulate out diesel freeze protect fluid, 3 BPM @ 80 psi for 15 Bbls. 17:00 - 19:00 2.00 PULL P DECOMP POH and UD 7" tubing; total 57 jts and 4' mule shoe pup jt. 19:00 - 20:00 1.00 PULL P DECOMP RID 7" tubing handling equipment and R/U 3-1/2" equipment. 20:00 - 20:30 0.50 PULL P DECOMP Install Wear Ring and run-in 2 lock-down screws. 20:30 - 21 :30 1.00 CLEAN P DECOMP M/U BHA #1: 8.5" bit, bit sub, junk basket, and two 9.125" scrapers. 21:30 - 00:00 2.50 CLEAN P DECOMP RIH w/ BHA #1 on 3-1/2",15.5# DP. 5/12/2004 00:00 - 01 :30 1.50 CLEAN P DECOMP RIH w/ BHA #1 to 4890' MD stopping for 1-stand trips every 500' and making short trip from 4100' to 4890' to ensure adequate scraping of casing for perforation and subsequent installation of gravel packing equipment. 01 :30 - 03:00 1.50 CLEAN P DECOMP Clean rig floor and mix Dirt Magnet sweep solution. 03:00 - 06:00 3.00 CLEAN P DECOMP Reverse circulate 290 Bbls heated, filtered seawater, 20 Bbl Dirt Magnet solution, 20 Bbl hot seawater, 20 Bbls Dirt Magnet solution 6 BPM @ 1200 psi. Follow with 580 Bbls hot, filtered seawater. 06:00 - 11 :30 5.50 CLEAN N WAIT DECOMP SI and wait on vac trucks for hot, filtered seawater. Relocate camp to make room for tankage and equipment for gravel-packing completion operations. Printed: 5/24/2004 9:28:25 AM e e legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W -400 WORKOVER NABORS ALASKA DRilLING I NABORS 4ES Start: 5/9/2004 Rig Release: 5/20/2004 Rig Number: Spud Date: 10/21/2003 End: 5/20/2004 5/12/2004 11 :30 - 13:00 1.50 CLEAN P DECOMP Reverse circulate hot, filtered S/w, 6 BPM @ 1200 psi, TP 100 psi for 401 Bbls. SI and blow down lines. 13:00 - 15:30 2.50 CLEAN N WAIT DECOMP SI, wait on vac trucks for S/W. clean and service rig; load 5-1/2" work string in pipe shed. 15:30 - 17:00 1.50 CLEAN P DECOMP Reverse circulate hot, filtered S/W, 6 BPM @ 1200 psi, TP 100 psi for 400 Bbls. SI and blow down lines. Final turbidity of returned fluid was 13 NTUs. 17:00 - 00:00 7.00 CLEAN N WAIT DECOMP SI and wait on filtered 9.2 KCI brine to be mixed at MI plant and trucked to location. Onsite tank storage not yet available. Service rig. 5/13/2004 00:00 - 05:00 5.00 CLEAN N WAIT DECOMP SI and wait on KCI brine mixed at MI plant from Prince Creek filtered water. First truck arrived @ 0130 hrs, 2nd @ 0500 hrs. 05:00 - 08:00 3.00 CLEAN P DECOMP Reverse circulate clean Sea water from well bore with filtered 9.2 Ib/gal KCL. Final KCL returns = 26 NTUs. 08:00 - 10:30 2.50 CLEAN P DECOMP POOH. Lay down 25 jt 31/2" drill Pipe. Continue POOH...stand-back 43 stands of 31/2" drill Pipe. 1 0:30 - 11 :00 0.50 CLEAN P DECOMP Lay BHA #1. Clean Junk Basket...small amount of metal slivers and mise trash. 11 :00 - 11 :30 0.50 PERF P COMP Hold PJSM for handling 7" Perf guns with All. 11 :30 - 15:30 4.00 PERF P COMP Load Guns and Blank Pipe in Pipe Shed. RIU floor and perforating handling equipment. M/U 429.70' of perforating guns: 18 SPF, 7" High shot Density, 120/60 phasing. 15:30 - 17:30 2.00 PERF P COMP TIH w/ TCP guns on 43 stands 3-1/2" DP, position guns across target interval 4167' to 4597'. P/U wt = 72K. 17:30 - 18:30 1.00 PERF P COMP R/U SWS equipment. 18:30 - 20:30 2.00 PERF P COMP RIH w/ GR and eeL to correlate position of guns. 20:30 - 21 :30 1.00 PERF P COMP R/D SWS and P/U DP 15' to reposition guns. PJSM at 2100 hrs w/ night tour, SWS perf expert, Tour Pusher, BP Engineer, & Co Man. 21 :30 - 22:00 0.50 PERF P COMP Prepare to fire guns. Good surface indication that guns fired at 2150 hours. 22:00 - 00:00 2.00 PERF P COMP Monitor well and break circulation at 4 BPM / 400 psi. 5 minute fluid loss = 3 Bbls. POOH 18 jts to position string above perfs and monitor and circulate well. Build Herculite dike for MI mixing and filtration eqpt. 5/14/2004 00:00 - 01 :30 1.50 PERF P COMP POOH w/3-1/2" DP and stand back in derrick. RIU eqpt to break out and lay down guns. Well taking 18 Bbls per hour of 9.2 ppg KCI. 01 :30 - 03:30 2.00 PERF P COMP PJSM. Break out and lay down guns. All 5160 shots fired. 03:30 - 04:30 1.00 CLEAN P COMP Change out tubular handling equipment to run 3-1/2" DP. M/U Halco Champ Packer and Multi-Service valve. 04:30 - 06:30 2.00 CLEAN P COMP TIH with Halco 9 5/8" Champ Pkr/MS Valve. Set Pkr at 3,680-ft. 06:30 - 10:30 4.00 CLEAN P COMP Rig up N2 Pumper. Test Line to 2,500 psi. Fill dry Drill Pipe with N2 and pressure up to 1,150 psi. Pressure up on Annu with KCL to 1,500 psi and open MS Valve. Surge off N2 cap through Choke to Tiger Tank. Bring pressure down to 0 psi in -30 minutes. No fluid followed N2 to surface. Monitor Well...small trickle of bubbles in bucket. 10:30 - 11 :00 0.50 CLEAN P COMP Pump - 125 bbls...unable to fill Well (Pits empty). 11 :00 - 12:30 1.50 CLEAN P COMP Release Halco Pkr. POOH with 3 1/2" Drill Pipe. 12:30 - 13:00 0.50 CLEAN P COMP Lay down Pkr. 13:00 - 15:00 2.00 CLEAN P COMP Pick-up Mule shoe. TIH with 3 1/2" Drill Pipe to 4,722-ft 4eskb. Printed: 5/24/2004 9:28:25 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W -400 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/9/2004 5/20/2004 Spud Date: 10/21/2003 End: 5/20/2004 5/14/2004 13:00 - 15:00 2.00 CLEAN P COMP Encountered no fill...{Sump Pkr setting depth at 4,602-ft). 15:00 - 22:00 7.00 CLEAN P COMP Park Mule Shoe at 4,722-ft...while hauling Prince Creek water for mixing KCL. 22:00 - 23:00 1.00 CLEAN P COMP Pump 9.2 ppg KCI @ 5 BPM, 350 Bbls to fill hole. No returns 23:00 - 00:00 1.00 CLEAN P COMP Discuss options for decreasing fluid weight. Make change to and mix 8.9 ppg KCI. 5/15/2004 00:00 - 01 :30 1.50 CLEAN P COMP Mix 8.9 ppg KCI brine; 375 Bbls in mud pits. 01 :30 - 03:30 2.00 CLEAN P COMP Pump 180 Bbls 8.9 ppg @ 1-2 BPM w/ no returns. 03:30 - 06:00 2.50 CLEAN P COMP POH and UD 3-1/2" DP per earlier discussion. Continue mixing 8.9 ppg KCI brine. 06:00 - 06:30 0.50 RUNCOMP COMP PJSM with SWS and All. 06:30 - 07:30 1.06 RUNCOMP COMP Rig up SWS and prepare to RIH with GR/JB. 07:30 - 11 :00 3.50 RUNCOMP COMP RIH with a 8.360" GR/JB. Set down at -4,170' (top perfs). Attempt several times. POOH (saw Fluid Level at 275'). Recovered a piece SS band (?). Mark on outside of GR indicated that possibily the band was wedged beside GR. Re-ran same GR/JB. Set down at same depth. Tried several times to get by...pulled tight on last attempt. POOH. Lay down Tool. 11:00 -13:00 2.00 RUNC0rl1f\J COMP Change GR to 8.175". RIH with GR/JB. Saw a "bobble" at 4,170'. Continue down to -4,490'. Had to work through. Set down at -4,530'...unable to pass through after several attempts. POOH had to work back through the 4,170'. Finish POOH. RD SWS. Leave Unit "spotted". 13:00 - 14:00 1.00 CLEAN N COMP Order out 8.50" Flat Btm Mill to drift Csg. Load and tally 150 Jts in Pipe Shed. 14:00 - 19:00 5.00 CLEAN N COMP RIH w/ 8.5" bit on 3-1/2" DP to work through tight spots in perf zones. Tight spots found at 4335',4383',4419',4434',4510', 4547', and 4589'. Ran bit to 4725' without encountering restrictions. 19:00 - 22:00 3.00 CLEAN N COMP POH and UD 3-1/2 DP and 8.5" flat bottom mill. Mill had numerous scoring marks on flutes. Decison made to make GR run. Clear rig floor. 22:00 - 23:00 1.00 RUNCOMP COMP PJSM. R/U SWS and M/U 8.125" GR and J/B and RIH to 4710'. No indication of restrictions. 23:00 - 00:00 1.00 RUNCOMP COMP POH, break out jars, J/B, and UD same. 5/16/2004 00:00 - 01 :00 1.00 RUNCOMP COMP M/U Baker "D" packer for 9-5/8" casing, w/ B guide, 7" mill-out extension, and 7" WLEG muleshoe. 01 :00 - 02:30 1.50 RUNCOMP COMP SWS RIH w/ Baker "D" packer and set packer top @ 4602'. Slowly (10 minutes) worked thru restriction @ 4320' before successfully setting packer on depth. 02:30 - 06:00 3.50 RUNCOMP COMP POH w/ SWS, break out and UD W/L tools, and R/D SWS equipment. R/U 5-1/2" tubing handling eqpt. Preparing screens and associated gravel packing jewelry, 06:00 - 11 :00 5.00 RUNCOMP COMP P/U screen assemblies and M/U with associated completion and setting equipment. 11 :00 - 16:00 5.00 RUNCOIvP COMP P/U 5-1/2",17#, L-80, IBT tbg and TIH w/ screen assembly. 16:00 - 16:30 0.50 RUNCOMP COMP M/U circulating head and space-out pup. 16:30 - 17:00 0.50 RUNCOMP COMP Land the gravel pack screens Snap-Latch Assembly into sump packer top @ 4602'. 17:00 - 20:00 3.00 RUNCOMP COMP PJSM. P/U string to neutral position, RIU to circulate 5 Bbls clean brine, drop 1-3/4" Baker-Lite ball and follow multi-step Baker instructions for setting the Baker SC-1 packer. Packer Printed: 5/24/2004 9:28:25 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W -400 W-400 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 5/9/2004 Rig Release: 5/20/2004 Rig Number: Spud Date: 10/21/2003 End: 5/20/2004 5/16/2004 17:00 - 20:00 3.00 RUNCOMP COMP set @ 1300 psi. Crossover tool released after backside pressure test (1500 psi) against closed annulus. 20:00 - 00:00 4.00 RUNCOMP COMP PJSM. Reverse circulate 5 tubing volumes at 6-7 BPM to reverse out the Baker-Lite packer setting ball. R/U Schlumberger to increase circulating rate to 10-12 BPM. Ball to surface after 3 tubing volumes. 5/17/2004 00:00 - 03:00 3.00 RUNCOMP COMP R/U Sclumberger for Super Pickle and 15% HCI tubing cleaning operations. 03:00 - 04:00 1.00 RUNCOMP COMP Circulate in Super Pickle per Workover program instructions. 04:00 - 06:00 2.00 RUNCOMP COMP Reverse out Super Pickle until returns are clean. 06:00 - 07:00 1.00 RUNCOMP COMP PJSM and valve walk-through for Safety assurance. 07:00 - 09:00 2.00 RUNCOMP COMP Pump 15% HCI acid, spot above X-over port, reverse out to disposal tank until returns are clean and pH is neutral. 09:00 - 10:00 1.00 RUNCOMP COMP PJSM. Displace tubing w/ filtered Prince Creek source water. 10:00 - 10:30 0.50 RUNCOMP COMP Circulating Step Rate test performed by Dowell. 10:30 - 11 :30 1.00 RUNCOMP COMP Reverse Circulating Step Rate Test performed by Dowell. 11 :30 - 14:00 2.50 RUNCOM COMP 14:00 - 15:30 1.50 RUNCOMP COMP Bleed down lines and rig down Dowell. 15:30 - 16:30 1.00 RUNCOMP COMP Monitor well. Tubing flowing at very low rate. 16:30 - 17:00 0.50 RUNCOMP COMP Pump 1/2 tubing volume (45 Bbls) of 8.9 ppg KCI (Prince Creek source) and monitor well. Stopped flowing. 17:00 - 22:30 5.50 RUNCOMP COMP Complete R/D Dowell. POH and UD 5-1/2", 17# workstring. 78 jts remain in Pipe Shed to RIH w/ new ESP completion. 22:30 - 00:00 1.50 RUNCOMP COMP UD 4" inner string. Break out and UD Baker running tool and send to Baker shop for re-dressing. 5/18/2004 00:00 - 01 :00 1.00 RUNCOMP COMP PJSM. R/U SWS for Gravel Pack logging run. 01 :00 - 06:00 5.00 RUNCOMP COMP SWS Gravel Pack logging run. Two down-runs from 3800' to 4610'. Log indicate the Gravel Pack was very successful. RD SWS. 06:00 - 06:30 0.50 RUNCOMP COMP Service Rig. 06:30 - 09:00 2.50 RUNCOMP COMP Rig down remaining DS/SWS Frac equipment. Pull Wear Bushing. Clear Rig Floor. 09:00 - 10:00 1.00 RUNCOMP COMP Rig up to handle ESP Assembly. Hang double groove ESP Sheave. 10:00 - 21 :00 11.00 RUNCOMP COMP Pick-up and service ESP Assembly. Fill motor. String cable over sheave. Connect to motor & test same. P/U X-over. M/U sensor gauge. Hook up RTD & modify RTD clamp. Connect temperature probe. Secure & test same. Repaired short in spooling unit electrical system. 21 :00 - 22:30 1.50 RUNCOMP COMP P/U & RIH w/18 jts 51/2" 17#, L-80 tubing, 22:30 - 23:30 1.00 RUNCOMP COMP Pull Heat trace line over sheave. P/U Cannon clamps & M/U flat guards for Heat Trace. 23:30 - 00:00 0.50 RUNCOMP COMP Con't to P/U & RIH w/5 1/2" 17#, L-BO tubing. Check control lines every 1000'. Pump thru pump every 1000'. 3 BPM @ 200 psi. 5/19/2004 00:00 - 12:00 12.00 RUNCOMP COMP Con't to P/U & RIH w/ 51/2" 17#, L-80 tubing. Install heat trace flat guards on every jt. Pump thru & test ESP every 1000'. Ran total of 80 jts 5 1/2" tubing. Installed: 23 SS bands, 98 Cannon clamps, 8 -3' flat guards, 16 - 4' flat guards, 436 - 6' flat guards & 1189 steel bands. P/U 74K, S/O 62K. Bottom of string @ 3437'. Pump intake @ 3354'. Top of ESP at 3,338'. 12:00 - 18:30 6.50 RUNCOMP COMP M/U hanger on landing jt. Install penetrator. Splice plugs, M/U Printed: 5/24/2004 9:28:25 AM e e Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: W-400 W-400 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 5/9/2004 5/20/2004 Spud Date: 10/21/2003 End: 5/20/2004 5/19/2004 12:00 - 18:30 6.50 RUNCOMP COMP I-wire, heat trace & ESP cable. R/D spooling unit. RID double sheave. Plug in ESP/HT cables. Test connections. 18:30 - 19:30 1.00 RUNCOMP COMP Land completion. P/u 74K, S/O 62K. RILDS.UD landing jt. Blow down lines. 19:30 - 21:00 1.50 BOPSUF P COMP N/D BOPE. Remove spacer spool. N/D 2nd annular valve. 21:00 - 00:00 3.00 WHSUR P COMP N/U adapter flange. Make surface connections to I-wire. Check ESP connection & penetrator. Test adapter flange. N/U & test tree to 5K. M/U lubricator. Pull TWC. UD lubricator. R/u & test lines. Freeze protect well as follows: Pump 48 bbls down tbg & 90 bbls down annulus. 2 BPM @ 350 psi, R/D hot oiler equip & lines. . P/U lubricator & install BPV. Ud lubricator. Clean cellar. R/D lines. Secure well. RELEASE RIG @ 0600 Hrs. 5/20/2004 00:00 - 01 :00 01 :00 - 03:30 1.00 WHSUR P 2.50 WHSUR P COMP COMP 03:30 - 04:30 04:30 - 06:00 1.00 WHSUR P 1.50 RUNCOMP COMP COMP Printed: 5/24/2004 9:28:25 AM SCHLUMBERGER Survey report Client...................: B. P. Exploration (Alaska) Inc. Field....................: Prudhoe Bay Unit-WOA Well. . . . . . . . . . . . . . . . . . . . .: W-400 API number.. .............: 50-029-23180'-'00 Engineer.................: B. Barnes " COUNTy:..................: Doyon 141 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Driller's Pipe Tally GL above permanent.......: 55.17 ft KB above permanent.......: N/A - Top Drive DF above permanent... ....: 83.17 ft ----- vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-). .......: 0.00 ft ----~ Platform reference point--------------- Latitude (+N/S-).........: N 70 17 46.949 Departure (+E/W-)........: W 149 5 41.162 Azimuth from rotary table to target: 152.38 degrees [(c)2003 IDEAL ID8 1C_01] 26-0ct-2003 15:00:02 Spud date....... . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey.... ....: Page 1 of 3 21-0ct-03 26-0ct-03 58 0.00 ft 5285.00 ft e ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2003 Magnetic date.. ..........: 20-0ct-2003 Magnetic field strength..: 1151.11 HCNT Magnetic dec (+E/W-). ....: 25.30 degrees Magnetic dip.............: 80.81 degrees ----- MWD survey Reference Reference G..... .........: Reference H.... ..........: Reference Dip............: Tolerance of G...........: Tolerance of H....... ....: Tolerance of Dip... ......: Criteria --------- 1002.68 mGal 1151.11 HCNT 80.81 degrees (+/-) 2.50 mGal ( + / -) 6. 00 HCNT (+/-) 0.45 degrees e ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 25.30 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 25.30 degrees (Total az corr= magnetic dec - grid conv) Survey Correction Type ...: I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction - SCHLUMBERGER Survey Report 26-0ct-2003 15:00:02 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 210.48 0.24 78.21 210.48 210.48 0.12 0.09 0.43 0.44 78.21 0.11 MWD IFR MSA - 3 221.91 0.25 86.42 11.43 221.91 0.14 0.10 0.48 0.49 78.63 0.32 MWD IFR MSA - 4 297.30 1.45 59.80 75.39 297.29 0.16 0.59 1.47 1. 58 68.22 1. 63 MWD IFR MSA - 5 391. 62 2.32 59.02 94.32 391.56 -0.00 2.17 4.14 4.67 62.32 0.92 MWD IFR MSA 6 480.95 3.29 67.19 89.33 480.78 0.10 4.09 8.05 9.03 63.04 1.17 MWD IFR MSA e - 7 571.99 2.94 72.49 91. 04 571.69 0.73 5.81 12.68 13.95 65.39 0.50 MWD IFR MSA 8 663.25 3.08 71.25 91.26 662.82 1.52 7.30 17.24 18.72 67.04 0.17 MWD IFR MSA - 9 752.58 3.50 79.65 89.33 752.00 2.70 8.56 22.19 23.79 68.90 0.71 MWD IFR MSA - 10 844.08 3.68 75.08 91. 50 843.32 4.18 9.82 27.78 29.46 70.53 0.37 MWD IFR MSA 11 941. 20 4.88 110.79 97.12 940.19 7.95 9.16 34.65 35.84 75.20 2.95 MWD IFR MSA - 12 1033.11 4.94 112.94 91.91 1031.76 13.93 6.23 41.95 42.41 81. 56 0.21 MWD IFR MSA - 13 1123.84 5.08 123.06 90.73 1122.14 20.45 2.51 48.92 48.98 87.06 0.99 MWD IFR MSA - 14 1217.26 6.47 129.99 93.42 1215.09 28.92 -3.13 56.42 56.50 93.17 1. 66 MWD IFR MSA - 15 1311.21 10.43 132.95 93.95 1308.00 41.84 -12.32 66.70 67.83 100.47 4.24 MWD IFR MSA 16 1401.18 14.73 136.95 89.97 1395.79 60.56 -26.24 80.48 84.65 108.06 4.87 MWD IFR MSA - 17 1492.71 18.11 140.06 91.53 1483.58 85.68 -45.65 97.56 107.71 115.08 3.81 MWD IFR MSA - 18 1586.71 20.90 142.25 94.00 1572.18 116.46 -70.11 117.21 136.58 120.89 3.07 MWD IFR MSA - 19 1678.81 22.22 142.94 92.10 1657.83 149.82 -97.00 137.77 168.49 125.15 1. 46 MWD IFR MSA - 20 1771.30 24.13 147.04 92.49 1742.86 185.90 -126.82 158.60 203.07 128.65 2.70 MWD IFR MSA e 1862.69 -161.53 177.67 240.12 132.27 5.13 MWD IFR MSA 21 27.35 154.90 91. 39 1825.19 225.49 - 22 1955.84 29.49 157.55 93.15 1907.12 269.71 -202.10 195.51 281.19 135.95 2.67 MWD IFR MSA - 23 2048.18 29.53 158.39 92.34 1987.48 314.97 -244.26 212.57 323.80 13 8.97 0.45 MWD IFR MSA - 24 2140.64 30.66 158.91 92.46 2067.48 361.05 -287.43 229.44 367.78 141. 40 1. 26 MWD IFR MSA - 25 2233.76 34.03 158.17 93.12 2146.14 410.57 -333.79 247.68 415.64 143.42 3.64 MWD IFR MSA 26 2325.26 37.61 157.86 91. 50 2220.32 463.86 -383.43 267.73 467.65 145.08 3.92 MWD IFR MSA - 27 2418.46 43.43 157.86 93.20 2291.14 524.11 -439.49 290.54 526.85 146.53 6.24 MWD IFR MSA - 28 2511.98 48.09 156.82 93.52 2356.37 590.84 -501.29 316.37 592.78 147.74 5.05 MWD IFR MSA - 29 2605.11 51. 66 155.68 93.13 2416.38 661.87 -566.45 345.06 663.28 148.65 3.95 MWD IFR MSA - 30 2697.94 52.74 154.46 92.83 2473.28 735.14 -632.96 375.98 736.21 149.29 1. 56 MWD IFR MSA - [ (c) 2003 IDEAL ID8 1C 01] - .. ... SCHLUMBERGER Survey Report 26-0ct-2003 15:00:02 Page 3 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100£) type (deg) -------- ------ ------- ------ ----_._-- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 2790.95 54.79 154.99 93.01 2528.25 810.09 -700.80 408.00 810.92 149.79 2.25 MWD IFR MSA - 32 2883.50 52.09 154.77 92.55 2583.37 884.35 -768.11 439.56 884.98 150.22 2.92 MWD IFR MSA 33 2975.87 52.13 155.11 92.37 2640.10 957.18 -834.14 470.43 957.65 150.58 0.29 MWD IFR MSA - 34 3069.43 52.29 153.97 93.56 2697.44 1031.06 -900.90 502.22 1031. 42 150.86 0.98 MWD IFR MSA e - 35 3163.41 54.03 155.22 93.98 2753.78 1106.21 -968.83 534.47 1106.48 151.12 2.14 MWD IFR MSA 36 3256.17 53.77 154.80 92.76 2808.44 1181.08 -1036.77 566.14 1181.27 151. 36 0.46 MWD IFR MSA - 37 3349.67 53.63 154.51 93.50 2863.79 1256.38 -1104.87 598.39 1256.51 151.56 0.29 MWD IFR MSA - 38 3443.35 53.53 153.69 93.68 2919.41 1331.73 -1172.68 631.32 1331.82 151.70 0.71 MWD IFR MSA - 39 3533.61 53.57 154.49 90.26 2973.04 1404.30 -1237.98 663.04 1404.36 151.83 0.71 MWD IFR MSA - 40 3626.54 51. 22 153.68 92.93 3029.74 1477.88 -1304.20 695.21 1477.92 151. 94 2.62 MWD IFR MSA 41 3720.40 47.85 154.58 93.86 3090.64 1549.24 -1368.44 726.38 1549.27 152.04 3.66 MWD IFR MSA - 42 3813.41 44.03 155.67 93.01 3155.31 1615.99 -1429.05 754.50 1616.00 152.17 4.19 MWD IFR MSA - 43 3906.29 40.49 154.95 92.88 3224.04 1678.36 -1485.80 780.58 1678.36 152.28 3.85 MWD IFR MSA - 44 3998.23 37.09 154.79 91.94 3295.70 1735.89 -1537.93 805.03 1735.89 152.37 3.71 MWD IFR MSA - 45 4090.54 33.37 154.12 92.31 3371.10 1789.09 -1585.97 827.97 1789.09 152.43 4.04 MWD IFR MSA 46 4184.10 31. 37 154.05 93.56 3450.11 1839.15 -1631. 02 849.86 1839.15 152.48 2.14 MWD IFR MSA - 47 4276.05 31.38 154.34 91.95 3528.62 1887.00 -1674.11 870.71 1887.01 152.52 0.17 MWD IFR MSA - 48 4368.74 31.68 153.92 92.69 3607.62 1935.45 -1717.73 891.86 1935.46 152.56 0.40 MWD IFR MSA e - 49 4461.86 31.04 152.87 93.12 3687.14 1983.90 -1761. 06 913.55 1983.91 152.58 0.90 MWD IFR MSA 50 4554.55 31.15 151.91 92.69 3766.51 2031.77 -1803.47 935.74 2031.78 152.58 0.55 MWD IFR MSA 51 4647.52 31.26 152.09 92.97 3846.03 2079.94 -1846.00 958.36 2079.95 152.56 0.16 MWD IFR MSA - 52 4741.47 31. 44 151.70 93.95 3926.26 2128.81 -1889.12 981. 39 2128.82 152.55 0.29 MWD IFR MSA - 53 4833.38 31.42 151.73 91.91 4004.69 2176.74 -1931.32 1004.10 2176.74 152.53 0.03 MWD IFR MSA 54 4926.00 31. 26 151.64 92.62 4083.80 2224.91 -1973.73 1026.95 2224.91 152.51 0.18 MWD IFR MSA - 55 5018.92 31. 24 151.82 92.92 4163.23 2273.11 -2016.18 1049.79 2273.11 152.49 0.11 MWD IFR MSA 56 5111.53 31.06 151. 96 92.61 4242.50 2321. 00 -2058.43 1072.35 2321.01 152.48 0.22 MWD IFR MSA - 57 5204.36 30.77 152.83 92.83 4322.14 2368.69 -2100.69 1094.45 2368.69 152.48 0.57 MWD IFR MSA 58 5285.00 30.77 152.83 80.64 4391.43 2409.94 -2137.39 1113.29 2409.95 152.49 0.00 Projected to TD [(c) 2003 IDEAL ID8 lC 01] - - e e W-400 Survey Report S lumberger Report Date: 26·0ct-Q3 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 152.380' Field: Prudhoe Bay Unit· WOA Vertical Section Origin: N 0.000 ft. E 0.000 ft Structure I Slot: W·PAD / W-400 (Slot 41) TVD Reference Datum: KB Well: W·400 TVD Reference Elevation: 83.20 ft relative to MSL Borehole: W·400 Sea Bed I Ground Level Elevation: 55,17 ft relative to MSL UWII API#: 500292318000 Magnetic Declination: 25.294' Survey Name / Date: W-400 / October 26. 2003 Total Field Strength: 57554.502 nT Tort I AHD / 0011 ERD ratio: 96.276' /2449.65 ft /5.453/ 0.558 Magnetic Dip: 80.806' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: October 23. 2003 Location LatlLong: N 70 1746,949. W 149541.162 Magnetic Declination Model: BGGM 2003 Location Grid NlE Y/X: N 5958792,000 ftUS. E 611789.000 ftUS North Reference: True North Grid Convergence Angle: +0.85223889' Total Corr Mag North -> True North: +25.294' Grid Scale Factor: 0.99991420 Local Coordinates Referenced To: Well Head Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS I DLS I Build Rate I Walk Rate I Northing Easting Latitude Longitude Depth Section EW (It) (deg) (deg) (It) (It) (It) (It) (It) (degll00 It) (degll00 It) (degll00 It) (ltUS) (ltUS) 0.00 0.00 0.00 0.00 -83.17 0.00 0.00 0.00 0.00 0.00 0.00 5958792.00 611789.00 N 70 17 46.949 W 149541.162 210.48 0.24 78.21 210.48 127.31 0.12 0.09 0.43 0.11 0.11 0.00 5958792.10 611789.43 N 70 17 46.950 W 149541.149 221.91 0.25 86.42 221.91 138.74 0.14 0.10 0.48 0.32 0.09 71.83 5958792.10 611789.48 N 70 17 46.950 W 149541.148 297.30 1.45 59.80 297.29 214.12 0.16 0.59 1.47 1.63 1.59 -35.31 5958792.61 611790.46 N 70 17 46.955 W149541.119 391.62 2.32 59.02 391.56 308.39 0.00 2.17 4.14 0.92 0.92 -0.83 5958794.23 611793.10 N 70 17 46.971 W 149541.041 480.95 3.29 67.19 480.78 397.61 0.10 4.09 8.05 1.17 1.09 9.15 5958796.21 611796.99 N 70 17 46.990 W 149 5 40.927 571.99 2.94 72.49 571.69 48R52 0.73 5.81 12.68 0.50 -0.38 5,82 5958798.00 611801.60 N 70 17 47.006 W 149 5 40.792 663.25 3.08 71.25 662.82 579.65 1.52 7.30 17.24 0.17 0.15 -1.36 5958799.56 611806.13 N 70 17 47.021 W 149 5 40.659 752.58 3.50 79.65 752.00 668.83 2.70 8.56 22.19 0.71 0.47 9.40 5958800.89 611811.06 N 70 17 47.034 W 149 5 40.515 844.08 3.68 75.08 843.32 760.15 4.18 9,82 27.78 0.37 0.20 -4.99 5958802.23 611816.63 N 70 17 47.046 W 149 5 40.352 941.20 4.88 110.79 940.19 857.02 7.95 9.16 34.65 2.95 1.24 36.77 5958801.67 611823.51 N 70 17 47.039 W 149 5 40.151 1033.11 4.94 112.94 1031.76 948.59 13.93 6.23 41.95 0.21 0.07 2,34 5958798.85 611830.85 N 70 17 47.011 W 149539.939 1123.84 5.08 123.06 1122.15 1038.98 20.45 2.51 48.92 0.98 0.15 11.15 5958795.24 611837.87 N 70 17 46.974 W 149 5 39.736 1217.26 6.47 129.99 1215.09 1131.92 28.92 ·3.13 56.42 1.66 1.49 7.42 5958789.71 611845.45 N 70 17 46.919 W 149539.517 1311.21 10.43 132.95 1308.00 1224.83 41.84 -12.33 66.70 4.24 4.22 3.15 5958780.67 611855.87 N 70 17 46.828 W 149 5 39.217 1401.18 14.73 136.95 1395.79 1312.62 60.56 -26.24 80.48 4.87 4.78 4.45 5958766.96 611869.85 N 70 17 46.691 W 149 5 38.816 1492.71 18.11 140.06 1483.58 1400.41 85.68 ·45.66 97.56 3.81 3.69 3.40 5958747.80 611887.22 N 70 17 46.500 W 149538.318 1586.71 20.90 142.25 1572.18 1489,01 116.47 ·70.12 117.21 3.07 2.97 2.33 5958723.84 611907.22 N 70 17 46.260 W 149537.745 1678.81 22.22 142.94 1657.83 1574.66 149.82 -97.01 137.76 1.46 1.43 0.75 5958697.06 611928.17 N 70 17 45.995 W149537.146 1771.30 24.13 147.04 1742.86 1659.69 185.90 -126.83 158.59 2.70 2.07 4.43 5958667.55 611949.44 N 70 17 45.702 W 149 5 36.539 1862.69 27.35 154.90 1825.19 1742.02 225.49 ·161.54 177.67 5.13 3.52 8.60 5958633.14 611969.03 N 70 17 45.361 W 149535.983 1955.84 29.49 157.55 1907.12 1823.95 269.71 -202.11 195.50 2.67 2.30 2.84 5958592.84 611987.47 N 70 17 44.962 W 149535.463 2048.18 29.53 158.39 1987.48 1904.31 314.98 -244.27 212.56 0.45 0.04 0.91 5958550.94 612005.15 N 70 17 44.547 W 149534.966 2140.64 30.66 158.91 2067.47 1984.30 361.06 -287.45 229.44 1.25 1.22 0.56 595850R 02 612022.67 N701744.122 W 149534.474 2233.76 34.03 158.17 2146.13 2062.96 410.59 -333.81 247.67 3.64 3.62 -0.79 5958461.94 612041.59 N 70 17 43.666 W 149533.943 2325.26 37.61 157.86 2220.32 2137.15 463.87 -383.45 267.72 3.92 3.91 -0.34 5958412.61 612062.37 N701743.178 W 149533.358 2418.46 43.43 157.86 2291.13 2207.96 524.12 -439.52 290.53 6.24 6.24 0,00 5958356.89 612086.01 N 70 1742.627 W 149532.694 2511.98 48.09 156.82 2356.36 2273.19 590.85 -501.32 316.36 5.05 4.98 -1.11 5958295.49 612112.75 N 70 1742.019 W 149531.941 2605.11 51.66 155.68 2416.37 2333.20 661.89 -566.48 345.05 3.95 3.83 -1.22 5958230.77 612142.41 N 70 1741.378 W 149531.105 2697.94 52.74 154.46 2473.27 2390.10 735.16 -632.99 375.97 1.56 1.16 -1.31 5958164.73 612174.31 N 70 1740,724 W 149530.204 2790.95 54.79 154.99 2528.24 2445.07 810.11 ·700.82 408.00 2.25 2.20 0.57 5958097.38 612207.34 N 70 1740.057 W 149 5 29.270 2883.50 52.09 154.77 2583.37 2500.20 884.37 -768.13 439.55 2.92 -2.92 -0.24 5958030.56 612239.89 N 70 1739.395 W 149528.351 2975.87 52.13 155.11 2640.10 2556.93 957.20 -834.16 470.43 0.29 0.04 0.37 5957965.00 612271.74 N 70 17 38.745 W 149 5 27.451 3069.43 52.29 153.97 2697.43 2614.26 1031.08 -900.92 502.21 0.98 0.17 -1.22 5957898.73 612304.51 N 70 1738.089 W 149526.525 3163.41 54.03 155.22 2753.78 2670.61 1106.23 -968.86 534.47 2.14 1.85 1.33 5957831.29 612337.77 N 70 1737.421 W 149 5 25.585 3256.17 53.77 154.80 2808.43 2725.26 1181.10 -1036.79 566.13 0.46 ·0.28 -0.45 5957763.84 612370.44 N 70 1736.752 W 149 5 24.662 3349,67 53.63 154.51 2863.78 2780.61 1256.39 -1104.89 598.39 0.29 -0.15 -0.31 5957696.23 612403.70 N 70 17 36.083 W 149523.722 3443.35 53.53 153.69 2919.40 2836.23 1331.74 ·1172.70 631.32 0.71 -0.11 -0.88 5957628,92 612437.63 N 70 1735.416 W 149522.763 3533.61 53.57 154.49 2973.03 2889.86 1404.31 -1238.00 663.04 0.71 0.04 0.89 5957564.10 612470.32 N 70 17 34.773 W 149521.839 3626.54 51.22 153.68 3029.73 2946.56 1477.90 -1304.22 695.21 2.62 -2.53 -0.87 5957498.38 612503.47 N 70 17 34.122 W 149 5 20.901 3720.40 47.85 154.58 3090.64 3007.47 1549.26 -1368.46 726.37 3.66 -3.59 0.96 5957434.62 612535.58 N 70 17 33.490 W 149519.993 3813.41 44.03 155.67 3155.31 3072.14 1616.01 ·1429.07 754.50 4.19 -4.11 1.17 5957374.43 612564.60 N 70 17 32.894 W 149519.174 3906.29 40.49 154.95 3224.04 3140.87 1678.38 -1485.82 780.57 3.85 -3.81 -0.78 5957318.08 612591.52 N 70 17 32.336 W 149518.414 3998.23 37.09 154.79 3295.69 3212.52 1735.91 -1537.96 805.03 3.70 -3.70 ·0.17 5957266.32 612616.74 N 70 17 31.823 W 149517.702 4090.54 33.37 154.12 3371,08 3287.91 1789.12 ·1586.00 827.97 4,05 -4.03 -0.73 5957218.63 612640.40 N701731.351 W 149517.033 4184.10 31.37 154.05 3450.1 0 3366.93 1839.18 -1631.05 849.86 2.14 -2.14 ·0.07 5957173.91 612662.95 N 70 17 30.908 W 149516.395 4276.05 31.38 154.34 3528.60 3445.43 1887.03 -1674.15 870.70 0.16 0.01 0.32 5957131.13 612684.43 N 70 1730.484 W 149515.788 4368.74 31.68 153.92 3607.61 3524.44 1935.48 -1717.76 891.85 0.40 0.32 -0.45 5957087.84 612706.22 N 70 17 30.055 W 149515.172 4461.86 31.04 152.87 3687.12 3603.95 1983.93 -1761.09 913.55 0.90 -0.69 -1.13 5957044.84 612728.56 N 70 17 29.629 W 149514.540 SurveyEditor Ver 3.1 RT-SP3.03-HFI.2 Bld( d031 rt-546 ) W-400 (Slot 41)\W-400\W-400\W-400 Generated 12/3/2003 4:53 PM Page 1 of 2 e e 4554.55 31.15 151.91 3766.50 3683.33 2031.80 -1803.51 935.73 0.55 0.12 -1.04 5957002.76 612751.37 N 70 1729.211 W 149513.893 4647.52 31.26 152.09 3846.01 3762.84 2079.97 -1846.04 958.35 0.16 0.12 0.19 5956960.58 612774.61 N 70 17 28.793 W 149513.235 4741.47 31.44 151.70 3926.25 3843.08 2128.84 -1889.16 981.37 0.29 0.19 -0.42 5956917.81 612798.28 N 70 1728.369 W 149512.564 4833.38 31.42 151.73 4004.67 3921.50 2176.77 -1931.36 1004.09 0.03 -0.02 0.03 5956875.96 612821.61 N 70 1727.954 W149511.902 4926.00 31.26 151.64 4083.78 4000.61 2224.94 -1973.77 1 026.93 0.18 -0.17 -0.10 5956833.89 612845.09 N 70 1727.537 W 149511.237 5018.92 31.24 151.82 4163.22 4080.05 2273.14 -2016.23 1049.77 0.10 -0.02 0.19 5956791.79 612868.54 N 70 1727.119 W 149510.571 5111.53 31.06 151.96 4242.47 4159.30 2321.04 -2058.48 1072.34 0.21 -0.19 0.15 5956749.88 612891.74 N 70 17 26.704 W 14959.914 5204.36 30.77 152.83 4322.12 4238.95 2368.73 -2100.74 1094.44 0.57 -0.31 0.94 5956707.95 612914.46 N 70 17 26.288 W 14959.270 5285.00 30.77 152.83 4391.41 4308.24 2409.99 -2137.44 1113.28 0.00 0.00 0.00 5956671.54 612933.84 N 70 1725.927 W 14958.721 Leqal Description: Northinq (y) [ftUS] Eastinq (X) [ftUS] Surface: 3818 FSL 1455 FEL S21 T11N R12E UM 5958792.00 611789.00 BHL: 1681 FSL 346 FEL S21 T11 N R12E UM 5956671.54 612933.84 SurveyEdilor Ver 3.1 RT-SP3.03-HF1.2 Bld( d031 rt-546 ) W-400 (Slol 41)\W-400\W-4oo\W-4oo Generated 12/3/2003 4:53 PM Page 2 of 2 ""~"-e Complet n ~OAA roN SUMMi\F& REF LOG: ANGLË AT TOP~: ::::~" ).' ,C;,k 675 1, mINCE ææ< WA1m stm. Y WE WELl.: W·400 API No: 5Q.1)29wZ31ßQ·OO Ii!P ExptOflttlcm (Ala$ ¡<lit) . . 8(')-.:s - II ~C; MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No W -400 Date Dispatched: 26-0ct-03 I nstallationlRig Doyon 141 Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 ReCEIV:D PEC 05 20)3 Alaska )II & Gas Coos. Commiteion AnchØl1!98 Received By: ~\...~ ---........ Please sign and return to: James H. Johnson .~ \.) ~_',~ ~ BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 " c::::' ·K~~"\~ . ~~ ~~ rnrF !Æ~!Æ~~~!Æ . ~IIASIiA. ORAND GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519 Re: Prudhoe bay Unit PBU W -400 BP Exploration (Alaska), Inc. Permit No: 203-165 (Revised) Surface Location: 3819' NSL, 1454' WEL, Sec. 21, TllN, R12E, UM Bottomhole Location: 1718' NSL, 360' WEL, Sec. 21, TIIN, R12E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to drill the above service well. This permit to drill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. You are planning to use this well as a water source to flood the fresh water sensitive Ivishak formation of the Prudhoe Oil Pool. As you know it is essential that the injected fluids be compatible. Therefore, it is a condition of this permit to drill that BP Exploration (Alaska), Inc. collect and test a water sample from the Ugnu Formation and provide results to the Commission that show that it is compatible with the reservoir, prior to using the water in the waterflood. 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 659-3607 (pager). Sincerely, ~ ~~ Rand;2edrich Commissioner BY ORDER OF THE COMMISSION DATED thisJ}1 day of October, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section _ STATE OF ALASKA . ALASKA cPAND GAS CONSERVATION COM VI SSION PERMIT TO DRILL 20 MC 25.005 1b. Current Well Class 0 Exploratory o Stratigraphic Test II Service 5. Bond: 181 Blanket 0 Single Well Bond No. 2S100302630-277 6. Proposed Depth: MD 5210 TVD 4306' 7. Property Designation: ADL 028263 II 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: 3819' NSL, 1454' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 2181' NSL, 609' WEL, SEC. 21, T11N, R12E, UM Total Depth: 1718' NSL, 360' WEL, SEC. 21, T11N, R12E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-611789 y. 5958792 Zone-ASP4 16. Deviated Wells: Kickoff Depth 1&. . Casing Program Size Casing 20" 13-3/8" 9-5/8" Hole 36" 16" 12-1/4" 400 ft Maximum Hole Angle Specifications Grade Coupling H-40 Weld L-80 BTC L-80 BTC Weight 91.5# 68# 47# It'- J. \ I" I l l L ... ,oJ Revised: 10/13/03 o Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU W-400 12. Field / Pool(s): Prudhoe Bay Field I Ugnu 8. Land Use Permit: 13. Approximate Spud Date: October 20,2003 14. Distance to Nearest Property: 13200' 9. Acres in Property: 2560 53° 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool (Height above GL): = 81.3' feet W-06 is 1360' away at 3397' 17. Anticipated pressure (see 20 MC 25.035) ,/ Max. Downhole Pressure: 1955 psig. Max. Surface Pressure: 1540 psig Setting Depth Quantity of Cement Top '. i ··.··Bottom (c.f. or sacks) MD rvD MD rvD (including stage data) Surface Surface 110' 110' 260 sx Arctic Set (Approx.) Surface Surface 3022' 2656' 702 sx Articset Lite, 408 sx 'G' /' Surface Surface 5210' 4306' 764 sx Class 'G' ,-./ Length 80' 3022' 5210' 19. PRESENT WELL CONDITIONSQMMARY (To be.complete(:ffOr RedriU þ,NDRe-entryOperations) Total Depth MD (ft): Total Depth rvD (ft): Plugs (measured): Depth MD (ft): Depth rvD Junk (measured): 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Bill Isaacson Title Senior Drilling Engineer Phone 564-5521 Date 10/ Permit To Drill Number: 203-165 50-029-23180-00-00 Conditions of Approval: Samples Required 0 Yes 0 No Hydrogen Sulfide Measures 0 Yes 0 No Other: 'Tes+ BaPE to ~$'OO ¡1s'£ ~~I4-1.U.-... M.I:T I I!( M.lM-t- ~i.uJX1 ~j r-eð I.vtW 4 . Approved Bv: ~ ~!./L- Form 10-401 Re~ise~ 3;200} Structural Conductor Surface Intermediate Production Liner Perforation Depth MD (ft): 20. Attachments 0 Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch perfOration Depth rvD (ft): 181 Drilling Program 0 Time vs Depth Plot o Seabed Report 181 Drilling Fluid Program o Shallow Hazard Analysis 18120 MC 25.050 Requirements Date: Contact Neil Magee, 564-5119 Prepared By Name/Number: Terrie Hubble, 564-4628 ~..... L) Permit A~val t Q Date: ",/30 ¡'()_-) Mud Log equir~ Directional Survey Required dfìf:l ~ iJ3 ;~ Gas COliS. BY ORDER OF o Rortjr~J\ LTHE COMMISSION Date /Z¡/r( ~ Submit In Duplicate bp . . To: Winton Aubert - AOGCC Date: October 14, 2003 From: Neil Magee - BPXA GPB Drilling & Wells Subject: W-400 Permit to Drill Application- Revised Dear Mr. Aubert, Attached is a revised Permit to Drill Application for the W-400 water source well. As a result of the longer than anticipated time taken for the drilling of W-209 by Nabors 9ES, it looks like it will be necessary for both Doyon 141 and Nabors 9ES to be on W Pad simultaneously. Unfortunately the original planned surface location of W-400 will make it difficult for Nabors 9ES to depart the pad once W-209 is complete. To allow for adequate rig clearance for Nabors 9ES to reach the access road it is necessary to have the W-400 surface location moved 70' to the North. /' All other details of the well remain the same. /' If you have any questions or require any additional information, please contact me at 564-5119. Scope Summary of DrillinQ Operations: 1. MIRU rotary drilling Rig 2. Nipple up diverter spool and riser. PU 5" DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/LWD (page 5) and directionally drill surface hole to approximately 100' TVD below the SV3 Sands. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. 4. Run and cement the 13-3/8", 68# surface casing back to surface. A Tam port collar may be run as a contingency if surface drilling is problematic. 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 12-1/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. Test the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Leak Off Test. 8. Drill to +/- 4255' TVDss. (Below the base of the UG3.) Condition hole for e-line logging. 9. Run Pex/Sonic from TD to surface casing shoe. Review log to determine cement volume required for production string cementing. 10. Run and cement the 9-5/8", 47# production casing. Test casing to 3500 psi. 11. Freeze protect the 13-3/8" x 9-5/8" annulus to 2200' TVDss. Record formation breakdown pressure on the Morning Report. 12. RIH with casing scraper and POOH laying down drill pipe. (Contingency) 13. Run a 5-1/2",15.5#, Butt, L-80 kill string assembly to 2200'. 14. Install TWC and nipple down the BOPE. Nipple up tree adapter on top of wellhead with 7-1/16" valve on top. Remove TWC. 15. RU hot oil truck and freeze protect well by reversing in diesel to freeze protect well from 2200' to surface. Allow to equalize. 16. Rig down and move off. W-400 Permit to Drill Application . . Completion Operations 1. MIRU Nabors 4ES 2. Nipple up and test BOP's. 3. Circulate out diesel freeze protect and recover kill string. 4. Perforate and gravel pack approximately 300' of the Ugnu 4A and Ugnu 3 intervals 5. Complete well with a 5-1/2" completion string and 800 hp ESP. 6. ND and install surface tree and ESP feed throughs. 7. Rig down and move off. W-400 Permit to Drill Application · . I Well Name: I W-400 Drilling Plan Summary- Revised Surface Location I Type of Well (service I producer I injector): I Service (Water Source Well) Surface Location: As-Built (Slot 43) Target Location: Bottom Hole Location: x = 611,789' Y = 5,958,792' 3818'FSL,1455'FEL,Sec.21,T11N,R12E X = 612,662.00' Y = 5,957,167.00' 2181'FSL,609'FEL,Sec.21, T11N, R12E X = 612,919.00' Y = 5,956,708.00' 1718'FSL,360'FEL,Sec.21, T11N, R12E Top of proposed water source interval in W-400 is 1360' ft away from W-06 the nearest wellbore. The well approaches within 13,200' ft of the nearest Prudhoe Bay property line. I AFE Number: 1 ??????? I Estimated Start Date: 110/20/2003 I I Rig: 1 To be determined I MD: 15210' 1 I TVD: 14306' I I RT/GL: 128.5' I 17.0 I RKB: 181.3' I Operating days to drill: I Well Design (conventional, slim hole, etc.): 12 String Water Producer I Objective: 1 Water source well in Ugnu reservoir CasinglTubing Program: Hole Csgl Wt/Ft Grade Conn Size Tbg O.D. 36" 20" 91.5# H-40 WLD 16" 13-3/8" 68# L -80 BTC 12 %" 9 5/8" 47# L-80 BTC Tubing 5 Y2" 15.5# L-80 IBT-M * 9-5/8" 47# Burst 6,870 psi, collapse 4,750 psi ** 13-3/8" 68# Burst 5,020 psi, collapse 2,260 psi Length 80' 3022' 5210' TBD Top MDITVD GL GL GL GL Btm MDITVD bkb 11 0/11 0 3022'/2656' 5210'/4306' TBD W-400 Drilling Program Revised Surface Location- Draft Page 1 . . Mud Program: 16" Surface Hole (0-3022'): Initial Base PF to top SV SV toTO Density (ppg) 8.5- 9.2 9.0 - 9.5 9.5 max Viscosity (seconds) 250-300 200-200 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ff) (mis/30m in) 45 - 70 NC 35-45 <8 25 - 35 < 8 9.0- 9.5 9.0 - 9.5 9.0- 9.5 12-1/4" Production Hole (3022' - 5210'): Interval Density YP PV pH (ppg) To TO 9.5 30 10 9.0-9.5 LSND API Filtrate 4-6 Hydraulics: Surface Hole: 16" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2015' 775 5" 19.5# 50 1800 9.5 N/A 3X18,20 1.052 2015' -3685' 850 5" 19.5# 50 2200 9.7 N/A 3X18,20 1.052 Production Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 3685' - 5029' 800 5" 19.5# 91 2400 11.1 N/A 2x18,16,24 1.135 Hole Cleaning Criteria: Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation Surface to SV-1 280 80 850 9.5 Acceptable 340 80 850 9.5 Marginal-Poor 300 100 850 9.5 Acceptable 350 100 850 9,5 Marginal-Poor 12-1/4" to Sweeps and fully reamed connections to maintain Top WS minimum hole cleaning requirements 280 80 800 9.5 Acceptable 340 80 800 9.5 Marginal-Poor 300 100 800 9,5 Marginal W-400 Drilling Program Revised Surface Location- Draft Page 2 Directional: Ver. I Anadrill(P8)(Slot 41) KOP: 400' Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Production Hole . . 53 deg at 2653' MD All wells pass 1/200 minor risk criteria. W -40 - 36' @ 688' W -42 - 37' @ 648' IFR-MS corrected surveys will be used for survey validation. Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Formation Markers: Formation Tops Base Permafrost SV5 SV4 SV3 SV2 SV1 UG4A UG3 UG1 WS1 TD Criteria TVDss 1800 1850 1972 2483 2680 2994 3397 3654 4156 4225 Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe MWD 1 GR None None MWD/GR/RES/(Res Recorded) Pex/Sonic US IT (done after rig release) Estimated pore pressure, PPG 8.7 ppg EMW, water bearing 8.7 ppg EMW, water bearing 8.7 ppg EMW, water bearing 8.7 ppg EMW, water bearing 8.7 ppg EMW, water bearing 8.7 ppg EMW, water bearing, (1955 psi) 8.9 ppg EMW, water bearing, Drill below base of UG1 (4225' TVDss) Test Type LOT EMW 10.5 ppg EMW Target W-400 Drilling Program Revised Surface Location- Draft Page 3 . . Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casing Size 113-3/8" Surface I Basis: Lead: Based on conductor set at 110', 1978' of annulus in the permafrost @ 250% excess and 184' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2272' MD ~\ I Total Cement Volume: Lead 557 bb1EI 25 ft<J I ,0 ~ks of Dowell ARTICSET Lite at 10.7 ~p an 4.4~cf/. Tail . \1 Ift<J 40 ks of Dowell Premium 'G' at 15.8 ppg and 1.1 disk. / The production casing will be cemented bringing cement up to the surface casing shoe. Actual volumes will be based on e-line log interpretation. Casing Size I 9-5/8" Production Longstring I Basis: 1 Based on cement from TD to surface casing shoe + ~ excess + 80' shoe Total Cement Volume: I ~8,..9~ls I 886 ft<J C!.JjSkS of Dowell G at 15.8 ppg and &/Sk W-400 Drilling Program Revised Surface Location- Draft Page 4 . . Well Control: Surface hole will be drilled with a diverter. The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular . preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 3500 psi for casing integrity considerations, the BOP equipment will be tested to 4000 psi. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: · Maximum surface pressure: 1955 psi @ 4156' TVDss - Ugnu 1540 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi (The casing will be tested to 3500) 9.3 ppg filtered brine / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. W-400 Drilling Program Revised Surface Location- Draft Page 5 . . DRilliNG PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor was installed May 1988. 1. Weld an FMC landing ring for the FMC BB wellhead on the 20" conductor. Install two 4" outlets on the conductor pipe for surface cementing operations. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. PU 5" DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/LWD (page 5) and directionally drill surface hole to approximately 100' TVD below the SV3 Sands. An intermediate wiper/bit trip to surface for a bit will be performed prior to exiting the Permafrost. 4. Run and cement the 13-3/8", 68# surface casing back to surface. A Tam port collar may be run as a contingency if surface drilling is problematic. 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 12-1/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. Test the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Leak Off Test. 8. Drill to +/- 4255' TVDss. (Below the base of the UG1.) Condition hole for e-line logging. 9. Run Pex/Sonic from TD to surface casing shoe. Review log to determine cement volume required for production string cementing. 10. Run and cement the 9-5/8",47# production casing. Test casing to 3500 psi. 11. Freeze protect the 13-3/8" x 9-5/8" annulus to 2200' TVDss. Record formation breakdown pressure on the Morning Report. 12. RIH with casing scraper and POOH laying down drill pipe. (Contingency) 13. Run a 5-1/2",15.5#, Butt, L-80 kill string assembly to 2200'. 14. Install TWC and nipple down the BOPE. Nipple up tree adapter on top of wellhead with 7-1/16" valve on top. Remove TWC. 15. RU hot oil truck and freeze protect well by reversing in diesel to freeze protect well from 2200' to surface. Allow to equalize. 16. Rig down and move off. W-400 Drilling Program Revised Surface Location- Draft Page 6 . . W-400 Drilling Programme Job 1: MIRU Hazards and Contingencies ).- W-Pad is not designated as an H2S site. None of the current producers on W-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. ).- The cellar area surrounding W-400 should be checked to insure level prior to move in. ~ Check the landing ring height on the W-400 conductor prior to move-in. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" --- Job 2: Drillinq Surface Hole ~ There are two close approach issues in the surface hole. W-40 approaches with a center to center distance of 36' at 688' and W-42 approaches within 37' at 648' ~ Hydrates/gas cut mud have been observed in wells drilled on W-Pad. These were encountered near the top of the SV sands. In addition wood and "boulders" have been encountered at approximately 1000' in offset wells. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations (during gyro use) Job 3: Install Surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1000'MD to allow remedial cementing. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" W-400 Drilling Program Revised Surface Location- Draft Page 7 . . Job 7: DrillinQ Production Hole Hazards and Contingencies ~ W-400 is not expected to cross any faults in the production hole section. There are two regional faults near the UG3 formation however the W-400 directional plan stays well to the south-east. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regardingLCM treatments and procedures and adjust drilling practices accordingly. ~ KICK TOLERANCE: In the case scenario of 8.9 ppg pore pressure at the Ugnu target depth, gauge hole, a fracture gradient of 11.0 ppg at the surface casing shoe, 9.4 ppg mud in the hole the kick tolerance is approximately 75 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Manager if LOT is less than 10.5 ppg. ~ There are no "close approach" issues with the production hole interval of W-400. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. ERD Recommended Practice Section 5.2 " Operating Practices" Job 8: LOQ Production Hole Hazards and Contingencies ~ Differential sticking is a concern. Keep tools moving at all times and monitor line tension. Operational Specifics . Run Pex/Sonic from TO to surface casing shoe. Collect data for determining open hole volume for upcoming production hole cement job. Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The interval is planned to be cemented with a single 15.8 ppg slurry. The slurry will cover from production hole TO to the surface casing shoe. Review e-line logs to help determine cementing volume as accurately as possible such that the production hole is cemented just up to the surface casing shoe. ~ Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. Pump approximately Y2 volume of casing-casing annulus prior to freeze protecting. After freeze protecting the 13-3/8" x 9-5/8" casing outer annulus with dead crude (2200' TVD), the hydrostatic pressure will be 7.5 ppg vs 8.9 ppg EMW of the formation pressure immediately below the shoe (worst case). Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 110 psi underbalance to the open hole. W-400 Drilling Program Revised Surface Location- Draft Page 8 . . ~ A LCM pill composed of "G Seal" may be placed across the production interval to help arrest mud dehydration if losses were experienced while drilling this interval. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 12: Run Kill Strinq Hazards and Contingencies ~ Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running the kill string. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus -------;;! Job 13: ND/NUlRelease Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus W-400 Drilling Program Revised Surface Location- Draft Page 9 W-400 (P8) Proposal Schlumberger Report Date: October 13, 2003 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 152.380' Field: Prudhoe Bay Unit - WOA st-JdY Vertical Section Origin: N 69490 ft, E 0.280 ft Structure / Slot: W-PAD IW-400 (Slot 41) SI TVD Reference Datum: KB Well: PlanW-400(Slot41) slblllty TVD Reference Elevation: 8140 ft relative to MSL Borehole: Plan W-400 Fea Sea Bed / Ground Level Elevation: 5343 ft relative to MSL UWIIAPI#: 500292318000 Magnetic Declination: 25.298' Survey Name / Date: W-400 (P8) 1 October 13,2003 Total Field Strength: 57554.271 nT Tort I AHD I DDII ERD ratio: 77.207' 12393.55 ft 15.3491 0.55E Magnetic Dip: 80.806' Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feel Declination Date: October 20, 2003 . Location Lat/Long: N 70.29637482. W 149.09476709 Magnetic Declination Model: BGGM 2003 Location Grid NIE YIX: N 5958792.000 ftUS, E 611789.000 ftUS North Reference: True North Grid Convergence Angle: -+0.85223889' Total Corr Mag North·> True North: +25.298' Grid Scale Factor: 0.99991420 Local Coordinates Referenced To: Well Head I Comments Measured Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Latitude Longitude Depth Section (II) (deg) (deg ) (II) (II) (II) (II) (II) (deg/100 II) (deg/100 II) (deg1100 II) (deg ) (IIUS) (IIUS) KBE 0.00 0.00 90.00 0.00 -81.43 61.44 0.00 0.00 0.00 0.00 0.00 90.00M 5958792.00 611789.00 N 70.29637482 W 149.09476709 Ndg 1.5/100 400.00 0.00 90.00 400.00 318.57 61.44 0.00 0.00 0.00 0.00 0.00 90.00M 5958792.00 611789.00 N 70.29637482 W 149.09476709 500.00 1.50 90.00 499.99 418.56 62.05 0.00 1.31 1.50 1.50 0.00 90.00M 5958792.02 611790.31 N 70.29637482 W 149.09475649 End Ndg 600.00 3.00 90.00 599.91 518.48 63.87 0.00 5.23 1.50 1.50 0.00 90.00M 5958792.08 611794.23 N 70.29637482 W 149.09472471 KOP Cry 1.5/100 1100.00 3.00 90.00 1099.22 1017.79 76.00 0.00 31.40 0.00 0.00 0.00 110.00M 5958792.47 611820.40 N 70.29637482 W 149.09451283 Cry 3.5/100 1200.00 4.00 110.00 1199.04 1117.61 79.79 -1.19 37.30 1.56 1.00 20.00 132.10M 5958791.36 611826.31 N 70.29637156 W 149.09446511 1300.00 6.87 132.10 1298.59 1217.16 87.98 -6.40 45.01 3.50 2.87 22.10 25.46G 5958786.27 611834.10 N 70.29635734 W 149.09440264 1400.00 10.14 140.68 1397.48 1316.05 102.21 -17.22 55.03 3.50 3.27 8.57 16.98G 5958775.60 611844.28 N 70.29632778 W 149.09432153 1500.00 13.53 145.05 1495.34 1413.91 122.43 -33.62 67.31 3.50 3.39 4.37 12.70G 5958759.39 611856.80 N 70.29628298 W 149.09422209 1600.00 16.96 147.68 1591.81 1510.38 148.57 -55.53 81.81 3.50 3.43 2.64 10.15G 5958737.70 611871.62 N 70.29622311 W 149.09410470 1700.00 20.41 149.45 1686.53 1605.10 180.53 -82.88 98.48 3.50 3.45 1.77 8.48G 5958710.60 611888.69 N 70.29614839 W 149.0179 1800.00 23.88 150.73 1779.14 1697.71 218.19 -115.56 117.24 3.50 3.47 1.27 7.30G 5958678.20 611907.94 N 70.29605911 W 149.0 85 1900.00 27.35 151.69 1869.30 1787.87 261.40 -153.46 138.04 3.50 3.48 0.97 6.42G 5958640.63 611929.29 N 70.29595559 W 149.0 47 2000.00 30.83 152.46 1956.67 1875.24 310.02 -196.42 160.79 3.50 3.48 0.76 5.76G 5958598.01 611952.68 N 70.29583821 W 149.09346527 Base Perm 2088.53 33.92 153.01 2031.43 1950.00 357.42 -238.56 182.50 3.50 3.48 0.63 5.29G 5958556.21 611975.01 N 70.29572309 W 149.09328954 2100.00 34.32 153.08 2040.92 1959.49 363.85 -244.29 185.41 3.50 3.49 0.57 5.23G 5958550.52 611978.01 N 70.29570743 W 149.09326594 SV5 2118.85 34.97 153.18 2056.43 1975.00 374.56 -253.85 190.25 3.50 3.49 0.56 5.15G 5958541.03 611982.99 N 70.29568132 W 149.09322673 2200.00 37.80 153.60 2121.75 2040.32 422.70 -296.89 211.81 3.50 3.49 0.51 4.81G 5958498.32 612005.18 N 70.29556373 W 149.09305222 SV4 2270.40 40.26 153.92 2176.43 2095.00 467.01 -336.65 231.41 3.50 3.49 0.45 4.56G 5958458.85 612025.37 N 70.29545510 W 149.09289356 2300.00 41.29 154.04 2198.85 2117.42 486.34 -354.03 239.89 3.50 3.49 0.42 4.47G 5958441.61 612034.11 N 70.29540763 W 149.09282491 2400.00 44.78 154.43 2271.93 2190.50 554.54 -415.49 269.54 3.50 3.49 0.39 4.19G 5958380.61 612064.67 N 70.29523973 W 149.09258485 2500.00 48.27 154.77 2340.72 2259.29 627.04 -481.03 300.66 3.50 3.49 0.34 3.95G 5958315.53 612096.75 N 70.29506065 W 149.09233295 2600.00 51.77 155.08 2404.96 2323.53 703.58 -550.43 333.12 3.50 3.49 0.31 3.75G 5958246.63 612130.24 N 70.29487106 W 149.09207015 Well Design Ver 3.1RT-SP3.03-HF1.2 Bld( d031rt-546) W-400 (Slot 41 )IPlan W-400 (Slot 41 )IPlan W-400IW-400 (P8) Generated 10/13/2003 11: 13 AM Page 1 of 2 Comments Measured I Inclination I Azimuth I TVD I Sub-Sea TVD I Vertical I NS EW I DLS I Build Rate I Walk Rate I Tool Face I Northing Easting Latitude Longitude Depth Section (It) (deg) (deg) (It) (It) (It) (It) (It) (deg/100 It) (degf100 It) (deg/100 It) (deg ) (ltUS) (ltUS) End Bid 2653.52 53.64 155.23 2437.39 2355.96 746.10 -589.06 351.01 3.50 3.49 0.28 O.OOG 5958208.28 612148.70 N 70.29476552 W 149.09192536 SV3 2871.15 53.64 155.23 2566.43 2485.00 921.14 -748.19 424.43 0.00 0.00 0.00 O.OOG 5958050.27 612224.47 N 70.29433078 W 149.09133100 13-318" Csg PI 3022.94 53.64 155.23 2656.43 2575.00 1043.22 -859. 18 475.64 0.00 0.00 0.00 O.OOG 5957940.07 612277.32 N 70.29402756 W 149.09091648 SV2 3208.46 53.64 155.23 2766.43 2685.00 1192.43 -994.83 538.23 0.00 0.00 0.00 O.OOG 5957805.37 612341.91 N 70.29365697 W 149.09040986 Drp 4/100 3573.24 53.64 155.23 2982.71 2901.28 1485.80 -1261.54 661.29 0.00 0.00 0.00 -174.82G 5957540.54 612468.92 N 70.29292830 W 149.08941380 3600.00 52.57 155.11 2998.78 2917.35 1507.17 -1280.97 670.27 4.00 -3.98 -0.45 -174.75G 5957521.26 612478.19 N 70.29287523 W 149.08934106 3700.00 48.59 154.62 3062.27 2980.84 1584.33 -1350.89 703.07 4.00 -3.98 -0.49 -174.44G 5957451.83 612512.02 N 70.29268420 W 149.08907563 3800.00 44.61 154.07 3130.97 3049.54 1656.93 -1416.37 734.51 4.00 -3.98 -0.55 -174.06G 5957386.83 612544.43 N 70.29250530 W 149.08882119 3900.00 40.63 153.43 3204.54 3123.11 1724.61 -1477.10 764.43 4.00 -3.98 -0.64 -173.59G 5957326.57 612575.25 N 70.29233940 W 149.08857898 4000.00 36.66 152.69 3282.63 3201.20 1787.04 -1532.76 792.70 4.00 -3.97 -0.75 -173.00G 5957271.33 612604.34 N 70.29218731 W 149.08835018 UG4 4041.69 35.00 152.33 3316.43 3235.00 1811.44 -1554.41 803.97 4.00 -3.97 -0.85 -172.72G 5957249.85 612615.93 N 70.29212817 W 149..03 4100.00 32.69 151.79 3364.86 3283.43 1843.91 -1583.10 819.18 4.00 -3.97 -0.94 -172.26G 5957221.39 612631.56 N 70.29204978 W 149. 90 UG4a 4101.87 32.62 151.77 3366.43 3285.00 1844.92 -1583.99 819.66 4.00 -3.96 -1.00 -172.25G 5957220.51 612632.05 N 70.29204735 W 149.08813205 End Drp 4117.48 32.00 151.61 3379.62 3298.19 1853.26 -1591.34 823.61 4.00 -3.96 -1.02 O.OOG 5957213.23 612636.12 N 70.29202729 W 149.08810003 W-400 Tgt 4217.48 32.00 151.61 3464.43 3383.00 1906.25 -1637.95 848.81 0.00 0.00 0.00 O.OOG 5957167.00 612662.00 N 70.29189993 W 149.08789611 UG3 4532.31 32.00 151.61 3731.43 3650.00 2073.06 -1784.71 928.14 0.00 0.00 0.00 O.OOG 5957021.45 612743.50 N 70.29149897 W 149.08725412 UG1 5128.96 32.00 151.61 4237.43 4156.00 2389. 18 -2062.83 1078.4 7 0.00 0.00 0.00 O.OOG 5956745.62 612897.94 N 70.29073910 W 149.08603754 WS1 5210.31 32.00 151.61 4306.42 4224.99 2432.28 -2100.75 1098.97 0.00 0.00 0.00 O.OOG 5956708.01 612918.99 N 70.29063550 W 149.08587167 TD 1 9-5/8" Csg 5210.32 32.00 151.61 4306.43 4225.00 2432.29 -2100.76 1098.97 0.00 0.00 0.00 O.OOG 5956708.00 612919.00 N 70.29063548 W 149.08587165 Leqal Description: Northin!! (Y) [ftUS] Eastinq (X) [ftUS] Surface: 3818 FSL 1455 FEL S21 T11N R12E UM 5958792.00 611789.00 W-400 Tgt: 2181 FSL 610 FEL S21 T11 N R12E UM 5957167.00 612662.00 TD 1 BHL : 1718 FSL 360 FEL S21 T11 N R12E UM 5956708.00 612919.00 . WellDesign Ver 3.1RT-SP3.03-HF1.2 Bld( d031rt-546) W-400 (Slot 41 )\Plan W-400 (Slot 41 )\Plan W-400\W-400 (P8) Generated 10/13/2003 11: 13 AM Page 2 of 2 WEll MagnetiC Parameters Model' BGGM 2003 W-400 (Slot 41) (P8) Dip 80.806' MagDac" +25.298" o 750 1500 £' Õ C) <p ~ ~ II Q) -æ o (/) o ~ 2250 3000 3750 4500 . . Schlumberger FIELD STRUCTURE W-PAD Prudhoe Bay Unit - WOA Date: 0<:\0ber20,2003 FS: 57554.3nT SurfacelocatÍOfl Lat N701746.949 Lon" W149541.162 NAD27 Alaska State Planes, Zone 04, US f"eet Northing 5958792.00nuS GIidConv: +0,85223889" Easting" 6t1789.00ttUS ScaIeFacI: 0.9999141961 Miscellaneous Slot: W-400(SIot41) Plan: W-400(P8) o 2250 750 1500 Ndgl.5/100 End Ndg KOP Cry 1.51100 --- Cry 3.5/100 W-400 (PS) o 750 1500 2250 Vertical Section (ft) Azim = 152.38°, Scale = 1 (in):600(ft) Origin = 69.49 Nt-S. 0.28 EJ-W TVD Ref: KB (81.43 ft aboYe MSL) SrvyDate: October13,2003 o 750 1500 2250 3000 3750 4500 WELL . . Schlumberger FiElD Prudhoe Bay Unit - WOA STRUCTURE W-PAD Magnetic Parameters Modal: BGGM2003 W-400 (Slot 41) (P8) -400 Dip' 80.806' Mag Dec' +25.298' Surface Location Lat· N70 17 46.949 Loo W149541.162 TVD Ref: KB (81.43 ft above MSl) SrvyData: October13,2003 NAD27 Alaska State Planes, Zone 04, US Feet Nortliiog: 5958792.00 flUS Grid Conv: +0.85223889' Easting: 611789.00 /tUS Scale Fact: 0.9999141961 Misœllaoeous Slot: W-400(SIot41) Plan: W-400(P8) Date October 20. 2003 FS: 57554.3 nT o 800 1200 400 o -2000 o :N -.(~. ~nl...................................,,,,.,,,.' ,,, J -400 -800 -800 ^ ^ ^ z E' 0 0 ~ ê = ~ II C1> (ij -1200 -1200 () en en V V V -1600 -2000 -1600 W-400 (P8) o 400 800 <<< W Scale = 1(in):300(ft) E »> 1200 . BPX AK Anticollision Report . C",npany; BP Amoco Date; 10/13/2003 Time:.. .10:55:25 Page: 1 Field: Prudhoe Bay Reference Site; PB W Pad Co-ordinate(NE) Refer!!nce: Welt Plan W-400(slot 41). TrÙeNorth Reference Well: PlanW-400 (slot41) Vertical (TVD) Reference: W-400 Plans4181.4 ReferenceWeIIPa(h: Plan W-400 Db;. . . Sybase NO GLOBAL SCAN; Using user defined selection & scan criteria Reference; Principal Plan & PLANNED PROGRAM Interpolation Method; MD Interval; 50.00 ft Error Model; ISCWSA Ellipse Depth Range: 28.00 to 5291.75 ft Scan Method; Trav Cylinder North Maximum Radius: 10000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Well path Date: 10/13/2003 Validated; No Version; Planned From To Survey TooIcode Tool Name ft ft 28.00 5210.32 Planned: Plan #8 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points Diameter Hole Size Name in in 3022.94 2656.43 13.375 16.000 133/8" 5210.32 4306.43 9.625 12.250 9 5/8" Summary Offset Wellpath > Reference Offset Ctr-Ctr No-Go Allowable Well Wellpath MD MD Distance Area Deviation Warning ft ft ft PB W Pad W-01 Plan#3 W-01A VO Plan: 812.04 800.00 400.21 17.38 382.83 Pass: Major Risk PB W Pad W-01 W-01 V3 812.04 800.00 400.21 17.21 383.00 Pass: Major Risk PB W Pad W-02 W-02 V4 1814.36 1900.03 194.56 30.63 163.94 Pass: Major Risk PB W Pad W-02 W-02A V20 1815.35 1900.00 194.60 30.66 163.94 Pass: Major Risk PB W Pad W-03 W-03 V4 1345.64 1350.00 325.44 22.51 302.93 Pass: Major Risk PB W Pad W-03 W-03A V1 1345.64 1350.00 325.44 22.51 302.93 Pass: Major Risk PB W Pad W-04 W-04 V1 1388.25 1400.00 302.25 22.44 279.81 Pass: Major Risk PB W Pad W-05 Plan W-05A (Rotary) VO 1160.42 1150.00 300.59 23.35 277 .24 Pass: Major Risk PB W Pad W-05 Plan#2 W-05L 1 VO Plan: 1152.61 1150.00 300.34 23.41 276.93 Pass: Major Risk PB W Pad W-05 W-05 V3 1152.61 1150.00 300.34 23.41 276.93 Pass: Major Risk PB W Pad W-06A W-06A V2 1313.54 1300.00 252.74 24.42 228.32 Pass: Major Risk PB W Pad W-06 W-06 V1 1313.54 1300.00 252.74 24.42 228.32 Pass: Major Risk PB W Pad W-07 W-07 V1 1002.13 1000.00 288.96 24.19 264.77 Pass: Major Risk PB W Pad W-08 W-08 V1 1407.07 1400.00 234.46 26.22 208.24 Pass: Major Risk PB W Pad W-08 W-08A V11 1362.81 1350.00 233.42 24.90 208.52 Pass: Major Risk PB W Pad W-09 W-09 V1 1453.02 1450.00 179.86 33.69 146.18 Pass: Major Risk PB W Pad W-10 W-10 V3 2232.72 2150.00 170.06 53.91 116.15 Pass: Major Risk PB W Pad W-10 W-10A V4 2232.72 2150.00 170.06 53.91 116.15 Pass: Major Risk PB W Pad W-11 W-11 V1 1616.91 1600.00 176.90 34.63 142.28 Pass: Major Risk PB W Pad W-12A W-12A V3 2803.28 2600.00 204.77 70.31 134.46 Pass: Major Risk PB W Pad W-12 W-12 V1 2803.28 2600.00 204.77 70.31 134.46 Pass: Major Risk PB W Pad W-15 W-15 V1 1232.25 1250.00 668.38 18.16 650.23 Pass: Major Risk PB W Pad W-15 W-15A V10 1232.25 1250.00 668.38 18.16 650.23 Pass: Major Risk PB W Pad W-15 W-15PB1 V6 1232.25 1250.00 668.38 18.16 650.23 Pass: Major Risk PB W Pad W-15 W-15PB2 V1 1232.25 1250.00 668.38 18.16 650.23 Pass: Major Risk PB W Pad W-16 W-16 V3 1192.29 1199.90 702.36 18.17 684.19 Pass: Major Risk PB W Pad W-16 W-16L 1 V3 1192.29 1199.90 702.36 18.17 684.19 Pass: Major Risk PB W Pad W-17 W-17 V1 1200.00 1200.00 731.50 20.24 711.26 Pass: Major Risk PB W Pad W-18 W-18 V1 1200.00 1200.00 765.17 21.71 743.46 Pass: Major Risk PB W Pad W-19 Plan#11 W-19AL 1 V1 Pia 1200.00 1200.00 799.12 19.22 779.90 Pass: Major Risk PB W Pad W-19 W-19 V2 1228.28 1250.00 799.43 19.42 780.01 Pass: Major Risk PB W Pad W-19 W-19A V1 1200.00 1200.00 799.12 19.05 780.07 Pass: Major Risk PB W Pad W-200PB1 W-200PB 1 V7 1152.94 1150.00 1010.35 19.00 991.36 Pass: Major Risk PB W Pad W-200 W-200 V6 1152.95 1150.00 1010.36 18.92 991.44 Pass: Major Risk PB W Pad W-201 W-201 V4 964.63 950.00 1047.66 15.08 1032.58 Pass: Major Risk PB W Pad W-203 W-203 V9 657.57 650.00 295.40 9.71 285.69 Pass: Major Risk PB W Pad W-203 W-203L 1 V7 657.57 650.00 295.40 9.49 285.90 Pass: Major Risk PB W Pad W-203 W-203L2 V3 657.57 650.00 295.40 9.49 285.90 Pass: Major Risk PB W Pad W-205 Plan W-205LOBa V1 Plan 350.53 350.00 283.35 6.66 276.69 Pass: Major Risk PB W Pad W-205 Plan W-205LOBc V1 Plan 350.53 350.00 283.35 6.66 276.69 Pass: Major Risk PB W Pad W-205 W-205 OBd V6 250.53 250.00 283.51 4.50 279.00 Pass: Major Risk PB W Pad W-207 W-207 V10 813.63 800.00 530.58 13.84 516.75 Pass: Major Risk PB W Pad W-207 W-207PB1 V2 813.63 800.00 530.58 13.84 516.75 Pass: Major Risk PB W Pad W-209 W-209 V5 Plan: Plan #8 201.33 200.00 427.48 3.82 423.66 Pass: Major Risk . BPX AK . Anticollision Report 9¡mpany; BP Amoco Field; Prudhoe Bay Reference Site; PBWPad Reference Well; Plan W-400 (slot 41) Reference Wellpatþ; Plan W-400 Summary <------------- Offset WeUpatb > Reference Offset Ctr-Ctr No-Go Allowable Site Well Wellpatb MD MD Distance Area Deviation Warning ft ft ft ft ft PB W Pad W-209 W-209PB1 V5 201.33 200.00 427.48 3.56 423.92 Pass: Major Risk PB W Pad W-20 W-20 V1 1233.54 1250.00 834.32 20.36 813.96 Pass: Major Risk PB W Pad W-211 W-211 V8 1532.26 1650.00 518.81 33.75 485.06 Pass: Major Risk PB W Pad W-212 W-212 V12 1153.98 1150.00 616.72 17.59 599.13 Pass: Major Risk PB W Pad W-215 W-215 V7 250.62 250.00 563.65 4.39 559.26 Pass: Major Risk PB W Pad W-215 W-215PB1 V2 250.62 250.00 563.65 4.39 559.26 Pass: Major Risk PB W Pad W-21 W-21 V3 804.57 800.00 877.02 18.73 858.29 Pass: Major Risk PB W Pad W-21 W-21A V12 813.87 800.00 877.26 18.97 858.29 Pass: Major Risk PB W Pad W-22 W-22 V1 1231.22 1250.00 896.07 20.76 875.31 Pass: Major Risk PB W Pad W-23 W-23 V3 1187.98 1200.00 936.96 18.72 918.23 Pass: Major Risk PB W Pad W-23 W-23A V5 1200.00 1200.00 937.07 18.91 918.16 Pass: Major Risk PB W Pad W-24 W-24 V1 1200.00 1200.00 975.47 22.06 953.41 Pass: Major Risk PB W Pad W-25 W-25 V1 1135.72 1150.00 480.43 18.19 462.24 Pass: Major Risk PB W Pad W-26A W-26A V6 1098.03 1100.00 512.15 20.50 491.65 Pass: Major Risk PB W Pad W-26 W-26 V1 1098.03 1100.00 512.15 20.50 491.65 Pass: Major Risk PB W Pad W-27 W-27 V1 1179.45 1200.00 548.44 19.48 528.96 Pass: Major Risk PB W Pad W-29 W-29 V1 1134.19 1150.00 623.08 21.69 601.39 Pass: Major Risk PB W Pad W-30 W-30 V1 1178.19 1200.00 655.86 20.34 635.52 Pass: Major Risk PB W Pad W-31 W-31 V1 1177.55 1200.00 686.82 19.03 667.79 Pass: Major Risk PB W Pad W-32 W-32 V5 1134.09 1150.00 725.59 17.78 707.81 Pass: Major Risk PB W Pad W-32 W-32A PB1 V12 1136.47 1150.00 725.63 17.40 708.23 Pass: Major Risk PB W Pad W-32 W-32A V3 1136.47 1150.00 725.63 17.81 707.82 Pass: Major Risk PB W Pad W-34 W-34 V1 1137.37 1150.00 248.07 19.39 228.68 Pass: Major Risk PB W Pad W-34 W-34A V1 1137.37 1150.00 248.07 19.39 228.68 Pass: Major Risk PB W Pad W-34 W-34APB1 V1 1137.37 1150.00 248.07 19.39 228.68 Pass: Major Risk PB W Pad W-35 W-35 V1 1089.75 1100.00 215.09 19.70 195.39 Pass: Major Risk PB W Pad W-36 W-36 V1 1137.79 1150.00 175.06 18.58 156.49 Pass: Major Risk PB W Pad W-37 W-37 V3 1039.71 1050.00 140.72 18.90 121.82 Pass: Major Risk PB W Pad W-37 W-37 A V3 1039.71 1050.00 140.72 18.90 121.82 Pass: Major Risk PB W Pad W-38 W-38 V2 1034.07 1050.00 72.90 22.76 50.14 Pass: Major Risk PB W Pad W-38 W-38A V1 0 1036.64 1050.00 72.97 22.57 50.40 Pass: Major Risk PB W Pad W-39 Plan#4 W-39A VO Plan: 1138.66 1150.00 73.20 23.48 49.72 Pass: Major Risk PB W Pad W-39 W-39 V1 1138.66 1150.00 73.20 23.48 49.72 Pass: Major Risk PB W Pad W-40 W-40 V1 688.83 700.00 36.08 12.19 23.89 Pass: Major Risk PB W Pad W-42 W-42 V1 648.37 650.00 37.23 10.86 26.37 Pass: Major Risk PB W Pad W-44 W-44 V1 1597.96 1600.00 91.59 24.59 67.00 Pass: Major Risk Field: Prudhoe Bay Site: PB W Pad Well: Plan W-400 (slot 41) Wellpath: Plan W-400 100 . -294 . ·····200 100 -0 270 90 . 200 -294 Travelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [lOOft/in] Polygon I 2 3 4 Site: PB W Pad . Drilling Target Conf.: 99 Description: Map Northing: 5957167.00 ft Map Easting : 612662.00 ft Latitude: 70017'30.840N Xft 40.21 426.36 132.52 -305.34 Target: W-400 Tgt .11: Plan W-400,Plan W-400 (slot 41) sed on: Planned Program Vertical Depth: 3383.00 ft below Mean Sea Level Local +N/-S: -1637,95 ft Local +E/-W: 848.81 ft Longitude: 149°05'16.426W Map E ft 612698.00 613096.00 612805.00 612355.00 Map N ft 5957450.00 5956654.00 5956463.00 5957278.00 / yft 282.46 -519.44 -706,11 115.56 -800 -1000 -1200 -14-00 -1500 -1800 -2000 -2200 -24-00 / -2500 0 CJ CJ CJ CJ CJ CJ CJ CJ o 0 CJ CJ CJ CJ CJ CJ CJ CJ o ~ -3- LD CD CJ N -3- LD CD Q ~ ~ J " . Tree: CIW 7" 5M Wellhead: FMG BB Wellhead 20" 91.1 ppf, H-40 I 100' I- 133/8",67 ppf, L-80 Btrc. prod. csg L 95/8", 47 ppf, L-80 Btrc. prod. csg O' I DATE REV. BY W-400 - COMMENTS Proposed diaqram(P8) 10/13/03 nm . Orig. OF elev. = xxx' Orig. GL elev. = xxx' Ii "Suspension String" 5.5",15.5 # / ft., J-55 Mod BU. 4.950" ~ I 2200' W-Pad Well W-400 WSW API NO: 50-xxx-xxxxx . . W-400 Well Summary of Drillina Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section: · Gas hydrates may be encountered near the base of the Permafrost at 2080' MD and near the TO hole section as well. · Gravel bedsl"boulders" encountered at 1100-1300' in offset wells proved problematic. · Sidetracking occurred on two of these wells while making bit trips. · There are two close approach issues in the surface hole. W-44 approaches with a center to center distance of 30' at 891' and W-42 approaches within 34' at 600'. · Hole cleaning will be critical in this 16" surface hole section. Optimize rotation/RaP/Flow Rate to ensure adequate hole cleaning. Production Hole Section: · This well is expected to have a kick tolerance in the 100 bbl range. Even so a heightened awareness of kick detection, pre-job planning and trip tank calibration will be essential while drilling/tripping in this hole section. · The intermediate hole section will be drilled with a recommended mud weight of 9.5 ppg to cover the Ugnu 8.9 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. · There are no close approach issues in this hole section. · Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE W-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies e e Per Alaska Oil and Gas Conservation Commission Regulation 20 AAC 25.015 Changes to a Program in a Permit to Drill sub section (a) (]) submit and obtain the commission's approval of a new application for a Permit to Drill if the surface location is changed, if the bottom-hole location or the location of an objective formation is changed by more than 500 feet laterally or vertically, or if the change requires a spacing exception under 20 AAC 25.055; however, no additional fee is required . lR\ In, o u FRANK H. MURKOWSKI, GOVERNOR (ill Æ\ u tJ ~~fÆ . A'~ASK& OIL AND GAS CONSERVATION COMMISSION 333 W. -r" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, Alaska 99519 Re: Prudhoe bay Unit PBU W -400 BP Exploration (Alaska), Inc. Pennit No: 203-165 Surface Location: 3749' NSL, 1455' WEL, Sec. 21, TIIN, RI2E, UM Bottomhole Location: 1718' NSL, 360' WEL, Sec. 21, TIIN, RI2E, UM Dear Mr. Isaacson: Enclosed is the approved application for pennit to drill the above service well. This penn it to drill does not exempt you from obtaining additional pennits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the pennit in the event it was erroneously issued. You are planning to use this well as a water source to flood the fresh water sensitive Ivishak fonnation of the Prudhoe Oil Pool. As you know it is essential that the injected fluids be compatible. Therefore, it is a condition of this pennit to drill that BP Exploration (Alaska), Inc. collect and test a water sample from the Ugnu Fonnation and provide results to the Commission that show that it is compatible with the reservoir, prior to using the water in the waterflood. 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 tenns and conditions of this pennit may result in the revocation or suspension of the pennit. 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 659-3607 (pager). ~~~ R~d; ¿edrich Commissioner BY ORDER OF THE COMMISSION DATED this 3~ day of September, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section \¡Jc,A- ~ltl/z.oo~ 181 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: 3749' NSL, 1455' WEL, SEC. 21, T11N, R12E, UM Top of Productive Horizon: 2181' NSL, 609' WEL, SEC. 21, T11 1'4, R12E, UM Total Depth: 1718' NSL, 360' WEL, SEC. 21, T11 1'4, R12E, UM . STATE OF ALASKA . ALASKA AND GAS CONSERVATION CO.SSION PERMIT TO DRILL 20 AAC 25.005 11 b. Current Well Class b!',EXplOratory o Stratigraphic Tes 181 .ßérvice 5. Bond: !HI Blanket Ingle Well Bond No. 2S 100302630-277 6. Proposed Depth: MD 5029' TVD 4306' 7. Property Designation: ADL 028263 o Development Oil 0 Multiple Zone o Development Gas 0 Single Zone 11. Well Name and Number: PBU W-400 ./ 12. Field I Pool(s): Prudhoe Bay Field 1 Ugnu 8. Land Use Permit: 13. Approximate Spud Date: November 1, 2003 14. Distance to Nearest Property: 13200' ,,;' 9. Acres in Property: 2560 4b. Location of Well (State Base Plane Coordinates): Surface: X-611790 y-5958723 Zone-ASP4 16. Deviated Wells: Kickoff Depth .18. Cåsing Program Size Casinç¡ 20" 13-3/8" 9-518" Hole 42" 16" Weiç¡ht 91.5# 68# 47# Grade H-40 L-80 L-80 Couplinç¡ Weld BTC BTC Lenç¡th 80' 3685' 5029' 10. KB Elevation Plan RKB 15. Distance to Nearest Well Within Pool (Height above GL): = 81.3' feet W-06 is 1360' away at 3397' /' 17. Anticipated pressure (see 20 MC 25.035) ./ Max. Downhole Pressure: 1966 psig. Max. Surface Pressure: 1551 psig Setting D~pthii '. >. .. Qu¡;¡nti~pfcement Top/BOttom (c. f-ofsacks) MD TVD MD TVD (includinç¡ staç¡e data) Surface Surface 110' 110' 260 sx Arctic Set (Approx.) Surface Surface 3685' 3175' 767 sx Articset Lite, 408 sx 'G' Surface Surface 5029' 4306' 470 sx Class 'G' 400 ft Maximum Hole Angle 39° 12-1/4" PRE$J:NTWELL CONDITION SUMMARY (To be e<>mpløteqJorRedrill AND Re-entry Operations) Total Depth MD (ft): Total Depth TVD (ft): Plugs (measured): Effective Depth MD (ft): Depth TVD (ft):1 Junk (measured): Structural Conductor Surface Intermediate Production Liner 20. Attachments !HI Filing Fee 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): !HI Drilling Program 0 Time vs Depth Plot o Seabed Report !HI Drilling Fluid Program o Shallow Hazard Analysis !HI 20 MC 25.050 Requirements Date: Contact Neil Magee, 564-5119 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 Title Senior Drilling Engineer 1 ''- Prepared By Name/Number: Terrie Hubble, 564-4628 Permit To Drill API Number: Permit AJ2P~ail See cover letter for Number: 20:.3 -/6 S 50- ð 2- 9 - :z -3 / g- ð Date: '1.1 3 PO) other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log equir d 0 Yes IZI No Hydrogen Sulfide Measures 0 Yes IZJ No Directional Survey Required ~ Yes No Other: Test- þOPE '~ ~S'oo p a ~"",-i ""\.IA.IM.. M.1: T J ~VIA.~f- ß/(ß.{¡P¡ l~, Y'lþ"UNJ.. Approved By: Form 10-401 Revised 3/200 ~¿;l_j~ COMMISSIONER BY ORDER OF THE COMMISSION Date 7jJið3 Submit In Duplicate bp e e To: Winton Aubert - AOGCC Date: September 19, 2003 From: Neil Magee - BPXA GPB Drilling & Wells Subject: W-400 Permit to Drill Application Dear Mr. Aubert, / Attached is the Permit to Drill Application for W-400 water source well. This well is a proposed water source well producing from the Ugnu 4A and Ugnu 3 sands of the Prince Creek formation. This well will provide up to 20,000 bwpd to the W Pad gas cap water injectors W-40, W-42 and W-44. The increased ,/ injection will facilitate voidage replacement and allow continued production drilling in the West End of Prudhoe. Plans are to drill and case W -400 with one of the rotary rigs; Nabors 9ES, 7ES or Doyon 141. After the long lead completion equipment arrives, the well will be gravel packed and completed with an ESP pump by Nabors 4ES. The completion operations are expected to take place near year end 2003. Enclosed is a Permit to Drill Application. The completion details will be forwarded at a later date, once plans have been finalized. If you have any questions or require any additional information, please contact me at 564-5119. Scope Summary of Drillinq Operations: 1. MIRU rotary drilling Rig /" 2. Nipple up diverter spool and riser. PU 5" DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/LWD (page 5) and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiper/bit trip to surface for a bit will be performeo/' prior to exiting the Permafrost. 4. Run and cement the 13-3/8", 68# surface casing back to surface. A Tam port collar may be run as a contingency if surface drilling is problematic. 5. ND riser spool and NU casing / tubing head. NU BOPE and test to 4000 psi. / 6. MU 12-1/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. Test the 13-3/8" casing /' to 3500 psi for 30 minutes. / 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Leak Off Test. / 8. Drill to +/- 4255' TVDss. (Below the base of the UG3.) Condition hole for e-line logging. 9. Run Pex/Sonic from TD to surface casing shoe. Review log to determine cement volume required for production string cementing. /' 10. Run and cement the 9-5/8", 47# production casing. Test casing to 3500 psi. 11. Freeze protect the 13-3/8" x 9-5/8" annulus to 2200' TVDss. Record formation breakdown pressure on the Morning Report. 12. RIH with casing scraper and POOH laying down drill pipe. (Contingency) 13. Run a 5-1/2",15.5#, Butt, L-80 kill string assembly to 2200'. 14. Install TWC and nipple down the BOPE. Nipple up tree adapter on top of wellhead with 7-1/16" valve on top. Remove TWC. W-400 Permit to Drill Application e e 15. RU hot oil truck and freeze protect well by reversing in diesel to freeze protect well from 2200' to /' surface. Allow to equalize. down and move off. Completion Operations 1. MIRU Nabors 4ES 2. Nipple up and test BOP's. 3. Circulate out diesel freeze protect and recover kill string. / 4. Perforate and gravel pack approximately 300' of the Ugn~ ~, and gnu 3 intervals 5. Complete well with a 5-1/2" completion string and 800 he.~S!. 6. ND and install surface tree and ESP feed throughs. ~ -, 7. Rig down and move off. /' W-400 Permit to Drill Application e e IWell Name: IW-400 Drilling Plan Summary I Type of Well (service I producer I injector): 1 Service (Water Source Well) Surface Location: As-Built (Slot 43) Target Location: Bottom Hole Location: x = 611,789.50' Y = 5,958,722.50' 3749' FSL, 1455' FEL, Sec. 21, T11N, R12E / X = 612,662.00' Y = 5,957,167.00' 2181'FSL,609'FEL,Sec.21,T11N,R12E ~ X = 612,919.00' Y = 5,956,708.00' 1718'FSL,360'FEL,Sec.21, T11N, R12E ~ Top of proposed water source interval in W-400 is 1360' ft away from W-06 the nearest wellbore. The well approaches within 13,200' ft of the nearest Prudhoe Bay property line. /' I AFE Number: I??????? I Estimated Start Date: 111/1/2003 1 I MD: 15029' 1 / I TVD: 14306' 1 I Rig: 1 To be determined / I Operating days to drill: I RT/GL: 128.5' I I RKB: 181.3' I Well Design (conventional, slim hole, etc.): 12 String Water Producer I Objective: 1 Water source well in Ugnu reservoir CasingITubing Program: Hole Csgl WtlFt Gra~ Conn Size Tbg O.D. / 42" Insulated 20" 91.5# H-40 WLD 16" 13-3/8" 68# L-80 BTC 12 W' 95/8" 47# L-80 BTC Tubing 5 %" 17# L-80 IBT-M * 9-5/8" 47# Burst 6,870 psi, collapse 4,750 psi ** 13-3/8" 68# Burst 5,020 psi, collapse 2,260 psi Length 80' 3685' 5029' TBD Top MDITVD GL GL GL GL Btm MDITVD bkb 110/110 3685'/3175' 5029'/4306' TBD W-400 Drilling Program- Draft Page 1 · e Mud Program: 16" Surface Hole (0-3685'): Initial Base PF to top SV SV toTO Densitv (ppg) 8.5- 9.2 ~'19.5 ~ax Viscosity (seconds) 250-300 200-200 150-200 Fresh Water Surface Hole Mud Yield Point API FL PH (lb/100ff) (mis/30m in) 45 - 70 NC 35-45 <8 25 - 35 < 8 9.0- 9.5 9.0- 9.5 9.0- 9.5 12-1/4" Production Hole (3685' - 5029'): Interval Density YP PV (PPfJTI tJ/ pH LSND API Filtrate 4-6 ToTO 30 10 9.0-9.5 Hydraulics: Surface Hole: 16" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 0-2015' 775 5" 19.5# 50 1800 9.2 N/A 3X18,20 1.052 2015'-3685' 850 5" 19.5# 50 2200 9.5 N/A 3X18,20 1.052 Production Hole: 12-1/4" Interval Pump Drill AV Pump PSI ECD Motor Jet Nozzles TFA GPM Pipe (fpm) ppg-emw ("/32) (in2) 3685' - 5029' 800 5" 19.5# 91 2400 11.1 N/A 2x18,16,24 1.135 Hole Cleaning Criteria: Interval ROP Drill Pump Mud Hole Cleaning Condition Pipe GPM Weight Rotation Surface to SV-1 280 80 850 9.5 Acceptable 340 80 850 9.5 Marginal-Poor 300 100 850 9.5 Acceptable 350 100 850 9.5 Marginal-Poor 12-1/4" to Sweeps and fully reamed connections to maintain Top WS minimum hole cleaning requirements 280 80 800 9,5 Acceptable 340 80 800 9.5 Marginal-Poor 300 100 800 9.5 Marginal W-400 Drilling Program- Draft Page 2 Directional: Ver. I Anadrill(P4)(Slot 43) KOP: 400' Maximum Hole Angle: Close Approach Wells: Logging Program: Surface Production Hole It e 39 deg at 1862' MD All wells pass 1/200 minor risk criteria. W-44 - 30' @ 891' W-42 - 34' @ 600' IFR-MS corrected surveys will be used for survey validation. Drilling: Open Hole: Cased Hole: Drilling: Open Hole: Cased Hole: Formation Markers: Formation Tops Base Permafrost SV5 SV4 SV3 SV2 SV1 UG4A UG3 UG1 WS1 TD Criteria TVDss 1800 1850 1972 2483 2680 2994 3397 3654 4156 4600 Integrity Testing: Test Point Depth Surface Casing Shoe 20' min from surface shoe W-400 Drilling Program- Draft MWD 1 GR None None MWD/GR/RES/(Real Time) PexlSonic USIT (done after rig release) Estimated pore pressure, PPG water bearing water bearing water bearing water bearing water bearing water bearing, 9.1 ppg EMW (1966 psi) water bearing, Dril! below base of UG3 (4225' TVDss) q.s- Test Type LOT EMW 10.5 ppg EMW Target ;'" Page 3 e e Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as a contingency if cement is not circulated to surface. Casing Size 113-3/8" Surface I Basis: Lead: Based on conductor set at 110', 1905' of annulus in the permafrost @ 250% excess and 917' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface Tail: Based on 750' MD(>500'TVD) open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2935' MD .LJ I Total Cement Volume: Lead 609 bb~1 , e ~~KS of Dowell ARTICSET Lite at 10.7 ppg an .4 f/~ Tail ~I ~ft.j l&-sks of Dowell Premium 'G' at 15.8 ppg and ~f/sk. The production casing will be cemented bringing cement up to the surface casing shoe. Actual volumes will be based on e-line log interpretation. Casing Size I 9-5/8" Production Longstring I Basis: I Based on cement from TD to surface casing shoe + 3~excess + 80' shoe Total Cement Volume: I I~" Is 1 545 ft;;! l~kS of Dowell G at 15.8 ppg and C7f/Sk W-400 Drilling Program- Draft Page 4 e e Well Control: Surface hole will be drilled with a diverter. The intermediate/production hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon the planned casing test of 3500 psi for casing integrity considerations, the BOP equipment will be tested to 4000 psi. /' Oiverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- · Maximum anticipated BHP: 19~.9"~i @ 4156' TVOss - Ugnu · Maximum surface pressure: ÃŠ51--6si @ surface ~d- on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: · Planned completion fluid: 4000 psi (The casing will be tested to 3500) ../ 9.3 ppg filtered brine / 6.8 ppg diesel Disposal: · No annular disposal in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at OS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to OS- 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. W-400 Drilling Program- Draft Page 5 e e DRILLING PROCEDURE SUMMARY Pre-Rig Work: The 20" insulated conductor is scheduled for installation in September 2003. 1. Weld an FMC landing ring for the FMC BB wellhead on the 20" conductor. Install two 4" outlets on the conductor pipe for surface cementing operations. 2. If necessary, level the pad and prepare location for rig move. Rig Operations: 1. MIRU Nabors 9ES. 2. Nipple up diverter spool and riser. PU 5" DP as required and stand back in derrick. 3. MU 16" drilling assembly with MWD/LWD (page 5) and directionally drill surface hole to approximately 100' TVD below the SV1 Sands. An intermediate wiperlbit trip to surface for a bit will be performed prior to exiting the Permafrost. 4. Run and cement the 13-318", 68# surface casing back to surface. A Tam port collar may be run as a contingency if surface drilling is problematic. 5. ND riser spool and NU casing I tubing head. NU BOPE and test to 4000 psi. 6. MU 12-1/4" drilling assembly with MWD/LWD (page 5) and RIH to float collar. Test the 13-3/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to 9.5 ppg drilling fluid. Drill new formation to 20' below 13-3/8" shoe and perform Leak Off Test. 8. Drill to +1- 4255' TVDss. (Below the base of the UG3.) Condition hole for e-line logging. 9. Run Pex/Sonic from TD to surface casing shoe. Review log to determine cement volume required for production string cementing. 10. Run and cement the 9-5/8", 47# production casing. Test casing to 3500 psi. 11. Freeze protect the 13-3/8" x 9-518" annulus to 2200' TVDss. Record formation breakdown pressure on the Morning Report. 12. RIH with casing scraper and POOH laying down drill pipe. (Contingency) 13. Run a 5-1/2", 15.5#, Butt, L -80 kill string assembly to 2200'. 14. Install TWC and nipple down the BOPE. Nipple up tree adapter on top of wellhead with 7-1/16" valve on top. Remove TWC. 15. RU hot oil truck and freeze protect well by reversing in diesel to freeze protect well from 2200' to surface. Allow to equalize. down and move off. W-400 Drilling Program- Draft Page 6 e e W-400 Drilling Programme Job 1: MIRU Hazards and Contingencies þ> W-Pad is not designated as an H2S site. None of the current producers on V-Pad have indicated the presence of H2S. As a precaution however Standard Operating Procedures for H2S precautions should be followed at all times. þ> The cellar area surrounding W-400 should be checked to insure level prior to move in. þ> Check the landing ring height on the W-400 conductor prior to move-in. The BOP nipple up may need review for space out. Reference RPs .:. "Drilling! Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drillinq Surface Hole ).- There are two close approach issues in the surface hole. W-44 approaches with a center to center distance of 30' at 891' and W -42 approaches within 34' at 600' ).- Hydrates/gas cut mud have been observed in wells drilled on W-Pad. These were encountered near the top of the SV- sands. In addition wood and "boulders" have been encountered at approximately 1000' in offset wells. Reference RPs .:. "Prudhoe Bay Directional Guidelines" .:. "Well Control Operations Station Bill" .:. Follow Schlumberger logging practices and recommendations (during gyro use) --..~",,""- .,.."",..." _.~ ~_"(mw.~.J;;; ~--- Job 3: Install Surface Casinq Hazards and Contingencies ).- It is critical that cement is circulated to surface for well integrity. 250% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. A 9-5/8" port collar will be available as a contingency if surface hole drilling is problematic. If used the port collar will be positioned at ±1 OOO'MD to allow remedial cementing. Reference RPs .:. "Casing and Liner Running Procedure" .:. "Surface Casing and Cementing Guidelines" .:. "Surface Casing Port Collar Procedure" W-400 Drilling Program- Draft Page 7 e e Job 7: Drillinq Production Hole Hazards and Contingencies ~ W-400 is not expected to cross any faults in the production hole section. There are two regional faults near the UG3 formation however the W-400 directional plan stays well to the south east. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices accordingly. ~ KICK TOLERANCE: In the case scenario of 9.2 ppg pore pressure at the Ugnu target depth, gauge hole, a fracture gradient of 1 Þ at the surface casing shoe, 9.5 ppg mud in the hole the kick tolerance is approximate 150 Is. An accurate LOT will be required as well as heightened awareness for kick d on. Contact Drilling Manager if LOT is less than 10.5 ppg. ~ There are no "close approach" issues with the production hole interval of W-400. Reference RPs .:. Standard Operating Procedure for Leak-off and Formation Integrity Tests .:. Prudhoe Bay Directional Guidelines .:. Lubricants for Torque and Drag Management. .:. ERD Recommended Practice Section 5.2 " Operating Practices" ,~..".,.~.~~~~..,'- ~,~-.",-",..~,< Job 8: Loq Production Hole Hazards and Contingencies ~ Differential sticking is a concern. Keep tools moving at all times and monitor line tension. OperaüonalSpecifics · Run Pex/Sonic from TD to surface casing shoe. Collect data for determining open hole volume for upcoming production hole cement job. Job 9: Case & Cement Production Hole Hazards and Contingencies ~ The interval is planned to be cemented with a single 15.8 ppg slurry. The slurry will cover from production hole TD to the surface casing shoe. Review e-line logs to help determine cementing volume as accurately as possible such that the production hole is cemented just up to the surface casing shoe. ~ Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. Pump approximately Y2 volume of casing-casing annulus prior to freeze protecting. After freeze protecting the 13-3/8" x 9-5/8" casing outer annulus with dead crude (2200' TVD), the hydrostatic pressure will be 7.5 ppg vs 9.1 ppg EMW of the formation pressure immediately below the shoe (worst case). Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 250 psi underbalance to the open hole. W-400 Drilling Program- Draft Page 8 e e ~ A LCM pill composed of "G Seal" may be placed across the production interval to help arrest mud dehydration if losses were experienced while drilling this interval. Reference RPs .:. "Intermediate Casing and Cementing Guidelines" .:. "Freeze Protecting an Outer Annulus" Job 12: Run Kill Strinq Hazards and Contingencies ~ Watch hole fill closely, verify no light fluids are introduced down hole and verify proper safety valves are on the rig floor while running the kill string. Reference RPs .:. Completion Design and Running .:. Freeze Protection of Inner Annulus Job 13: ND/NUlRelease Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs .:. Freeze Protection of Inner Annulus W-400 Drilling Program- Draft Page 9 e e W-400 Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Surface Hole Section; · Gas hydrates may be encountered near the base of the Permafrost at 1800' MD and near the TD hole section as well. · Gravel beds/"boulders" encountered at 1100-1300' in offset wells proved problematic. · Sidetracking occurred on two of these wells while making bit trips. · There are two close approach issues in the surface hole. W-44 approaches with a center to center distance of 30' at 891' and W-42 approaches within 34' at 600'. · Hole cleaning will be critical in this 16" surface hole section. Optimize rotation/RaP/Flow Rate to ensure adequate hole cleaning. Production Hole Section: · This well is expected to have a kick tolerance in th~1 range. Even so a heightened awareness of kick detection, pre-job planning and ~hk calibration will be essential while drilling/tripping in this hole section. · The intermediate hole section will be drilled with a recommended mud weight of 9.5 ppg to cover the Ugnu 9.1 ppg pore pressure. · Tight hole, hole packing-off, and lost returns have been encountered in previous wells on this pad. Back reaming at connections and good hole cleaning practices will contribute to favorable hole conditions. . There are no close approach issues in this hole section. · Lost circulation is considered a minimum risk however losses have been encountered due to "breathing" in previous wellbores. Loss circulation is considered to be a minor risk. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. / HYDROGEN SULFIDE - H2S · This drill-site not designated as an H2S drill site. Recent wells test do not indicate the presence of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE W-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION Version 1.0 Rigsite Hazards and Contingencies e Tree: CIW 7" 5M Wellhead: FMC SS Wellhead 20" 91.1 ppf, H-40 I 110' ,- 13 3/8", 67 ppf, L-80 Strc. prod. csg L I 3685' I 95/8", 47 ppf, L-80 Strc. prod. csg 15029" I DATE REV. BY W-400 - COMMENTS Proposed diagram(P4) 09/15/03 nm e Orig. OF elev. = xxx' Orig. GL elev. = xxx' Ii "Suspension String" 5.5", 15.5 # / ft., L-80 Mod Btrc. 4.950" I 2200' ~ ,/ / W-Pad Well W-400 WSW API NO: 50-xxx-xxxxx e Tree: CIW 7" 5M Wellhead: 20" 91.1 ppf, H-40 I 110' I· 13-3/8" 67 ppf, L-80 I 3685' I L 5.5", 17 # / ft., L-80 Mod Btrc. 4.767" 4.892" 10, .0233 bpi 9 5/8", 40 ppf, L-80 Btrc. prod. csg Gravel Pack Summary: Upper zone - xx/xx/xx- Est.. XX,xxx Ibs. of 20-40 Carbolite Lower zone - xx/xx/xx - Est.. XX,xxx Ibs. of 20-40 Carbolite. Minimum gravel pack restriction = x.xx" safety shear sub @ xxxx' and xxxx'. Perforation Summary: Ref log: GRlCCL xxlxxlxx Size SPF Interval (TVO) W-400 ;,- ~ ~ ~ ~ ~ ~ ~ - ~ ~ ~ /. -,e " Orig. OF elev. = xxx' Orig. G L elev. = xxx' RDF To 9 518" landing ring = 29.2 NOTE: 5.5" Tubing wI one jt 7 inch at suñacE ~ Centrilift HC 19000 ESP, Model HPLT, HPMT XXXX Centrilift HST 3 EHL 675 seal section 1 XXXX' I Centrilift Series,HMI 800 hp. motor, 4160v. / I xxxx' I 114 amp Centrilift PumpMate I XXXX' I 95/8 pkr. / XXXX' ~~ 9 5/8" csg. shoe ~~~~~~lIar 5029' COMMENTS W-Pad Proposed diaQram Well W-400 WSW Draft Well Design API NO: 50-xxx-xxxxx DATE REV. BY 12/09/02 bws 09/5/03 nm KBE KOP Bid 1/100 Bid 211 00 Crv 3/100 End Bid Base Perm SV5 SV4 Report Date: Client: Field: Structure I Slot: Well: Borehole: UWUAPI#: Survey Name I Date: Tort I AHD I DDII ERD ratio: Grid Coordinate System: location lat/long: location Grid N/E Y/X: Grid Convergence Angle: Grid Scale Factor: Comments Measured Depth (ft) 0.00 400.00 500.00 600.00 700.00 Schlumbøpuøp W-400 (P4) Proposal September 17, 2003 Survey I DlS Computation Method: BP Exploration Alaska Vertical Section Azimuth: Prudhoe Bay Unit - WOA dy Vertical Section Origin: W-PAD/W-400 IIIllIIty Stu TVD Reference Datum: Plan W-400 1II11a I I TVD Reference Elevation: W-400 Fea." Sea Bed I Ground level Elevation: 50029 Magnetic Declination: W-400 (P4) I September 17, 2003 Total Field Strength: 48.105°/2315.6711/5.114/0.538 Magnetic Dip: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: N 70.29618493, W 149.09477141 Magnetic Declination Model: N 5958722.500 IIUS, E 611789.500 IIUS North Reference: ..0.85223381° Total Corr Mag North .> True North: 0.99991420 local Coordinates Referenced To: Inclination (deg) 0.00 0.00 1.00 3.00 5.03 7.72 10.57 13.49 16.44 19.40 22.37 25.35 28.34 31.32 34.31 37.30 39.18 39.18 39.18 39.18 Azimuth (deg) 90.00 90.00 90.00 90.00 123.11 135.40 141.24 144.59 146.77 148.29 149.43 150.31 151.01 151.60 152.09 152.51 152.74 152.74 152.74 152.74 Version DO 3.1RT (d031rC546) 3.1RT-SP3.03 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1600.00 1700.00 1800.00 1862.96 2015.93 2080.43 2237.83 TVD (ft) 0.00 400.00 499.99 599.93 699.69 799.07 897.79 995.58 1092.18 1187.32 1280.74 1372.18 1461.39 1548.13 1632.16 1713.26 1762.71 1881.27 1931.27 2053.27 Sub·Sea TVD (ft) -81.27 318.73 418.72 518.66 618.42 717.80 816.52 914.31 1010.91 1106.05 1199.47 1290.91 1380.12 1466.86 1550.89 1631.99 1681.44 1800.00 1850.00 1972.00 Vertical Section (ft) 0.00 0.00 0.42 2.08 7.18 17 .48 32.95 53.56 79.25 109.94 145.55 185.98 231.13 280.86 335.05 393.54 432.51 529. 13 569.88 669.30 NS (ft) 0.00 0.00 0.00 0.00 -2.39 -9.57 -21.50 -38.17 -59.52 -85.49 -116.01 -151.01 -190.37 -234.01 -281.79 -333.58 -368.19 -454.10 -490.33 -578.73 EW (ft) 0.00 0.00 0.87 4.36 10.65 91.42 111.71 133.82 157.69 183.26 210.45 228.36 272.63 291.29 336.84 Minimum Curvature / Lubinski 151.570° N 0.000 II, E 0.000 II KB 81.30 II relative to MSL 52.77 II relative to MSL 25.196° 57561.385 nT 80.809° January 15, 2004 BGGM 2003 True North +25.196° Well Head DlS ( deg/100 ft ) 0.00 0.00 1.00 /'2.00 3.00 19.04 29.50 42.00 56.52 73.01 W-400\Plan W-400\W-400\W-400 (P4) Tool Face (deg) 90.00M 90.00M 90.00M 123.11M 33.11 G 3.00 3.00 3.00 3.00 3.00 20.89G 15.12G 11.84G 9.74G 8.28G 3.00 3.00 3.00 3.00 3.00 7.22G 6.42G 5.79G 5.28G 4.87G 3.00 3.00 0.00 0.00 0.00 4.53G O.OOG O.OOG O.OOG O.OOG Northing (ftUS) 5958722.50 5958722.50 5958722.51 5958722.56 5958720.27 5958713.22 5958701.44 5958684.96 5958663.84 5958638.12 5958607.87 5958573.18 5958534.15 5958490.88 5958443.49 5958392.11 5958357.78 5958272,54 5958236.60 5958148.89 Easting (flUS) 611789.50 611789.50 611790.37 611793.86 611800.18 611808.68 611819.31 611832.06 611846.89 611863.76 611882.63 611903.44 611926.13 611950.64 611976.91 612004.86 612023.29 612068.83 612088.03 612134.88 - latitude longitude N 70.29618493 W 149.09477141 N 70.29618493 W 149.09477141 N 70.29618493 W 149.09476435 N 70.29618493 W 149.09473609 N 70.29617839 W 149.09468518 N 70.29615879 W 149.09461728 N 70.29612619 W 149.09453260 N 70.29608066 W 149.09443135 N 70.29602234 W 149.094~ N 70.29595139 W 149.094. N 70.29586800 W 149.09403123 N 70.29577239 W 149.09386695 N 70.29566484 W 149.09368794 N 70.29554564 W 149.09349469 N 70.29541511 W 149.09328772 N 70.29527360 W 149.09306761 N 70.29517906 W 149.09292254 N 70.29494435 W 149.09256422 N 70.29484537 W 149.09241311 N 70.29460386 W 149.09204441 Generated 9/17/20039:15 AM Page 1 of 2 SV3 2897.08 39.18 152.74 2564.27 2483.00 1085.74 -949.01 527.60 0.00 O,OOG 5957781.53 612331,11 N 70.29359227 W 149.09050020 SV2 3151.23 39.18 152.74 2761.27 2680.00 1246.28 -1091.75 601.15 0.00 O.OOG 5957639.91 612406.76 N 70.29320229 W 149.08990492 SV1 3556.33 39.18 152.74 3075.27 2994.00 1502.17 -1319,28 718.37 0.00 O.OOG 5957414.17 612527.35 N 70,29258068 W 149.08895615 13-3/8" Csg pt 3685.34 39.18 152.74 3175.27 3094.00 1583.67 -1391.74 755.70 0.00 O.OOG 5957342.28 612565.75 N 70.29238271 W 149.08865400 Drp 3/100 3696.59 39.18 152.74 3183.99 3102.72 1590.77 -1398.05 758.95 0.00 -175.21 G 5957336.01 612569.10 N 70.29236546 W 149.08862767 3700.00 39.08 152.73 3186.63 3105.36 1592.93 -1399.97 759.94 3.00 -175.20G 5957334.11 612570.11 N 70.29236023 W 149.08861968 3800.00 36.09 152.30 3265.87 3184.60 1653.91 -1454.08 788.08 3.00 -174.86G 5957280.43 612599.05 N 70.29221239 W 149.08839193 3900.00 33.11 151.81 3348.17 3266.90 1710.68 -1504.24 814.68 3.00 -174.45G 5957230.68 612626.39 N 70.29207535 W 149.08817667 End Drp 3937.13 32.00 151.61 3379.46 3298.19 1730.66 -1521.83 824.15 3.00 O.OOG 5957213.23 612636.11 N 70.29202729 W 149.08810005 W-400 Tgt 4037.13 32.00 151.61 3464.27 3383.00 1783.65 -1568.44 849.34 0.00 O.OOG 5957167.00 612662.00 N 70.29189993 W 149.08789612 UG4 4053.63 32,00 151.61 3478.27 3397.00 1792.39 -1576.14 853.50 0.00 O.OOG 5957159.37 612666.27 N 70.29187891 W 149.08786246 UG3 4356.68 32.00 151.61 3735.27 3654.00 1952.97 -1717.40 929.86 0.00 O.OOG 5957019.27 612744.72 N 70.29149297 W 149.08724450 UG1 4948.61 32.00 151.61 4237.27 4156.00 2266.63 -1993.33 1079.01 0.00 O.OOG 5956745.61 612897.94 N 70.29073910 W 149.086_ TO / 9-5/8" Csg 5029.97 32.00 151.61 4306.27 4225.00 2309.74 -2031.26 1099.51 0.00 O.OOG 5956708.00 612919.00 N 70.29063548 W 149.085 Lellal Description: NorthinQ (YI rftUS] EastinQ (XI rftUS] Surface : 3749 FSL 1455 FEL S21 T11 N R12E UM 5958722.50 611789.50 W-400 Tgt : 2181 FSL 610 FEL S21 T11 N R12E UM 5957167.00 612662.00 TD/BHL: 1718 FSL 360 FEL S21 T11N R12E UM 5956708.00 612919.00 e Version DO 3.1 RT ( d031 rt_546 ) 3.1 RT-SP3.03 W-400\Plan W-400\W-400\W-400 (P4) Generated 9/17/2003 9:15 AM Page 2 of 2 WEll Magnetic:Parameters Modet BGGM 2003 W-400 (P4) Dip: 80.809" Mag Dee: +25.196" o 750 1500 g o o 'R §: ~ II Q) -¡;¡ () (/) o ç 2250 3000 3750 Date: January 15, 2004 FS: 57561.4n1 o . FIELD Surfaœ location Lat N70 1746.266 Lon; W149541.177 750 KOP Bid 1/100 ---- Cry 3/100 Bid 2/100 e Schlumbørgør Prudhoe Bay Unit - WOA STRUCTURE W-PAD NAD27 Alaska state Planes, Zone 04, us Feet NorthIng: 5958722.50ftUS GridConv: +0.85223381· Easting: 611789.50ftUS Scale Fact 0.9999141963 Misœ"aneous Sk¡¡; W-400 Plan: W-400{p4) 1500 2250 TVDRef: KB(8127ftaboYeMSl) Srvy Dale: Seplsmber 17, 2003 3000 o 750 1500 2250 Drp 3/100 W-400Tg1 TD /9-5/S" Csg 4500 o W-400 (P4) 750 1500 2250 Vertical Section (ft) Azim = 151.57", Scale = 1(in):600(ft) Origin = 0 Nt-S, 0 E/-W 3000 3750 4500 3000 WELL W-400 (P4) MagneticPammeters Model: BGGM 2003 Dip: 80.809' Mag Dee: +25.196' o -300 -600 e FIELD e Schlumberger Prudhoe Bay Unit - WOA STRUCTURE W-PAD Date: January 15, 2004 FS' 57561.40T Surface Location Lat N70 17 46.266 Lon: W149541.177 NAD27 Alaska state Planes. Zooe 04, US Feet Northing: 5958722.50 ftUS Grid Com: +0.85223381' Easllng: 611789.50ftUS Scale Fact: 0.9999141963 1VD Ref: KB (81 :0 ft above MSL) SNyDate: September17,2003 o 300 Miscell!Vl6OUS Slot: W-400 W-400(P4) 600 1200 KOP Bid 900 o -300 -600 ^ ^ ^ z -900 -900 f2' 0 0 ~ ;§: ..- II Q) ro -1200 () -1200 (/) (/) V V V -1500 -1800 -2100 o -1500 -1800 -2100 300 600 900 <<< W Scale = 1(in):300(ft) E >>> 1200 · BPX AK Anticollision Report e NO GLOBAL SCAN: Using user defined selection & scan criteria Interpolation Method: MD Interval: 50.00 ft Depth Range: 28.50 to 5029.97 ft Maximum Radius: 3000.00 ft Reference: Error Model: Scan Method: Error Surface: Principal Plan & PLANNED PROGRAM ISCWSA Ellipse Trav Cylinder North Ellipse + Casing Survey Program for Definitive Wellpath Date: 6/18/2003 Validated: No Planned From To Survey ft ft 28.50 5029.97 Planned: Plan #4 V1 Version: 3 Toolcode Tool Name MWD+IFR+MS MWD + IFR + Multi Station Casing Points 3685.34 3175.27 5029.97 4306.27 13.375 9.625 16.000 12.250 133/8" 9 5/8" Summary PB W Pad W-01 Plan#3 W-01A VO Plan: 700.00 700.00 455.52 14.48 441.04 Pass: Major Risk PB W Pad W-01 W-01 V3 700.00 700.00 455.52 14.31 441.21 Pass: Major Risk PB W Pad W-02 W-02 V4 1330.35 1450.00 418.87 22.25 396.63 Pass: Major Risk PB W Pad W-02 W-02A V20 1331.31 1450.00 418.89 22.27 396.62 Pass: Major Risk PB W Pad W-03 W-03 V4 793.42 800.00 397.80 12.39 385.41 Pass: Major Risk PB W Pad W-03 W-03A V1 793.42 800.00 397.80 12.39 385.41 Pass: Major Risk PB W Pad W-04 W-04 V1 834.50 850.00 372.18 13.61 358.57 Pass: Major Risk PB W Pad W-05 Plan W-05A (Rotary) VO 800.00 800.00 344.80 13.80 331.01 Pass: Major Risk PB W Pad W-05 Plan#2 W-05L 1 VO Plan: 792.01 800.00 344.67 13.87 330.80 Pass: Major Risk PB W Pad W-05 W-05 V3 792.01 800.00 344.67 13.87 330.80 Pass: Major Risk PB W Pad W-06A W-06A V2 948.71 950.00 299.61 16.24 283.37 Pass: Major Risk PB W Pad W-06 W-06 V1 948.71 950.00 299.61 16.24 283.37 Pass: Major Risk PB W Pad W-07 W-07 V1 1085.58 1100.00 328.03 26.53 301.50 Pass: Major Risk PB W Pad W-08 W-08 V1 1040.05 1050.00 278.29 17.86 260.43 Pass: Major Risk PB W Pad W-08 W-08A V11 1045.55 1050.00 278.47 17.74 260.73 Pass: Major Risk PB W Pad W-09 W-09 V1 1606.14 1650.00 70.22 37.51 32.71 Pass: Major Risk PB W Pad W-10 W-10 V3 1684.73 1700.00 108.12 41.76 66.36 Pass: Major Risk PB W Pad W-10 W-10A V4 1684.73 1700.00 108.12 41.76 66.36 Pass: Major Risk PB W Pad W-11 W-11 V1 1522.45 1550.00 76.25 33.22 43.03 Pass: Major Risk PB W Pad W-12A W-12A V3 1939.99 1900.00 65.82 48.37 17.45 Pass: Major Risk PB W Pad W-12 W-12 V1 1939.99 1900.00 65.82 48.37 17.45 Pass: Major Risk PB W Pad W-15 W-15 V1 681.73 700.00 744.17 11.28 732.89 Pass: Major Risk PB W Pad W-15 W-15A V10 681.73 700.00 744.17 11.28 732.89 Pass: Major Risk PB W Pad W-15 W-15PB1 V6 681.73 700.00 744.17 11.28 732.89 Pass: Major Risk PB W Pad W-15 W-15PB2 V1 681.73 700.00 744.17 11.28 732.89 Pass: Major Risk PB W Pad W-16 W-16 V3 680.87 700.00 775.97 11.52 764.46 Pass: Major Risk PB W Pad W-16 W-16L1V3 680.87 700.00 775.97 11.52 764.46 Pass: Major Risk PB W Pad W-17 W-17 V1 686.69 700.00 807.49 11.81 795.68 Pass: Major Risk PB W Pad W-18 W-18 V1 685.31 700.00 841.50 12.53 828.98 Pass: Major Risk PB W Pad W-19 Plan#11 W-19AL 1 V1 Pia 683.20 700.00 875.38 11.45 863.94 Pass: Major Risk PB W Pad W-19 W-19 V2 677.93 700.00 875.29 11.18 864.11 Pass: Major Risk PB W Pad W-19 W-19A V1 683.20 700.00 875.38 11.28 864.11 Pass: Major Risk PB W Pad W-200PB1 W-200PB1 V7 644.07 650.00 1080.77 10.98 1069.79 Pass: Major Risk PB W Pad W-200 W-200 V6 644.08 650.00 1080.78 10.91 1069.86 Pass: Major Risk PB W Pad W-201 W-201 V4 644.30 650.00 1113.11 10.26 1102.85 Pass: Major Risk PB W Pad W-203 W-203 V9 992.33 950.00 266.06 14.85 251.21 Pass: Major Risk PB W Pad W-203 W-203L 1 V7 992.33 950.00 266.06 14.64 251.42 Pass: Major Risk PB W Pad W-203 W-203L2 V3 992.33 950.00 266.06 14.64 251.42 Pass: Major Risk PB W Pad W-207 W-207 V1 0 700.00 700.00 592.40 11.84 580.56 Pass: Major Risk PB W Pad W-207 W-207PB1 V2 700.00 700.00 592.40 11.84 580.56 Pass: Major Risk PB W Pad W-20 W-20 V1 683.20 700.00 909.71 11.26 898.45 Pass: Major Risk PB W Pad W-211 W-211 V8 750.89 800.00 649.60 12.68 636.92 Pass: Major Risk PB W Pad W-212 W-212 V12 647.56 650.00 680.49 9.40 671.09 Pass: Major Risk PB W Pad W-21 W-21 V3 675.83 700.00 944.59 15.65 928.94 Pass: Major Risk · BPX AK Anticollision Report e Summary PB W Pad W-21 W-21A V12 682.56 700.00 944.87 15.86 929.01 Pass: Major Risk PB W Pad W-22 W-22 V1 681.03 700.00 974.72 12.74 961.98 Pass: Major Risk PB W Pad W-23 W-23 V3 638.91 650.00 1010.03 10.18 999.86 Pass: Major Risk PB W Pad W-23 W-23A V5 645.62 650.00 1010.07 10.26 999.81 Pass: Major Risk PB W Pad W-24 W-24 V1 644.51 650.00 1045.48 11.22 1034.25 Pass: Major Risk PB W Pad W-25 W-25 V1 632.02 650.00 549.58 10.73 538.85 Pass: Major Risk PB W Pad W-26A W-26A V6 638.75 650.00 584.48 10.93 573.55 Pass: Major Risk PB W Pad W-26 W-26 V1 638.75 650.00 584.48 10.93 573.55 Pass: Major Risk PB W Pad W-27 W-27 V1 631.33 650.00 619.06 10.55 608.51 Pass: Major Risk PB W Pad W-29 W-29 V1 629.85 650.00 691.46 12.60 678.85 Pass: Major Risk PB W Pad W-30 W-30 V1 630.59 650.00 725.17 11.90 713.27 Pass: Major Risk PB W Pad W-31 W-31 V1 629.97 650.00 757.70 11.18 746.53 Pass: Major Risk PB W Pad W-32 W-32 V5 629.51 650.00 794.94 11.71 783.23 Pass: Major Risk PB W Pad W-32 W-32A PB1 V12 631.53 650.00 794.97 11.32 783.65 Pass: Major Risk PB W Pad W-32 W-32A V3 631.53 650.00 794.97 11.73 783.24 Pass: Major Risk PB W Pad W-34 W-34 V1 634.99 650.00 315.04 10.93 304.11 Pass: Major Risk PB W Pad W-34 W-34A V1 634.99 650.00 315.04 10.93 304.11 Pass: Major Risk PB W Pad W-34 W-34APB1 V1 634.99 650.00 315.04 10.93 304.11 Pass: Major Risk PB W Pad W-35 W-35 V1 590.44 600.00 280.83 12.40 268.43 Pass: Major Risk PB W Pad W-36 W-36 V1 635.78 650.00 243.32 10.78 232.54 Pass: Major Risk PB W Pad W-37 W-37 V3 636.51 650.00 208.61 11.02 197.59 Pass: Major Risk PB W Pad W-37 W-37A V3 636.51 650.00 208.61 11.02 197.59 Pass: Major Risk PB W Pad W-38 W-38 V2 820.60 850.00 160.51 17.03 143.48 Pass: Major Risk PB W Pad W-38 W-38A V10 823.01 850.00 160.55 16.82 143.73 Pass: Major Risk PB W Pad W-39 Plan#4 W-39A VO Plan: 637.41 650.00 139.52 12.39 127.13 Pass: Major Risk PB W Pad W-39 W-39 V1 637.41 650.00 139.52 12.39 127.13 Pass: Major Risk PB W Pad W-40 W-40 V1 636.89 650.00 104.77 11.22 93.55 Pass: Major Risk PB W Pad W-42 W-42 V1 598.34 600.00 33.92 9.92 24.00 Pass: Major Risk PB W Pad W-44 W-44 V1 891.38 900.00 30.04 13.51 16.53 Pass: Major Risk Field: Prudhoe Bay Site: PB W Pad Well: Plan W-400 Wellpath: Plan W-400 W-ll(W-ll) - -294 ·······200 100 -0 W-09 (W-09) 270 W-203 (W-203J,2) IPO 100 e m200 --294 180 29~ Tmvelling Cylinder Azimuth (TFO+AZI) [deg] vs Centre to Centre Separation [100ft/in] , ~... ( ¡- ( ¡ J r { ¡ 1 \ , 1 j L· i ) ¡ TL No. 55234 March' 3, 1977 Page 7 TEST II . . Formation: "A" Sand Core: 3,602 ft. Treatment: Establish permeability to Sadlerochit brine, immediately follow with fresh water. Volume Thru (cc' s) Ko 52 140 230 319 413 Fresh Water Ko 61 91 108 120 Conclusion DATA TABLE II Flow Rate (cc's/Min) , Differential Pressure (psi) 1.00 3.30 4.00 3.50 3.90 3.94 3.00 3.20 4.10 3.72 4.20 4.28 3.40 1.70 0.80 0.62 0.41 4.85 5.20 5.04 5.00 5.05 The formation is highly sensitive to fresh water. Permeability (md · s) 38.5 ,·119 113 109 107 106 76.8 35.8 17.4 13.6 8.9 I I I I I I I I I I I I I I I I I I I , ~ . TABLE 1-2 . Waterflood Water Quality The waterflood process will utilize source water (seawater) and produced water. Typical composition of both water types is presented here. o SOUrce Water Analysis Sodium Iron Barium Calcium Magnesium Chloride Hydrocarbonate Carbonate Sulfate Dissolved Solids Suspended Solids Nitrogen Carbon Dioxide Dissolved Oxygen o Produced Water Analysis Sodium Iron Barium Calcium Magnesium Chloride Sulfate Sulfide Dissolved Solids Suspended Solids Carbon Dioxide Dissolved Oxygen Total Alkalinity pH Crude Oil In Water Total oil & Grease o Water Treatment Additives 10800 - 11100 o o 341 - 1160 - 18800 - 142 - o 2580 - 7400 6 .1 162 38 11000 61 2.2 22600 5.7 871 .26 1600 6.7 178 87 373 1260 19400 149 2640 3.5 1.0 17.0 156 .02 PPM PPM PPM PPM PPM PPM PPM MOIL PPM MOIL PPM PPM MOIL PPM MOIL MOIL MOIL MOIL MOIL MOIL MOIL \IT Percent PPM W (Max.) PPM W PPM W (Max.) PPM W Water treatment additives include biocide, corrosion inhibitors, scale inhibitors, oxygen scavengers, and antifoam agents. A coagulant 1.5 also added upstream of the seawater filtration equipment. -29- I I I I I I I I I I I I I I I I I I I .. v , . C. Compatibility with Formation and Confining Zones Water sensitivity tests on core samples showed no significant problems with formation plugging or clay swelling over the anticipated operating range of salinities for produced and Beaufort Sea water. 2. Type of Fluid - Miscible Gas A. Analysis of Composition of Fluid The composition of the injectant is expected to be similar to that described in Table 1-3. B. Source of Fluid The Central Gas Facility (OGF) will be operational in early 1987 and will be responsible for the supply and composition of miscible gas for the miscible project. C. CompatibHity with Formation and Confining Zones Full compatibility- reinjected into producing zone. 3. Type of Fluid - Produced Gas A. Analysis of composition of Fluid Composition of the injected gas will be similar to that described in Table 1-4. B. Source of Fluid Sadlerochit and Sag River reservoirs. -30- e http://www.state.ak.usllocallakpages/ ADMIN/ogc/orderslaio/ai03 e Area Injection Order No.3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 Porcupine Drive Anchorage, Alaska 99501-3192 Re: THE REQUEST OF STANDARD ALASKA PRODUCTION COMPANY for an Area Injection Order for that portion of the Prudhoe Bay Unit commonly known as the Western Operating Area including the contiguous K Pad Area. Area Injection Order No. 3 Western Operating Area including the K Pad Area Prudhoe Bay Unit Prudhoe Bay Field July 11, 1986 IT APPEARING THAT: 1. Standard Alaska Production Company (SAPC) requested the Alaska Oil and Gas Conservation Commission to issue an Area Injection Order permitting the underground injection of fluids within the Western Operating Area and K Pad Area of the Prudhoe Bay Unit for the purposes of enhanced recovery and the disposal of non-hazardous oil field waste fluids. 2. Notice of an opportunity for a public hearing on June 25, 1986, was published in the Anchorage Times on May 22,1986. 3. Neither a protest nor a request for a public hearing was timely filed. Accordingly, the Commission will, in its discretion, issue an order without a public hearing. FINDINGS: 1. An order permitting the underground injection of non-hazardous fluids on an area basis, rather than for each injection well individually, provides for efficiencies in the administration and surveillance of underground fluid injection operations. 20 MC 25.460 provides the Commission with the authority to issue an order governing underground injection operations on an area basis. 2. The Western Operating Area and the contiguous K Pad Area constitute a compact "project area" for the operation of a portion of the Prudhoe Bay Unit and can readily be described by governmental subdivisions. The Project Area is operated by a single operator. 3. The Project Area encompasses approximately the western one-half of the Prudhoe Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for enhanced recovery from this portion of the Prudhoe Oil Pool. The Project Area includes all existing injection wells and injection well sites planned for disposal by injection into Cretaceous and Tertiary strata of oil field waste fluids developed from the operation of this portion of the Prudhoe Bay Unit. Area Injection Order No.3 e http://www.state.ak.usllocal/akpagesl ADMIN/ogc/orderslaio/aio3 e 4. Those portions of aquifers described by a 1/4 mile area beyond and lying directly below the Project Area are exempted for Class II injection activities by Aquifer Exemption Order NO.1. 5. Less stringent requirements for well construction, operation, monitoring and reporting of injection operations may be more appropriate than would be required when injection occurs into, through or above portions of aquifers not exempted. 6. The vertical limits of injection strata and the confining formations may be defined in the ARCO Alaska Inc. (Atlantic Richfield-Humble) Prudhoe Bay, State Well NO.1 and the SAPC Prudhoe Bay Unit Well No. C-II. 7. The strata into which fluids are to be injected will accept fluids at injection pressures which are less than the fracture pressure of the injection strata and their confining formations. 8. Statewide regulations and conservation orders govern field operations except as modified by this order. 9. To ensure that fluids injected are confined to injection strata, the mechanical integrity of an injection well should be demonstrated periodically and monitored routinely for disclosure of possible abnormalities in operating conditions. 10. Injection wells existing on the date of this order were constructed and completed in accordance with regulations which conform to the requirement of 20 AAC 25.412. NOW, THEREFORE, IT IS ORDERED THAT the rules hereinafter set forth govern Class II underground injection operations in the following described area referred to in this order as the affected area: UMIAT MERIDIAN e http://www.state.ak.usllocallakpagesl ADMIN/ogc/orderslaio/aio3 e Area Injection Order No.3 T12N R10E Sections 13 and 24 T12N RIlE Sections 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19,20,21,22,23,24, 25,26,27,28,29,30,32,33,34,35 and 36. T12N R12E Sections 7, 17, 18, 19,20,21,22,23,24,25,26,27,28,29,30,31, 32, 33, 34, 35 and 36. T12N R13E Sections 19,20,21,22,23,26,27,28,29,30,31,32,33,34,35 and 36. T12N R14E Sections 27, 28, 29,31,32,33, and 34. T11N RIlE Sections 1,2,3,4,9, 10, 11, 12, 13, 14, 15,24, and 25. T11N R12E Entire Township T11N R13E Entire Township T11N R14E Sections 3, 4, 5, 6, 7,8,17,18,19,20,29,30,31 and 32. T10N R12E Sections 1,2,3,4, 10, 11 and 12. T10N R13E Sections 1,2,3,4,5,6, 7, 8, 9, 10, 11, 12, 13, 14, 15, 16 and 24. T10N R14E Sections 5, 6, 7, 8, 17, 18, 19 and 20. Rule 1 Authorized Injection Strata for Enhanced Recovery Within the affected area, non-hazardous fluids may be injected for purposes of pressure maintenance and enhanced oil recovery into strata defined as those strata which correlate with the strata found in ARCO Alaska Inc. (Atlantic Richfield-Humble) Prudhoe Say State Well NO.1 between the measured depths of 8110 feet and 8680 feet. Rule 2 Authorized Injection Strata for Disposal Within the affected area, non-hazardous oil field fluids may be injected for the purpose of fluid disposal into strata defined as those strata which correlate with the strata found in SAPC's Prudhoe Say Unit Well No. C-II between the measured depths of 3990 feet and 6293 feet. Rule 3 fluid Injection Wells The underground injection of fluids must be: 1) through a new well that has been permitted for drilling as a service well for injection in conformance with 20 AAC 25.005; 2) through an existing well that has been approved for conversion to a service well for injection in conformance with 20 AAC 25.280; or 3) through a well that existed as a service well for injection purposes on the date of this order. Pumping of excess non-hazardous fluids that are developed solely from well operations, or necessary to control the fluid level of reserve pits, into surface/production casing annuli is exempted from the above requirements. Rule 4 Monitoring The Tubing/Casing Annulus Pressures " , e http://www.state.ak.usllocal/akpagesl ADMIN/ogc/orderslaio/aio3 e Area Injection Order No.3 The tubing/casing annulus pressure of each injection well must be checked weekly as a routine duty to ensure there is no leakage and that it does not exceed a pressure that will subject the casing to a hoop stress greater than 70% of the casing's minimum yield strength. Rule 5 Reporting the Tubing/Casing Annulus Pressure Variations Tubing/casing annulus pressure variations between consecutive observations need not be reported to the Commission. Rule 6 Demonstration of Tubing/Casing Annulus Mechanical Integrity A schedule must be developed and coordinated with the Commission which ensures that the tubing/casing annulus for each injection well is pressure tested prior to initiating injection and at least once every four years thereafter. A test surface pressure of 1500 psi or 0.25 psi/ft multiplied by the vertical depth of the packer, which ever is greater, must be held for 30 minutes with no more than a 10 percent decline. The Commission must be notified at least 24 hours in advance to enable a representative to witness pressure tests. Rule 7 Well Integrity Failure Whenever operating pressure observances or pressure tests indicate pressure communication or leakage of any casing, tubing or packer, the operator must immediately cease injection, notify the Commission, and obtain approval for corrective action. Rule 8 Plugging and Abandonment of Fluid Injection Wells An injection well located within the affected area must not be plugged or abandoned unless approved by the Commission in accordance with 20 AAC 25.105. Rule 9 Administrative Relief Upon request, the Commission may administratively amend any rule stated above as long as the operator demonstrates to the Commission's satisfaction that sound engineering practices are maintained and the amendment will not result in an increased risk of fluid movement into an underground source of drinking water. DONE at Anchorage, Alaska and dated July 11, 1986. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission Lonnie C. Smith, Commissioner Alaska Oil and Gas Conservation Commission William W. Barnwell, Commissioner Alaska Oil and Gas Conservation Commission Area injection Order Index P055141 DATE 8/22/2003 I I CHECK NO. 055141 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 8/22/2003 INV# PR082003D PERMIT TO DRILL -=EE H w·l{ro e THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL .. e 11·055 ¡It ¡'II· 1:0 L. ¡. 20 ~8 '151: 0 ¡. 2 '78'1 bll· e e TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRJA TE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well ~ Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). Pn.,OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 ajody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing ,exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below tbe permafrost or from where samples are first caught and 10' sample intervals through target zones. Company BP EXPLORATION (ALASKA) INC Well Name: PRUDHOE BAY UN UGN W-400 Program SER Well bore seg 0 PTD#: 2031650 Field & Pool PRUDHOE BAY, UGNU UNDEF WTRSP - 64017 Initial ClasslType SER / WTRSP GeoArea Unit On/Off Shore ~ Annular Disposal 0 Administration P.ßlJl1itfee élttact)e.cL . Yes - - - - - 2 .Leéls.e-"!Jmber .approRriate. . . · Yes - - - - - - - - - 3 .U.nlq\Je weltn.am.ß.and oumb.er . . . . . . . . . . . . . . . . . . . . . . . . . . · .Y.ßs · - - - - - - - - - - - - - - - - - . - - - - - -- - - - - -- - - - - - - - - - - - - - ~ - - - " . - - - - - - -- 4 WeU JQcat.ßd In.a d.efjrJedpool. - - - - - · No · Th.is. is a !.Igl1u.fm. WélterSoyrçe well, tt will.SYRPlyjrJjectiol1 WélterJQrthe.we.st endl\i'is.hak . . 5 WeJUQcat.ßd proper .dlstance. from driJling urJitb.oUrJd.a!y. - - - - - · Yes Theattach.ßd dQcumelJts i.ncludilJgAIO .#3 .aod seyeraLexceptsJromtbe Alo..#. 3. appUc.atiQn, snow.the Ivisnak is 6 Well IQcat.ßd proper .dlstance. from Qtber wells. . . . . - - - - - Y.ßs · éI Wélter s.ßos.itlve fOJméltioo alJd théltpro.duced water al1d seawater weretbe QnJy. fLuids evaJuated fQr .Eo.R . 7 .S.utficierJtacreélgeaYélilable in drilJiog unjt. - - - - - · Y.ßs in .thelvishai<..PriOf: to aPRrQving .the Ugn\J water for IYist)aJc .Eo.R we must requirea. wa.ter aoalysisJf:orn. . 8 Jf.deviélted, is. weJlboJe platirJcluded . - - - -- · Yes the W-400.well aod. s.orneeyklence it is.CJ:>rnpatiþtewith th.ß .Ms.hak. This infQrmation wm.b.ß .used. to \Jpdate. 9 .Operator orJly élffected party. . - - - -- - - - - · Y.ßs Alo..#3. ßJ='C 10 .Operator bas.appropriate.b.ood inJQrce . . . . . . . . . . . . . . . . . . . . . · Y.ßs " - - - - - - - - - - - - - - - - - - - - 11 P.ßrmit cao be lssued witbQut conserva.tiOrJ order. . - - - - - · Yes Appr Date 12 P.ßlJl1it cao be issued witbQut ad.milJistrati\i'e.appr~>vaJ . . · Y.ßs - - - - RPC 9/29/2003 13 Can permit be approved before 15-day wait Yes e 14 WelUQcated wlthil1 élrea al1d.strata .authorlzed by Injectioo o.rder # (put 10# in. c.omm.ellts) (FQr .NA 15 .AJI wells. within .1l4.mite.area.of reyiew id.ellt[fied (For s.ervjc.e.well ol1ly). . . . . . . . . . . . . . . .NA - - - - - - - - - - - - - - - - - - - . - 16 Pre-produced illjector;duratiQnof pre-productiolJ l.ßss. than. 3. mOrJtbs (For.service well QnJy) . . NA - - - - -- 17 .A~MP.F:irJdjngof CQn.si,Stency.h.as bee.n.is.s\Jed fortbis pr9iect. . . . · NA - - - - - Engineering 18 .C.oodu.ctor st(ingprQvided . . . - - - - -- · Y.ßs - - - - 19 .S!.Irfacecas.ingpJQtects. aU known USDWs . . . . . . · . Y.ßs - - - - - - - -- 20 CMTv.otadequate.to circ.utate.o.ncOrJd.uctor.& SUJf.csg . . - - - - -- Y.ßs 21 .CMT. vol adequate. to tie-in JQng .striog to surf cs.g. · Y.ßs - - - -- 22 CMT will coYer.all JclJownpro.ductiye hQrizon.s. . . . - - - - - - - - - - · Yes 23 .C.asillg desiglls adeQuate f9r C,T, B.&Rermafr9st - - - - - . . . . . . . . . Y.ßs 24 Adequate.tankage.oJ re.seI'Ye pit. . - - - -- - - - - - - Ye!¡¡ · Rig JBD. . . . 25 If.a.re-d(iII~ has.a lOA03 fQr abandonme.nt beeo aPPJoved . . . - - -- .. .NA l'Jewwell, . 26 .Adequate.wellbore. s;eparatio.npropos.ep. . _ . . . . . . . . . . . . . . . . . . . . . . _ . . . . . . . Y.ß$ · - - - - - - - - - - - - - - - - - - - - 27 If.divecter Jequired, dQes it meet reguJations. - - - -- - - - - - · Yes Appr Date 28 .DrillilJQ fluid. prQgram schematic &. equip listadequat.ß. . . - - - - - - - - . . . . . Yes Max MW9,5. ppg. . . . . WGA 9/29/2003 29 .BOPEs,do.they meetreguJatiolJ . . - - - - ~ · Y.ßs - - - -- e 30 .B.oPEpres$ faiiog approptiate;test t.o.(pu.t psig in.commerJts). - - - - · Yes Testt035QOpsi. .MS~ 1551 psi.. 31 C.hokemanifold cQmpJies. w/API R~-53. (May 84). . . . . . - - - - - - - - -- · . Y.ßs 32 WQrk will OCcur withoutoperatjo.nsbutdo.wn. - - - - -- - - - - - · Y.ß$ - - - - -- 33 Is. pres.ence Qf H2S gas. prob.able. . . - - - - - · . No. 34 Meçba.nical.CJ:>nd.it[oo 9{ wells wi.thirJ AOß yerified (for.s.ervice welJ on.ly). - - - - - - Yes I'JQ wells witbin AOR.. Geology 35 Permit c.all be issuep wlo. hypr.ogen s.ulfide meaS!.l(e$. . . . - - - - -- Y.ßs 36 .D.ata.PJesented on. pote.ntial ove.rpres.sure .zOrJes. . . . . . . . - - - - - - - - _. NA Appr Date 37 .Sei'smicanalysjs. Qf sbaJlow gas.z.ooes. . . .NA RPC 9/29/2003 38 .Seabed .condition survey (if off-s.h9re) . . . .. .NA - - -- 39 . CQntact namelphone.forwee~ly progres.s.reRorts [expIQrato!y .only]. . . - - - -- ..... NA Geologic Public Commissioner: Date: Date Commissioner Date (JW ll~?(r ~~ ~~~ \!i