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195-144
Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. //~',.~'-//~-/~/ File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: E~Grayscale, halftones, pictures, graphs, charts- Pages'/~/~" [] Poor Quality Original - Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS' Scanned by: Bevedy Dianna~than Lowell /si [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 6 2014 WELL COMPLETION OR RECO - LETION REPORT AND LO9k0GCC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other N'Abandoned ►:a Suspended 1 b. Well Class (eOAAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG El WDSPL 0 Other '[i" \\,L' y/1 ` �No.of Completions Zero ®Development 0 Service J 2. Operator Name: ArA 5. I ate Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 2/8/2014 195-144. 313-593 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 9/16/1995 50-029-22599-00-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 9/30/1995 MPF-78, 2237'FSL,2555'FEL,Sec.06,T13N, R10E, UM 8. KB(ft above MSL): 47.54' 15.Field/Pool(s) Top of Productive Horizon: 4015' FSL,716' FEL, Sec.30,T14N, R10E, UM GL(ft above MSL): 12.2' Milne Point/Kuparuk River Oil, Total Depth: 9.Plug Back Depth(MD+TVD) 4273' FSL,699' FEL, Sec. 30,T14N, R10E, UM 15559' 7289' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 542005 y- 6035691 Zone- ASP4 16070' 7715' ADL 025509&355018 TPI: x- 543727 y- 6048036 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 543741 y- 6048295 Zone- ASP4 None 18.Directional Survey: El Yes ®No 19.Water depth,if offshore: 20. Thickness of Permafrost(ND): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1800'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MDITVD: MWD, Gyro, LWD,GR, RES, NEU, DEN N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE ToP BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.1# NT8OLHE 35' 113' 35' 113' _ 30" 260 sx Arctic Set(Approx.) 9-5/8" 40# NT8OLHE 35' 7919' 35' 4497' _ 12-1/4" 1555 sx PF'E',250 sx Class'G',250 sx PF'E' 7" 26# L-80 33' 16042' 33' 7689' 8-1/2" 231 sx Class'G' 24. Open to production or injection? 0 Yes ®No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2", 12.6#,L-80 Work 15399' 15294'/7092' String 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. d b,<G r Ytkfte WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No A , -= DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED SAW APR 8 ?)Y4 Diva,, 15600'VE Set Whipstock ., i >� 15603' 24 Bbls Class'G' / 15559' Set 2nd Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period • Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None iBDMS APR 16 20''\ Form 10-407 Revised 10/2012 1 4 ' 41,, I , if CONTINUED ON REVERSE -P14 412l'J( Submit Original Only 29. GEOLOGIC MARKERS(List all formations anc' ;ers encounter 30. FORMATION TESTS NAME ND Well Tested? Li Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Kuparuk D 15378' 7153' None Kuparuk C 15589' 7312' Kuparuk B 15603' 7323' Kuparuk A 15642' 7353' Kuparuk A3 15649' 7358' Kuparuk A2 15669' 7373' Kuparuk Al 15697' 7395' Miluveach 15739' 7428' Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nathan Sperry,564-4258 Email: Nathan.Sperry@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist Signature: Phone 564-4091 Date:3/s//j 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. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. 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: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: 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 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. North America-ALASKA-BP Page 1 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UW:500292259900 Active datum:Orig Rig on MPF-78 t47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) - (usft) 11/16/2013 06:00 - 06:30 0.50 MOB P PRE RIG RELEASED FROM WELL MPF-93. CONTINUE SECURE CELLAR AREA. 06:30 - 08:30 2.00 MOB P PRE PJSM WITH ALL CREWS FOR PULLING OFF WELL. INVITE PAD OPERATOR TO WITNESS RIG MOVE,DECLINED. MOVE OFF WELL MPF-93 AND OVER WELL MPF-78. MOVING ON AND OFF WELL IS WITNESSED •BY WSL,TOOLPUSHER. 08:30 - 11:30 3.00 I MOB P PRE SET RIG DOWN OVER MPF-78,START RIGGING UP. LEVEL AND SHIM RIG. • START RIG UP CIRC SKID AND LINE TO FLOWBACK TANK. TAKE 9.3#BRINE INTO PITS. CONTINUE RIGGING UP CIRC SKID. - ACCEPT RIG ON MPF-78 AT 1000 HRS 11:30 - 13:30 2.00 • RIGU P PRE CREW CHANGE AND RIG CHECKS. HEAT UP LINE OUT TO FLOWBACK TANK AND CHECK ALL CONNECTIONS. BLOWAIR OUT TO TANKS TO ENSURE ITS CLEAR. 13:30 - 14:00 0.50 RIGU P PRE CONDUCT RIG EVAC DRILL. ALL PERSONS MUSTER AND ACCOUNTED FOR. CONDUCT AAR. 14:00 - 16:00 2.00 RIGU P PRE PRESSURE TEST LINES ON CIRC SKID AND GOING OUT TO FLOWBACK TANK. 16:00 - 17:00 1.00 WHSUR P DECOMP PJSM THEN RIG UP BPV LUBRICATOR AND PT. PULL BPV. 17:00 - 18:00 1.00 WHSUR P DECOMP PJSM,WELL KILL. -REVIEW DDI WELL KILL S.O.P. -DISCUSS CIRCULATION KILL PLAN WITH MUD ENGINEER AND PIT CREW. DISCUSSED INDIVIDUAL ROLLS AND RESPONSIBILITIES. -WSL AND TOOL PUSHER INSPECT R/U OF KILL MANIFOLD AND HARD LINE. 18.00 - 19:00 1.00 WHSUR P DECOMP PERFORM CIRCULATION WELL KILL -SITP=1250 PSI,SICP=1340 PSI,OA=0 PSI KWF=9.3 PPG BRINE HEATED TO 120 F -BLEED FROM THE IA TO FLOW BACK TANK FROM 1340 PSI TO 200 PSI IN 30 MINS -CRUDE RETURNS JUST PRIOR TO SHUTTING IN 1-SHUT IN AND LINE UP TO PUMP Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 2 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:OOAM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:00 - 00:00 5.00 WHSUR P DECOMP OPEN TBG AND IA AND COME ONLINE WITH PUMPS PUMP 90 BBLS KWF DOWN THE TBG UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK. 80 BBLS FLUID RETURNED TO SURFACE. ALL CRUDE. -BULL HEAD ON THE FLY:30 BBLS KWF,3 BPM PUMP 810 BBLS KWF DOWN THE TBG UP THE IA THROUGH THE CHOKE TO THE FLOW BACK TANK. -ICP=3 BPM/1750 PSI FCP=5 BPM/2320 PSI -OBSERVED GAS BREAKING OUT IN RETURNS AT 237 BBLS CIRCULATED -CONFIRM CLEAN 9.3 PPG BRINE RETURNS AT 725 BBLS CIRCULATED. -MONITOR WELL FOR 50 MIN.TBG AND IA ON A VACUUM -LOST 170 BBLS KWF TO THE FORMATION. -14 BBL/HR LOSS RATE 24 HRS LOSSES=170 BBLS 9.3 PPG BRINE 250 BBLS CRUDE RECOVERED AND SENT TO MP RECYCLE 11/17/2013 00:00 - 01:00 1.00 WHSUR P DECOMP SPCC CHECKS AND PRE-TOUR MEETING PJSM,RIG DOWN KILL MANIFOLD. -BLOW DOWN ALL CIRCULATING LINE. -RIG DOWN CIRCULATING LINES&KILL MANIFOLD R/U SECONDARY KILL LINE. 01:00 - 04:00 3.00 WHSUR P DECOMP PJSM WITH WELL SUPPORT AND RIG CREW TO SET TWC -M/U LUBRICATOR&TEST -250 PSI LOW AND 3500 PSI FOR 5 MINS EACH,CHARTED -SET TWC -L/D LUBRICATOR. -PERFORM ROLLING TEST BELOW TWC -PUMP DOWN IA @ 3.5 BPM AND 500 PSI FOR 5 MINS,CHARTED -TEST TWC FROM ABOVE,250 PSI LOW& 3500 PSI HIGH FOR 5 MINS EACH,CHARTED 04:00 - 06:30 2.50 WHSUR P DECOMP PJSM,N/D TREE -FMC HAND BLED DOWN TUBING HEAD ADAPTOR -N/D 2 9/16"CAMERON TREE -CHECK HANGER THREADS=2-7/8 EUE 06:30 - 08:30 2.00 BOPSUR P DECOMP INSTALL BOPS AND KILL LINE, TURNBUCKLES. INSTALL HYDRAULIC LINES AND RISER. 08:30 - 09:30 1.00 WHSUR N WAIT DECOMP WELD ON RISER EXTENSION. RISER NEEDS 4 INCHES ADDED DUE TO LOWER TREE HEIGHT. 09:30 - 10:30 1.00 BOPSUR P DECOMP RIG UP TEST EQUIPMENT AND TEST JOINTS. PREP FOR BOP TEST. Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 3 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UW:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 15:00 4.50 BOPSUR P DECOMP PRESSURE TEST BOPS. ALL PREVENTERS TESTED AGAINST TWC AND HANGER. ANNULAR TESTED WITH 2-7/8"TEST JOINT. UPPER AND LOWER 2-7/8 X 5 VBRS TESTED WITH BOTH 2-7/8"AND 4-1/2"TEST JOINT. AOGCC INSPECTOR BOB NOBLE WAIVED WITNESS. TEST WAS WITNESSED BY TOOLPUSHER AND WSL. 15:00 - 15:30 0.50 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT. VAC OUT STACK AND PURGE LINES WITH AIR. 15:30 - 17:30 2.00 BOPSUR P DECOMP MAKE UP TWC LUBRICATOR AND TEST TO 250/3500 PSI,GOOD. PULL TWC. RIG DOWN WELLS SUPPORT EQUIPMENT AND OFFLOAD FROM RIG. 17:30 - 18:30 1.00 PULL P DECOMP PJSM ON PULLING 2 7/8"EUE TBG HANGER TO FLOOR. -MU 2-7/8"EUE LANDING JOINT WITH FOSV TO TBG HANGER. -BOLDS PER FMC REP. -PULL TBG HANGER OFF SEAT @ 140 K INCLUDES 40K TOP DRIVE WT. -PULL HANGER AND CLAMPS ON FIRST FULL JOINT, -CUT ESP CABLE. -POSITION SLICK JOINT ACROSS ANNULAR LOCK DOWN SCREWS=3.74"IN&4.75"OUT 18:30 - 20:30 2.00 PULL P DECOMP CLOSE ANNULAR AND CIRCULATE -PUMP DOWN TUBING,3.5 BPM=740 PSI -TAKE RETURNS THRU GAS BUSTER -PUMP 90 BBLS 9.3PPG BRINE, -SHUT DOWN AND MONITOR WELL -WSL/TOUR PUSHER VERIFY VACUUM AND NO TRAPPED PRESSURE -OPEN ANNULAR. -LD TUBING HANGER -HANG ESP SHEAVE IN DERRICK.LAY OUT CABLE TRUNK FOR ESP CABLE 20:30 - 21:00 0.50 PULL P DECOMP PREPARE TO RUN ESP CABLE OVER SHEAVE TO SPOOLER -CENTRILIFT REP PREP THREE LEAD LIFT DEVICE -SPLICE ESP CABLE,EXPOSING 3 SMALLER CABLES -CRIMP LIFT DEVICE TO EACH CABLE -ATTACH LIFT DEVICE TO WINCH CORD -TOOLPUSHER&WSL ON RIG FLOOR WITH RIG MECHANIC IN SPOOLING UNIT • 21:00 - 21:30 0.50 PULL P DECOMP PULL ESP CABLE OVER SHEAVE -ATTEMPT TO PULL ESP CABLE OVER SHEAVE -WITH ESP CABLE-5FT ABOVE RIG FLOOR THE WIRE LINES FROM THE 3 CRIMPED LIFT DEVICE FAILS -CABLE LEANS AGAINST A-LEG -SECURE CABLE AND INSPECT -MAKE NOTIFICATIONS AND DEVISE PLAN FORWARD Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 4 of 9 Operation Summary Report Common Well,Name:MPF-78 AFE No Event Type:WORKOVER 0O) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum:prig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:30 1.00 PULL P DECOMP ATTACH LIFT DEVICE TO ESP CABLE -POH WITH 2 STANDS,2-7/8"TUBING, • LAYING ESP CABLE SLACK ON RIG ROOF -CUT OLD CRIMPED CONNECTORS OFF CABLE -RE-SPLICE AND ATTACH NEW 3 LEAD LIFT DEVICE -ATTACH SECONDARY RESTRAINT FROM ESP CABLE TO WINCH CABLE -PICK CABLE UP-4 FT AND PULL TEST,NO ISSUES 22:30 - 23:30 1.00 PULL P DECOMP POOH WITH 2-7/8"EUE 8RD TUBING -RUN ESP CABLE OVER SHEAVE USING WINCH IN SPOOLING UNIT. -ATTACH ESP CABLE TO REEL IN SPOOLING UNIT. -POOH WITH 2-7/8 TUBING FROM 15466'TO 14672' 23:30 - 00:00 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL -GOOD RESPONSE BY FLOOR HANDS, EQUIPMENT TO SECURE WELL WAS EASILY ACCESIBLE -DISCUSSED ADDING PUP JOINT TO FOSV IN ORDER TO USE POWER TONGS TO TORQUE MAINTAIN HOLE FILL TO IA AT 12 BPH OF 9.3 PPG BRINE 24 HR LOSSES=99 BBLS 11/18/2013 00:00 - 04:00 4.00 PULL P DECOMP SPCC CHECKS AND PRE-TOUR MEETING -POOH WITH 2-7/8"EUE 8RD TUBING AND ESP ASSEMBLY -POH WITH TUBING,ESP CABLE -POOH FROM 14672'MD. -STAND BACK FIRST 65 STANDS OF TUBING IN DERRICK 04:00 - 04:30 , 0.50 PULL P DECOMP KICK WHILE TRIPPING DRILL AAR: GOOD RESPONSE BY CREW DISCUSSED WITH FILL IN PIT WATCHER CONTINGENCY PLANS FOR WEIGHTING UP 04:30 - 06:00 1.50 PULL P DECOMP BEGIN LAYING DOWN TUBING -65 STANDS IN DERRICK -LAY DOWN 2-7/8"EUE 8RD TUBING FROM 9421 FT -LAY DOWN 1 X 1 IN PIPE SHED. LAY DOWN PIPE FROM 9307 FT TO 7603 FT. 06:00 - 06:30 0.50 PULL P DECOMP CHANGE OUT SPOOL IN SPOOLING UNIT, FIRST ONE IS FULL. 06:30 - 12:00 5.50 PULL P DECOMP CONTINUE LAY DOWN PIPE SINGLES FROM 7603 FT TO 3811 FT. 12:00 - 12:30 0.50 PULL P DECOMP CREW CHANGE AND RIG CHECKS. 12:30 - 17:30 5.00 PULL P DECOMP CONTINUE LAY DOWN 2-7/8"8RD EUE TUBING FROM 3811 FT TO ESP. 17:30 - 20:00 2.50 PULL P DECOMP LD ESP PUMP AND MOTOR ASSEMBLY -FEED ESP CABLE THROUGH SHEAVE AND SPOOL UP ON REEL IN SPOOLING UNIT Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 5 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 II Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum:Orig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 21:00 1.00 PULL P DECOMP RIG DOWN CENTRILIFT -ESP LOOKS GOOD AS PER CENTRILIFT -R/D SHEAVE • -CLEAN AND CLEAR RIG FLOOR RECOVERED 6 PROTECTOLIZERS,3 FLAT GAURDS,&369 CLAMPS 21:00 - 21:30 0.50 EVAL P DECOMP MAKE UP WEAR RING RUNNING TOOL -P/U RUNNING TOOL -INSTALL WEAR RING,I.D.=7.0625 -LAY DOWN RUNNING TOOL 21:30 - 00:00 2.50 EVAL P DECOMP PJSM,MU AND RIH WITH 7"HES CHAMP PACKER -P/U CHAMP PACKER AS PER HES REP -OD OF CHAMP PACKER=5.94" -RIH ON 2-7/8"EUE 8RD TUBING FROM DERRICK -RIH TO-4340'MD,43 STANDS OF 2-7/8"IN ,HOLE MAINTAIN HOLE FILL TO IA AT 8 BPH OF 9.3 PPG BRINE 24 HR LOSSES=205 BBLS 11/19/2013 00:00 - 02:00 2.00 EVAL P DECOMP SPCC CHECKS AND PRE-TOUR MEETING RUN IN HOLE WITH 7"HES CHAMP PACKER -RIH FROM-4340 MD ON 2-7/8"EUE 8RD TUBING -RIH 62 STANDS FROM DERRICK 02:00 - 12:00 10.00 EVAL P DECOMP RUN IN HOLE WITH 7"HES CHAMP PACKER -RIH TO-5380 MD ON 2-7/8"EUE 8RD TUBING,STAND#62 -P/U 4"DP SINGLES FROM PIPE SHED -RIH TO 14,563'MD PUW=164 K,SOW=9 90K 12:00 - 12:30 0.50 EVAL P DECOMP !CREW CHANGE. -SPCC CHECKS AND WALKAROUNDS. -INSPECT FLOOR EQUIPMENT 12:30 - 14:00 1.50 EVAL P DECOMP RUN IN HOLE WITH 7"HES CHAMP PACKER -P/U 4"DP 1x 1 FROM PIPE SHED RIH FROM 14563'TO 15381' -MAKE UP TOP DRIVE 14:00 - 15:00 1.00 EVAL P DECOMP 'PJSM SLIP AND CUT DRILL LINE -HANG BLOCKS -SLIP AND CUT 61'OF DRILLING LINE 15:00 - 16:30 1.50 EVAL P DECOMP PJSM SET 7"HES CHAMP PACKER -RIH TO 15385' -PICK UP&OBTAIN PARAMETERS AT 15,373 FT -PUMP RATE=2 BPM @ 240 PSI -PUW=184 K,SOW=84K -SET DOWN 15K AND ROTATE 5 TURNS -PACKER SET AT 15,373'MD C.O.E. Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 6 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 18:30 2.00 EVAL P DECOMP PJSM,MIT-IA 7"L-80 26#CSG BY 2-7/8" TUBING&4"DP ANNULUS -CONFIRM VALVE ALLIGNMENT PRIOR TO TEST 1-PUMPED 50 STKS(4.25 BELS)TO 3,100 PSI FOR 30 CHARTED MINUTES 0 PSI LOST IN 1ST 15 MINS -0 PSI LOST IN 2ND 15 MINS -MIT-IA MEETS BP STP CRT-AK-10-45 CRITERIA -RECIEVED PERMISSION TO PROCEED FROM WTL -BLEED OFF PRESSURE,BLED BACK 4 BBLS -RIG DOWN TEST EQUIPMENT SEE ATTACHMENTS 18:30 - 19:30 1.00 EVAL P DECOMP RELEASE CHAMP PACKER FROM 15,373 MD -WORK PACKER PAST SET DEPTH -ALLOW ELEMENTS TO RELAX -CIRCULATE BOTTOMS UP @ 7 BPM&2510 PSI. -FLOW CHECK,NO FLOW 19:30 - 00:00 4.50 EVAL P DECOMP PULL OUT OF HOLE WITH CHAMP PACKER PULL OUT OF HOLE FROM 15,373 MD -LAYING DOWN 4"DRILL PIPE FROM 15,373 FT TO 12,162 FT. MAINTAIN HOLE FILL TO IA AT 6 BPH OF 9.3 PPG BRINE 24 HR LOSSES=182 BBLS 11/20/2013 00:00 - 07:00 7.00 EVAL P DECOMP SPCC CHECKS AND PRE-TOUR MEETING PULL OUT OF HOLE WITH CHAMP PACKER -PULL OUT OF HOLE FROM 12,162 MD -LAYING DOWN 4"DRILL PIPE 1 X 1 TO PIPE SHED 07:00 - 12:00 5.00 EVAL P DECOMP L/D 2-7/8"6.5#L-80,EUE TBG. -CHANGE HANDLING EQUIPMENT. -PLACE FOSV ON READY RACK. -POH AND L/D TBG WITH THREAD PROTECTORS. -F/580'T/298' 12:00 - 12:30 0.50 EVAL P DECOMP PERFORM PRE-TOUR CHECKS -SERVICE RIG FLOOR EQUIPMENT. 12:30 - 13:30 1.00 EVAL P DECOMP POH L/D TBG -L/D 2-7/8"EUE TBG F/298'TO SURFACE. -MAINTAIN CONTINUOUS HOLE FILL WITH 9.3#BRINE -7 BPH LOSS RATE. 13:30 - 14:00 0.50 EVAL P DECOMP L/D BHA -L/D 7"CHAMP TEST PACKER 14:00 - 14:30 0.50 EVAL P DECOMP CLEAN AND CLEAR RIG FLOOR. -PULL WEAR RING. Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 7 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: 11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum: ng Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 00:00 9.50 RUNCOM P RUNCMP LOAD 4-1/2"L-80,12.6#,IBT-M TBG INTO PIPE SHED. -AMBIENT TEMP=-13 DEG. -REMOVE THREAD PROTECTORS,STRAP AND RABBIT TBG. MAINTAIN HOLE FILL TO IAAT 6 BPH OF 9.3 PPG BRINE 24 HR LOSSES=147 BBLS 11/21/2013 00:00 - 07:00 7.00 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. CONTINUE LOAD 4-1/2"L-80,12.6#,IBT-M TBG INTO PIPE SHED. -REMOVE THREAD PROTECTORS,STRAP AND RABBIT TBG. 07:00 - 12:00 5.00 RUNCOM P RUNCMP PJSM,RUN 4-1/2"COMPLETION. -M/U HES 7"X 4.5"TNT PACKER.BAKER-LOC ALL CONNECTIONS BELOW PACKER. -RIH WITH 4-1/2"L-80,12.6#,IBT-M TBG TO 2717'. -PUW=66 KLBS,SOW=70 KLBS. P/U 1X1 FROM PIPE SHED. -MAINTAIN CONTINUOUS HOLE FILL WITH 9.3 LB BRINE. -M/U TQ=3600-3700 FT-LB. 12:00 - 00:00 12.00 RUNCOM P RUNCMP PJSM,RUN 4-1/2"COMPLETION. -RIH WITH 4-1/2"L-80,12.6#,IBT-M TBG FROM 2717'TO 12797'. -P/U 1X1 FROM PIPE SHED. MAINTAIN CONTINUOUS HOLE FILL WITH 9.3 'LB BRINE. -M/U TQ=3600-3700 FT-LB. MAINTAIN HOLE FILL TO IA AT 6 BPH OF 9.3 PPG BRINE. 24 HR LOSSES=145 BBLS. BP HSSE REP VISIT RIG LOCATION. 11/22/2013' 00:00 - 03:30 3.50 RUNCOM P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. PJSM,RUN 4-1/2"COMPLETION. -RIH WITH 4-1/2"L-80,12.6#,IBT-M TBG FROM 12797'TO 15399'. -P/U 1X1 FROM PIPE SHED. -MAINTAIN CONTINUOUS HOLE FILL WITH 9.3 LB BRINE. -M/U TQ=3600-3700 FT-LB. 03:30 - 04:30 1.00 RUNCOM P RUNCMP PJSM,LAND HANGER WITH FMC. -M/U 4"LANDING JOINT W/FOSV TO FMC 11" X 4-1/2"TUBING HANGER. -PUW=168 K,SOW=91 K -LAND FMC 11"X 4-1/2"HANGER -FMC RUN IN LOCK DOWN SCREWS. -L/D LANDING JOINT. Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 8 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date:11/23/2013 IX3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum:Orig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 07:30 3.00 RUNCOM P RUNCMP PJSM,CIRCULATE COMPLETION FLUID. -PRESSURE TEST SURFACE LINES/3500 PSI. -REVERSE CIRCULATE 265 BBLS OF BRINE WITH CORROSION INHIBITOR. -3 BPH/400 PSI. -FLUSH EACH WAY TO CLEAN BALL SEAT. 07:30 - 08:00 0.50 RUNCOM P RUNCMP M/U LANDING JOINT DROP 2 7/8"ROLLER STEAM BALL,WAIT 15 MIN. 08:00 - 11:00 3.00 RUNCOM P RUNCMP CREW CHANGE PJSM ON SET PACKER AND MIT-IA. -CLOSE BLINDS -WSL/DRILLER/TOOLPUSHER VERIFY VALVE ALIGNMENT. -PRESSURE TEST TBG T/250 PSI F/5 CHARTED MIN.PASSED. -SET TNT PACKER AT 15294'T/3500 PSI F/5 MIN.(32 STROKES) -TEST TBG T/3000 PSI F/30 CHARTED MIN. PASSED. -BLEED TBG TO 2000 PSI. -PRESSURE TEST IA T/3000 PSI F/30 CHARTED MIN.WITH 3.5 BBLS PUMPED. -MIT-IA:FIRST 15 MIN.LOST 15 PSI.SECOND 15 MIN LOST 5 PSI. -MIT-IA TEST MEETS CRT-AK-10-45 CRITERIA OF PASSING TEST. -RECEIVED PERMISSION TO PROCEED F/ WfL JAMES WILLINGHAM. -BLEED OFF AND OBSERVED DCK VALVE SHEAR AT 700 PSI. -PUMP EACH WAY TO VERIFY. -DOWN TBG 3 BPM/1200 PSI. DOWN THE IA 3 BPM/1370 PSI. WSL/DRILLER VERIFY NO TRAPPED PRESSURE,OPEN BLIND RAMS. 11:00 - 12:00 1.00 RUNCOM P RUNCMP PJSM,SET TWC -FMC REP M/U TWC ON RUNNING TOOL. -INSTALL TWC. -TEST F/BELOW 250/2800 PSI AND F/ ABOVE 250/3500 PSI -BOTH CHARTED 5 MIN. 12:00 - 13:00 1.00 RUNCOM P RUNCMP DRAIN BOP STACK 1-BLOW DOWN MANIFOLD AND LINES -R/D CIRCULATION MANIFOLD. 13:00 - 14:30 1.50 RUNCOM P RUNCMP 'PJSM,N/D BOPE -REMOVE MUD RISER REMOVE KILL LINE -N/D BOP AND SET BACK STACK 14:30 - 19:30 5.00 WHSUR P RUNCMP PJSM FOR N/U ADAPTOR FLANGE AND TREE -N/U ADAPTER FLANGE PER FMC REP AND TEST VOID 5000 PSI FOR 30 MINUTES.GOOD TEST. -COLD TEMPERATURES EFFECTING PRESSURE GAUGE. 19:30 - 21:00 1.50 WHSUR P RUNCMP N/U TREE -PRESSURE TEST TREE 250 PSI LOW,5000 PSI HIGH FOR 5 CHARTED MINUTES EACH. i GOOD TEST. Printed 12/2/2013 11:40:52AM North America-ALASKA-BP Page 9 of 9 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:WORKOVER(WO) Start Date:11/16/2013 End Date: 11/23/2013 X3-013YH-C:(1,500,000.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:DOYON 16 Spud Date/Time:9/16/1995 12:00:00AM Rig Release:11/23/2013 Rig Contractor:DOYON DRILLING INC. UWI:500292259900 Active datum:Ong Rig on MPF-78 i47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) - (usft) 21:00 - 23:00 2.00 WHSUR P RUNCMP PJSM,P/U LUBRICATOR AND PULL TWC -TEST LUBRICATOR TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MINTUES EACH. -PULL TWC. -SET BACK LUBRICATOR TO USE FOR SETTING BPV. 23:00 - 00:00 1.00 WHSUR P RUNCMP PJSM,PUMP DIESEL FREEZE PROTECT -R/U LRS AND TEST LINES TO 250 PSI LOW, 13500 PSI HIGH. -REVERSE CIRCULATE 80 BBLS DIESEL DOWN IA AT 3 BPM 1400 PSI. 11/23/2013 00:00 - 01:00 1.00 WHSUR P RUNCMP SPCC CHECKS AND PRE-TOUR MEETING. I I ALLOW DIESEL TO U-TUBE FOR 1 HOUR. 01:00 - 01:30 0.50 WHSUR P RUNCMP PJSM,R/U DSM LUBRICATOR,TEST 250 PSI, 3500 PSI,5 MIN,CHARTED INSTALL BPV,R/D LUBRICATOR. 01:30 - 02:00 0.50 WHSUR P RUNCMP LRS,TEST BPV FROM BELOW -250 PSI,2500 PSI,10 MIN,CHARTED 02:00 - 03:00 1.00 WHSUR P RUNCMP BLOW DOWN ALL CIRCULATING AND TEST LINES. R/D LRS HOT OILERS. -SECURE TREE AND CELLAR AREA -PULL CHANGE TRAILER,FUEL TRAILER, AND CUTTINGS BOX AWAY FROM RIG. -PREP RIG FOR MOVE. -RELEASED FROM MPF-78 FOR MOVE TO MPF-50 AT 03:00 HRS 11-23-2013. II it Printed 12/2/2013 11:40:52AM • MPF-78, Well History (Pre-Rig Sidetrack) Date Summary 11/25/13 T/I/0=200/0/0 Conduct PJSM; Start barriers list=SV&MV Tested independently passed; Rig up Lubricator with Pulling tool;Test to 300 and 3500 psi for 5 min. LTT passed; Open barriers and pulled 4 1/16 CIW"H"BPV#MPP-30 @ 106"w/1-1'ext. Removed second sv and installed SSV torqued and tested. 11/25/13 Assist slickline MIT-IA to 2500 psi. 11/26/13 Assist slickline MIT-IA to 2500 psi. PASS. Lost 8 psi in the first 15 mins and 5 psi in the second. Used 2.75 bbls diesel to reach test pressure. Bled back+/-3 bbls. Final WHPs=175/200/0. 11/26/13 SET BK-DGLV IN ST#1 @ 2493'MD. LRS MIT IA TO 2500psi- PASS(see Irs log for details). PULLED 4 1/2"SSCS FROM 2600'SLM. PULLED B&R AND RHC PLUG BODY FROM X-NIPPLE @ 15331' MD. RAN 3.63"CENT& 1 1/2"S. BAILER,TAGGED TD @ 15778'SLM, RECOVERED FRAC SAND. RAN PDS 40 ARM CALIPER FROM TD TO TUBING TAIL AS PER PROGRAM***GOOD DATA*** CURRENTLY RIH W/20'x 3.70" DRIFT. 11/27/13 DRIFTED TBG W/3.70"x 20' DUMMY WS DRIFT,TAGGED TD @ 15778'SLM, SAW NO RESTRICTIONS.***P/U WEIGHT 1000#@ 15700'SLM*** 11/28/13 RIGGING UP SWCP LL#9. CURRENTLY RIH W/SBHPS AS PER PROGRAM. 11/29/13 RAN SBHPS AS PER PROGRAM***GOOD DATA***. 11/30/13 (ELINE-WHIPSTOCK). INITIAL T/I/O=200/200/0. RIG UP AND PRESSURE TEST. 12/01/13 RUN 1: RIH WITH HEAD(ECRD)/XTRA-B TUFFTRAC/WPP TOOLS/BAKER 10/BAKER WHIPSTOCK. STUCK AT 1670'CANNOT COME FREE. TOP OF WHIPSTOCK HAS BEEN SET AT 1685.98'; CCL DEPTH OF 1670.9'; CCL TO TOP OF WHIPSTOCK= 15.08'. ORIENTATION =73.4 ROHS. DEVIATION 16 DEG. DEPTHS ARE ONLY BASED ON RIH. NO TIE IN PASS WAS ABLE TO BE COMPLETED. FINAL T/I/O=700/300/50. 12/01/13 T/I/0=400/160/50 Assist Eline(Whipstock) Pump 132 bbls 180*diesel in attempt to free up eline. FWHP's=900/300/2 E-line on well at LRS departure. 12/03/13 PULLED WHIP STOCK FROM 1685'MD. RAN 4.5"BLB W/3.73"GAUGE RING.TAGGED BOTTOM @ 15785'SLM. LRS ASSISTED W/PUMPING WHIP STOCK DRIFT DOWN HOLE. RAN 3.70"WHIP STOCK DOWN TO 15600'SLM.S/D MULTIPLE TIMES BUT WORKED THRU. RERUN WHIP STOCK W/O LRS ASSISTING. 12/03/13 T/I/O=650/210/5,Assist SSL(whipstock) Pumped 53 bbls diesel down TBG. 12/04/13 RAN 20'X 3.70"WHIP STOCK DUMMY W/3.5"MAGNET.STOP @ 15400'SLM.RECOVERED HALF OF SET SCREW&SMALL PIECES OF METAL. RAN 20'X 3.70"WHIP STOCK DUMMY W/3.5" MAGNET.S/D @ 15786' SLM.RECOVERED METAL SLIVERS. ***DID NOT DRIFT FREELY DOWN TO TD. SAT DOWN IN 5 SPOTS ON FIRST RUN AND 2 SPOTS ON SECOND RUN***. 12/04/13 T/I/0=650/210/5, Continued job from 12-3-13,Assit SS/L, (Whipstock), pump a total of 55 bbls diesel down tbg to assist ssl down hole. FWHP's=700/200/0 SSL on well at departure. 12/05/13 T/I/0=900/205/0 Load Tbg (whipstock) Pump 290 bbls 1%kcl/Lube 776 followed by 40 bbls 60/40 down tbg for E-line to set whipstock FWHP's=1250/-21/12. Page 1 of 2 MPF-78, Well History (Pre-Rig Sidetrack) Date Summary 12/05/13 (ELINE SET WHIPSTOCK). INITIAL T/I/O=450/100/0. RIH W/ELINE TOOLS&BAKER 4-1/2"x 7" THRU TBG WHIPSTOCK. 12/06/13 SET BAKER 4-1/2"x 7"THRU TBG WHIPSTOCK.TOP SET @ 15,600'(29 DEG LOHS). TWO RA PIP TAGS INSTALLED IN WHIPSTOCK @ 15610'(10' FROM TOWS). (NO ISSUES GETTING DOWNHOLE). (TIED INTO TCP CORRELATION LOG DATED 11-OCT-2006, CONFIRMED ON DEPTH WITH ATLAS TEMP/PRESS LOG DATED 06-NOV-95). FINAL T/I/O=425/100/0. WELL LEFT SI ON DEPARTURE- NOTIFIED PAD OP OF WELL STATUS. 12/28/13 CTU 9 w/1.75"CT. Scope; cement whipstock. standby for well support to rig up..** 12/29/13 CTU#9 1.75"Coil (CV=44.2)Job Objective: P&A perfs. Cement whipstock. Continue to stand by for Well Support to finish re-rig. MIRU, Make up CTC, (2)2"stingers, 2.5"BDJSN (.875" Ball). RU cementers, Pressure test. RIH w/1.9"x.125'CTC, 2"x 4'stinger,2"x 4'stinger,2.1"x.312'x-over,2.5"x.583' BDJSN (Take .875"ball). OAL=9.02' . Load well down CTBS with 350 bbls of 1%kcl and 60 bbls diesel. Tag WS at 15603'.flag pipe at 15590'. perform injectivity test down CTwith kcl. 12/30/13 Scope;cement whipstock. In hole w/1.9"x.125'CTC,2"x 4'stinger,2"x 4'stinger,2.1"x.312'x-over, 2.5"x.583' BDJSN at 15590'(flag). Pump 24 bbls of 15.8 class G cement. Got bump and lay in remaining cement. Perform hesitation squeeze and obtained requested 1000 psi over static pressure. Hold for 30 min. (8.8 bbls behind pipe). Drop ball contaminate down to flag,(3 passes). chase returns @ 80%. Freeze protect well with 60/40 to 2500'ctm. 01/05/14 T/I/0=728/81/0 MIT-T PASSED to 2500 psi. Pump 1.2 bbls 60/40 to reach test pressure 1st 15 min loss of 19 psi, 2nd 15 min loss of 11 psi.Total loss of 30 psi during 30 min test. Bled TBG pressure to 0 psi, FWHP 0/0/0. SV, WV, SSV=Closed, MV, IV, OV=Open. 01/12/14 Set 4"CIW TWC#MP4-11 /Torque flanges/PT tree/Pull TWC. T/I/O=0/0/0 Verified barriers(SV, MV) removed actuated 2nd swab valve and installed manual 2nd swab valve.TQ'd to spec. Installed lubricator and PT'd to 300 low and 5000 high (to test newly installed 2nd swab as well as lubricator)Set TWC and tagged at 110"with 18"extension.Torqued all flanges on tree to spec. PT'd bottom side of swab valve and top of master valve to 300 low and 3500 high. Shell tested tree to 300 low and 5000 high. Pulled TWC and tagged at 105"with 18"extension. Page 2 of 2 • North America-ALASKA-BP Page 1 Alt Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date. X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad 1 Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM !Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292259900 Active datum:Ong Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/5/2014 06:00 - 07:00 1.00 MOB P PRE PREPARE RIG TO MOVE OFF OF WELL MPF-70.PULL MATS,NOTIFY PAD OPERATOR AND HOLD PJSM. 07:00 - 08:00 1.00 MOB P PRE MOVE RIG OFF OF WELL MPF-70.STAGE RIG ON PAD.MOVE MATS FROM MPF-70 TO MPF-78.CLEAN UP AROUND WELL MPF-70. 08:00 - 09:30 1.50 MOB P PRE MOVE RIG OVER WELL MPF-78.SET DOWN AND LEVEL RIG. RIG ACCEPT AT 09:00 HOURS. 09:30 - 10:30 1.00 BOPSUR P PRE OPEN SWAB VALVES AND MASTER VALVE. PERFORM LEAK TIGHT TEST-PASS. 10:30 - 17:00 6.50 BOPSUR P PRE REMOVE TREE CAP.PERFORM NIPPLE UP OPERATIONS.PICK UP REEL.INSTALL HARD LINES AND IRON.INSTALL GRAPPLE AND PREPARE TO PULL COIL OVER INJECTOR. 17:00 - 18:00 1.00 BOPSUR P PRE FILL STACK AND PERFORM SHELL TEST. TEST BOP. 18:00 - 18:30 0.50 BOPSUR P PRE CREW CHANGE,INSPECT RIG EQUIPMENT. 18:30 - 00:00 5.50 BOPSUR P PRE CONTINUE PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,SUNDRY #195-153,AND CRT-AK-10-45 -AOGCC INSPECTOR CHUCK SCHEVE WAIVED WITNESSING THE BOP TEST AT 1700 02/05/14. -TEST IS WITNESSED BY TOOLPUSHER AND WSL. -TEST BOPE TO 250/3500 PSI FOR 5 CHARTED MIN -TEST CHOKE VALVES,CHOKE HCR,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES, BOP RAMS AND ANNULAR PREVENTER. -VBR AND ANNULAR TESTED WITH BOTH 2-3/8"AND 3-1/2"TEST JOINTS -2-3/8"RAMS TESTED WITH 2-3/6"TEST JOINT -3"RAMS TESTED WITH 3"TEST JOINT -TEST FULL OPENING SAFETY VALVES -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS AND DRAW DOWN TEST OF ACCUMULATOR. Printed 2/17/2014 9•52:47AM • North America-ALASKA-BP Page 24f4 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA I UWI:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/6/2014 00:00 - 05:30 5.50 BOPSUR P PRE CONTINUE PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,SUNDRY #195-153,AND CRT-AK-10-45 AOGCC INSPECTOR CHUCK SCHEVE WAIVED WITNESSING THE BOP TEST AT 1700 02/05/14. -TEST IS WITNESSED BY TOOLPUSHER AND WSL. -TEST BOPE TO 250/3500 PSI FOR 5 CHARTED MIN TEST CHOKE VALVES,CHOKE HCR,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES, BOP RAMS AND ANNULAR PREVENTER. -VBR AND ANNULAR TESTED WITH BOTH 2-3/8"AND 3-1/2"TEST JOINTS -2-3/8"RAMS TESTED WITH 2-3/8"TEST JOINT -3"RAMS TESTED WITH 3"TEST JOINT -TEST FULL OPENING SAFETY VALVES -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS AND DRAW DOWN TEST OF ACCUMULATOR. 05:30 - 06:00 0.50 BOPSUR P PRE RIG EVACUATION DRILL HOLD RIG EVACUATION DRILL WITH ALL PERSONNEL. -GATHER UP IN SAFET BRIEFING AREA. ALL PERSONNEL ACCOUNTED FOR. -HOLD AAR WITH NO SIGNIFICANT FINDINGS. 06:00 - 11:30 5.50 BOPSUR P PRE PRESSURE TEST MPD LOOP -PRESSURE TEST MANAGED PRESSURE DRILLING LOOP AND LUBRICATOR. -PRESSURE TEST SWACO AUTOMATIC CHOKE. -PRESSURE TEST WING ASSEMBLY. 11:30 - 12:00 0.50 1 BOPSUR P I I PRE PREPARE TO PULL COIL -RIG UP TO PULL COIL OVER TOP OF RIG. 12:00 - 12:30 0.50 BOPSUR P PRE PRE JOB SAFETY MEETING -HOLD PJSM FOR PULLING COIL OVER TOP OF RIG. • 12:30 - 13:00 0.50 BOPSUR P PRE PULL COIL OVER TOP OF RIG. -LINE UP TUGGER LINE TO GRAPPLE ON COIL PULL COIL OVER TOP OF RIG. 13:00 - 14:00 1.00 BOPSUR P PRE TEST ELINE -TEST CONDUCTIVITY OF ELINE -REHEAD LUBRICATOR SLICK LINE,NOT ENOUGH LINE WILL NEED TO LOAD MORE LINE. CHANGE OUT PACKOFF. 14:00 - 16:00 2.00 BOPSUR P PRE CIRCULATE COIL -CIRCULATE 10 BBLS MEOH -CIRCULATE COIL WITH FRESH WATER. -ADD WIRE TO LUBRICATOR SLICK LINE AND RE-HEAD. 16:00 - 16:30 0.50 BOPSUR P PRE RIG EVACUATION DRILL -HOLD RIG EVACUATION WITH MAN DOWN DRILL WITH ALL PERSONNEL. GATHER UP IN SAFET BRIEFING AREA. ALL PERSONNEL ACCOUNTED FOR. -HOLD AAR WITH NO SIGNIFICANT FINDINGS. Printed 2/17/2014 9:52:47AM North America-ALASKA-BP Page 3 oR10 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:30 - 17:00 0.50 BOPSUR P PRE TEST INNER REEL VALVE -TEST INNER REEL AND PACKOFF. 17:00 - 18:00 1.00 BOPSUR • P PRE BLOW BACK COIL -BLOW BACK COIL -RE-HEAD BHI 18:00 - 19:30 1.50 BOPSUR j P • PRE TEST CHECKS -PRESSURE TEST DUAL FLAPPER CHECK • • VALVES. • -CREW CHANGE 19:30 20:30 • 1.00 BOPSUR P ' PRE TEST BAKER TOOL CONNECTIONS 20:30 - 21:00 0.50 BOPSUR P PRE •CIRCULATE COIL —CIRCULATE TO WARM COIL -TROUBLESHOOT MI SWACO SUPER CHOKE 21:00 - 22:30 1.50 BOPSUR P PRE TEST NIGHT CAP -250/3500 PSI-GOOD -CONTINUE TROUBLESHOOTING ON CHOKE 22:30 - 00:00 1.50 BOPSUR N SFAL PRE PJSM -CHANGE OUT HYDRAULIC PUMP, AND SUPER CHOKE 2/7/2014 00:00 - 18:00 18.00 BOPSUR N SFAL PRE WORKING ON SWACO AUTOCHOKE -TROUBLESHOOTING SWACOAUTOCHOKE. SWACO PERSONNEL HOURED OUT, RETURN TO CAMP TO RESET. -ORDER OUT NEW CHOKE PANEL. -ORDER REPLACEMENT PARTS FROM TOWN AND WILL ARRIVE EARLY EVENING. -DIAL IN SETTINGS ON CHOKE AND ATTEMPT REPEATEDLY TO RESTORE PRESSURE FUNCTION. 18:00 - 18:30 0.50 BOPSUR N SFAL PRE CREW CHANGE 1-WAIT FOR MI SWACO TO REPAIR SUPER CHOKE. 18:30 - 22:00 3.50 BOPSUR N SFAL PRE PJSM -REBUILD SWACO AUTOCHOKE. • 22:00 - 23:30 1.50 BOPSUR N SFAL PRE !TEST SWACO AUTOCHOKE 250/3500 PSI. (CHARTED) • 23:30 - 00:00 0.50 BOPSUR N SFAL PRE I TEST AUTOCHOKE FLANGE CONNECTIONS 250/3500 PSI. -REPAIR AIR PUMP. 2/8/2014 00:00 - 01:15 1.25 BOPSUR N SFAL PRE TEST SUPER CHOKE FLANGE CONNECTION BREAKS 250/3500 PSI. • 01:15 - 02:30 1.25 STWHIP P PROD1 PJSM -PICK UP MILLING BHA. -GAUGE MILLS WINDOW MILL 3.80 GO,3.79 NO GO;STRING MILL 3.81 GO,3.80 NO-GO -STAB ON INJECTOR.TEST QTS 250/3500 PSI.PASSED 02:30 - 08:00 5.50 STWHIP P PROD1 RIH WITH MILLING BHA FROM SURFACE PUMPING AT 0.31 BPM WITH 200 PSI. TAKE RETURNS TO TIGER TANK. MEASURE TIGER TANK VOLUME EVERY 2000 FT. LOG TIE IN W/-57'CORRECTION. 08:00 - 10:00 2.00 STWHIP P PROD1 MILL CEMENT -TAG CEMENT AT 15,593'MD. -TOP OF WINDOW SLIDE 15,598.4'MD,4.6' FROM PINCH POINT. MILL CEMENT TO 15,603'MD. MILL AT 2.65 BPM WITH 3230 PSI. ANNULAR PRESSURE 4420 PSI. CHOKE PRESSURE 530 PSI. Printed 2/17/2014 9:52:47AM • North America-ALASKA-BP Page 4 t19.48 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:00 - 18:30 8.50 STWHIP P PROD1 MILL WINDOW Lj L -MILL WINDOW PER PLAN SCHEDULE TO �l 15,610'MD. Indf-14A -MILL FROM TOP OF WINDOWAT 15,603'TO 15,610'MD,THIS ISA7'WINDOW. NO STALLS DURING MILLING OPERATION -MILL AT 2.7 BPM WITH 3380 PSI. ANNULAR PRESSURE 4420 PSI,CHOKE PRESSURE 450 PSI. -WOB 2.5K WITH 11K DOWN WEIGHT. -VOLUME 143 BBL,IA=700 PSI,OA=100 PSI. -MUD WEIGHT IN AND OUT 9.2 PPG. 18:30 - 22:30 4.00 STWHIP P PROD1 DRILL 10'RATHOLE FROM 15,610'TO 15,620' MD. REAM AND DRY DRIFT WINDOW. -SAMPLES OFF BOTTOM SHOW GOOD FORMATION. 22:30 - 00:00 I 1.50 STWHIP P PROD1 I PULL OUT OF HOLE WHILE DISPLACING WELL TO 11.8 PPG BRINE FOLLOWING PRESSURE SCHEDULE. 2/9/2014 00:00 - 02:00 2.00 s STWHIP P PROD1 CONTINUE TO POH WHILE DISPLACING WELL TO 11.8 PPG BRINE FOLLOWING PRESSURE SCHEDULE. FLOWCHECKAT SURFACE. 02:00 - 02:45 0.75 STWHIP P PROD1 PJSM. POP OFF INJECTOR,UNSTAB COIL, AND L/D MILLING BHA. GAUGE MILLS. WINDOW MILL-3.79 GO,3.78 NO-GO. STRING MILL-3.80 GO,3.79 NO-GO. STAND INJECTOR ON LEGS. 02:45 - 04:30 ' 1.75 DRILL P PROD1 PJSM. M/U BUILD BHA. MAKE UP SLICK LINE LUBRICATOR. RUN BHA UP AND DOWN THROUGH SLICK LINE LUBRICATOR 2 X TO VERIFY THAT IT CAN BE PRESSURE UN-DEPLOYED. BHA DID PULL THROUGH, BUT PULLED TIGHT IN SEVERAL SPOTS. 04:30 - 05:30 1.00 DRILL P PROD1 PULL BUILD BHA OUT OF HOLE AND HANG OFF. MAKE UP LONG MPD LUBRICATOR. PICK UP AND STAB INJECTOR. PRESSURE TEST LUBRICATOR. POP OFF INJECTOR. 05:30 - 09:45 4.25 DRILL P PROD1 RUN BUILD BHA BACK IN HOLE. STAB COIL. GET ON WELL. TEST QTS.RIH WITH BUILD BHA.RUN AT 75 FPM WITH 15K DOWN WEIGHT.PUMP AT 1.65 BPM WITH 1300 PSI. START 9.2 PPG MUD DOWN HOLE TO DISPLACE THE KWF OF 11.8 PPG. 09:45 - 10:00 0.25 DRILL P PROD1 LOG TIE-IN AT 15,545'MD AT 1.5 FPM WITH 13K DOWN WEIGHT.PUMP AT 1.7 BPM WITH 1770 PSI.LOG CORRECTION OF MINUS 47'. 10:00 - 11:30 1.50 DRILL P PROD1 I DISPLACE 11.8 PPG KILL WEIGHT FLUID WITH 9.2 PPG DRILLING FLUID.PUMP AT 2.65 BPM WITH 2990 PSI.FINISH DISPLACEMENT.SHUT DOPWN AND TRAP 990 PSI PRESSURE. CLOSE EDC AND TAKE SLOW PUMP RATES. MOVE THROUGH WINDOW WITH NO PROBLEMS. 11:30 - 15:30 4.00 DRILL P PROD1 DIRECTIONAL DRILL AHEAD AT 2.7 BPM WITH 3391 PSI,FREE SPIN 3325 PSI.WOB 1K WITH 16K DOWN WEIGHT.ANNULAR 4488 PSI AND .11.84 ECD. Printed 2/17/2014 9:52:47AM North America-ALASKA-BP Page 5 oat? Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: ,X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:30 - 18:00 2.50 DRILL P PROD1 DIRECTIONAL DRILL AHEAD FROM AT 2.7 BPM WITH 3385 PSI.WOB 1.8K WITH 10K DOWN WEIGHT.ECD 11.8 PPG,4500 PSI ANNULAR AND 420 PSI CHOKE PRESSURE. 18:00 - 21:00 3.00 DRILL P PROD1 ,DIRECTIONAL DRILL BUILD SECTION FROM 15833'TO 15940'MD AHEAD AT 2.76 BPM WITH 3385 PSI.WOB 1.4K.ECD 11.8 PPG, 4525 PSI ANNULAR AND 403 PSI CHOKE PRESSURE 21:00 - 23:00 2.00 DRILL P PROD1 DISPLACE WELL TO 11.8 PPG BRINE TO TOP OF WINDOW. PUMPING 2.7 BPM W/3168 PSI. ECD 11.9 PPG,CHOKE PRESSURE 300 PSI 23:00 - 00:00 1.00 DRILL P PROD1 POOH FOR BHA SWAP. 2/10/2014 00:00 - 02:45 2.75 DRILL P PROD1 CONTINUE TO POH W/BUILD BHA. TAG UP. FLOW CHECK WELL. POP OFF INJECTOR. 02:45 - 03:15 0.50 DRILL P PROD1 PJSM. LAY DOWN BUILD BHA. BIT GRADED 3-2. 03:15 - 03:45 0.50 DRILL P PROD1 MAKE UP LATERAL BHA. STAB COIL. GET ON WELL. TEST QTS 250/3500. 03:45 - 06:45 3.00 DRILL P PROD1 RIH W/LATERAL BHA TO 15,390'MD. 06:45 - 08:00 1.25 DRILL P PROD1 LOG LONG TIE-IN FROM 15,390'MD TO 15,590' MD.LOG AT 3 FPM WITH 15K DOWN WEIGHT. PUMP AT 0.7 BPM WITH 275 PSI.LOG CORRECTION OF MINUS 52'. 08:00 - 08:30 0.50 DRILL P PROD1 DISPLACE WELLBORE OVER FROM 11.8 PPG BRINE TO 9.2 PPG DRILLING FLUID.PUMP AT 1.5 BPM WITH 2015 PSI. 08:30 - 12:00 3.50 DRILL P PROD1 DIRECTIONALLY DRILL AHEAD IN LATERAL SECTION TO 16,170'MD AT 65 FPH.PUMP AT 2.5 BPM WITH 3370 PSI.WOB 4.4K WITH 8K DOWN WEIGHT.ECD 11.8 WITH 4510 PSI ANNULAR AND 340 PSI ON CHOKE.PERFORM FLOW CHECK DUE TO INCREASE IN PIT VOLUME.WELL STATIC WITH PIT GAIN IDENTIFIED AS CENTRIFUGE BEING TURNED 'OFF.NO LOSSES TO WELL. 12:00 - 16:00 4.00 DRILL P PROD1 DIRECTIONALLY DRILL AHEAD IN LATERAL SECTION TO 16,401'MD AT 58 FPH.PUMP AT 2.6 BPM WITH 3820 PSI.WOB 4.6.ECD 11.8 WITH 4543 PSI ANNULAR AND 340 PSI ON CHOKE.MUD WEIGHT IN AND OUT 9.5 PPG. 16:00 - 17:45 1.75 DRILL P PROD1 PERFORM WIPER TO WINDOW AT 15,610'MD. PULL AT 29 FPM WITH 4.4K UP WEIGHT.PUMP AT 2.55 BPM WITH 3360 PSI.MAD PASS FROM 15,950'MD TO WINDOW.MAD PASS AT 4 FPM WITH 43K UP WEIGHT. 17:45 - 18:00 0.25 DRILL P PROD1 LOG TIE-IN AT 2 FPM WITH 10K DOWN WEIGHT.PUMP AT 0.9 BPM WITH 1720 PSI. LOG CORRECTION OF PLUS 1.5'. 18:00 - 18:30 0.50 DRILL P PROD1 RUN IN HOLE AT 35 FPM WITH 12K DOWN WEIGHT.PUMP AT 2.65 BPM WITH 3500 PSI. 18:30 - 00:00 5.50 DRILL P PROD1 DRILL LATERAL SECTION FROM 16402'TO 16616'MD. CIRC RATE:2.57 BPM CIRC PRESSURE:3552 PSI FREE SPIN: 3384 PSI WOB:3.0-4.3 KLBS ECD:11.90 CHOKE PRESSURE:401 PSI ANNULAR PRESSURE:4603 PSI PVT/IA/OA:235/150/120 MW:9.22 PPG Printed 2/17/2014 9:52'47AM • North America-ALASKA-BP Page 6 cf+. Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor NORDIC CALISTA UWI:500292259900 Active datum:Orig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/11/2014 00:00 - 04:15 4.25 DRILL P PROD1 DRILL LATERAL SECTION FROM 16616'TO 16850'MD. CIRC RATE:2.57 BPM CIRC PRESSURE:3552 PSI FREE SPIN: 3384 PSI WOB:3.0-4.3 KLBS ECD:11.90 CHOKE PRESSURE:401 PSI ANNULAR PRESSURE:4603 PSI PVT/IA/OA:235/150/120 MW:9.22 PPG 04:15 - 06:00 1.75 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 16850'MD AT 20 FPM,PUMPING 2.60 BPM W/3365 PSI. AT WINDOW OPEN EDC AND JET 7"CASING TO 4-1/2"TUBING AT 15,300'PULLING AT 25 FPM PUMPING 3.0 BPM W/3150 PSI. NO ISSUES GOING THROUGH SHALES BELOW WINDOW. 06:00 - 09:00 3.00 DRILL P PROD1 RUN IN HOLE THROUGH WINDOW. ENCOUNTER TIGHT HOLE AT 15,647'MD. WORK DOWN TO 15,655 MD WITH DIFFICULTY.TAKING WEIGHT AND STACKING UP.ATTEMPT SEVERAL TIMES WITH DIFFERENT PUMP RATES,NO GO.DECREASE PUMPS TO 0.3 AND TRY DIFFERENT TOOL FACES STILL UNABLE TO WORK THROUGH. SUSPECT TROUBLE IS SHALES.LOG SHOWS 3 SECTIONS FROM 15,610'MD RIGHT OUT OF THE WINDOW TO 15,650'MD,THEN 15,670' MD TO 15,680'MD,THEN 15,700'MD TO 15,730'MD. PULL UP TO WINDOW,BRING TOOLFACE TO AS DRILLED.BRING PUMPS UP TO DRILLING RATE OF 2.6 BPM WITH 3500 PSI,ANNULAR AT 4570 PSI WITH 375 PSI CHOKE PRESSURE. GO DOWN AT 10 FPM AND ABLE TO GO THROUGH UPPER SHALE.WORK DOWN THROUGH TO 15,750'MD WITH NO ADDITIONAL PROBLEMS. PULL BACK UP TO WINDOW AND GO BACK DOWN WITH NO PROBLEMS THROUGH UPPER SHALES BUT ENCOUNTER TIGHT SPOT AT THE LOWER SHALES OF 15,730'MD. WIPE AND ABLE TO WORK THROUGH. RUN IN HOLE TO BOTTOM AT 20 FPM WITH 10K DOWN WEIGHT.PUMP AT 2.5 BPM WITH 3300 PSI.MUD WEIGHT IN AND OUT 9.3 PPG. ANNULAR PRESSURE 4585 PSI WITH 385 PSI CHOKE PRESSURE,ECD 11.85. 09:00 - 13:00 4.00 DRILL P PROD1 DRILL AHEAD TO TD.PUMP AT 2.6 BPM WITH 3550 PSI.WOB 2-4K WITH 5K DOWN WEIGHT. ANNULAR PRESSURE 4575 PSI,CHOKE PRESSURE 380 PSI AND ECD OF 11.92. DRILL TO 17,055 13:00 - 15:00 2.00 DRILL P PROD1 WIPER TRIP TO WINDOW. 3600 PSI AT 2.55 BPM. SMOOTH UP TO WINDOW. OPEN EDC. CLEAN OUT TO TBG TAIL AT 15,402' Printed 2/26/2014 11:12:53AM North America-ALASKA-BP Page 7 of$13.1 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292259900 Active datum:Orig Rig on MPF-78 @47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 17:00 2.00 DRILL P PROD1 CLOSE EDC. BEGIN WIPER IN HOLE. SET DOWN IN SHALE INTERVALS AT 15,629', 15,671',15,740'. WORK THROUGH EACH INTERVAL BY PUMPING AT 2.3 BPM AND COIL RUNNING SPEED OF 9-10 FPM. ADDITIONAL TROUBLE SPOT AT 16,670'. CALL TD AT 17,060'DUE TO HOLE CONDITIONS. 17:00 - 18:30 1.50 DRILL P PROD1 WIPER TRIP BACK TO WINDOW. OPEN EDC NEAR WINDOW. BEGIN OVERPULLING. RUN BACK IN HOLE. CLOSE EDC.CIRCULATE UP THROUGH WINDOW AT 1.0 BPM. HOLE CLEANED UP. MAKE 100'JOG IN 7". OPEN EDC. 18:30 - 23:00 4.50 DRILL P PROD1 WIPER TRIP TO SURFACE. -60'/MIN PUMPING AT 3.47/3.17 BPM IN/OUT WITH 3842 PSI -FOLLOW MPD PRESSURE SECHEDULE FOR TRIPPING OUT 23:00 - 00:00 1.00 DRILL P PROD1 RUN BACK IN HOLE FROM SURFACE TO 4400' MD 90'/MIN PUMPING AT 2.85/3.43 BPM IN/OUT WITH 3347 PSI -FOLLOW MPD PRESSURE SECHEDULE FOR TRIPPING IN 2/12/2014 00:00 - 02:00 2.00 DRILL P PROD1 CONTINUE RUN IN HOLE FROM 4400'MD TO 15,500'MD -90'/MIN PUMPING AT 2.85/3.43 BPM IN/OUT WITH 3347 PSI -FOLLOW MPD PRESSURE SECHEDULE FOR TRIPPING IN 02:00 - 02:45 0.75 DRILL P PROD1 TIE-IN TO FORMATION WITH+2'CORRECTION CONTINUE RUN IN HOLE TO 15,575'MD LOG CCL UP TO 15,200'MD FOR TOL PICK CONTINUE RUN IN HOLE TO WINDOW,CLOSE EDC 02:45 - 04:30 1.75 DRILL P PROD1 CONTINUE WIPER FROM WINDOW TO TD -25'/MIN PUMPING AT 2.5 BPM HOLDING AS DRILLED TOOL FACE -STACK WEIGHT AND HAVE TO WORK THROUGH TROUBLE SHALES FROM 15,655' TO 15,720' -CONTINUE RUN IN HOLE -STACK WEIGHT AND HAVE TO WORK THROUGH TROUBLE SHALES FROM 16,675' TO 16,730' -REDUCE PUMP RATE FROM 2.5 BPM TO 1.8 BPM AND INCREASE DOWNHOLE PWD PRESSURE FROM 4600 PSI TO 4700 PSI,SEE IMPROVEMENT IN HOLE CONDITION -CONTINUE RUNNING IN HOLE TO TD AND TAG AT 17,061'MD.PICK UP AND CONFIRM TAG AT 17,060'MD. -SLOWLY RECIPROCATE COIL WHILE PUMPING LINER RUNNING PILL TO BIT Printed 2/26/2014 11:12:53AM North America-ALASKA-BP Page 83-• Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:OOAM :Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292259900 Active datum:Orig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) i (usft) 04:30 - 05:00 0.50 DRILL P PROD1 1POOH LAYING IN 9.2 PPG LINER RUNNING PILL WITH 1.5 PPB ALPINE BEADS FROM TD TO WINDOW -25'/MIN PUMPING AT 0.8 BPM -FOLLOW MPD PRESSURE SECHEDULE FOR TRIPPING OUT _ 05:00 - 06:00 1.00 DRILL P PROD1 PULL INTO WINDOW AND OPEN EDC PULL OUT OF HOLE WHILE DISPLACING WELL TO 11.8 PPG NABR BRINE FROM WINDOW TO SURFACE -60'/MIN PUMPING AT 2.75 BPM -FOLLOW MPD PRESSURE SCHEDULE FOR LAYING IN KWF TO SURFACE 06:00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS AND EQUIPMENT STATUS. MAKE FLUID CHECKS AND RIG ROUNDS. '1 CONTINUE TO POOH. 06:30 - 10:00 3.50 DRILL P ' PROD1 'CONTINUE TO POOH. CIRCULATE 11.8 PPG BRINE IN TO WELL. 1:1 RTNS. HOLD PJSM NEAR SURFACE. 10:00 - 11:00 1.00 DRILL P PROD1 TAG UP. FLOW CHECK WELL. GET OFF WELL. UNSTAB COIL. STANDBACK/LD BHA TOOLS. HYCALOG 3.75" BIT GRADED 1-1 2/15/2014 18:00 - 20:30 2.50 WHIP •N DPRB 15,641.00 WEXIT PJSM AND PICK UP CALLIPER LOGGING TOOL -PU INJECTOR AND MAKE UP LUBRICATOR EXTENSION,TEST UPPER OTS TO 3500/250 PSI FOR 5/5 MIN -PU BHI SMART TOOLS AND MU CALLIPER TOOL,SURFACE FUNCTION CALLIPER TO START TIMER -STAB COIL,GET ON WELL,TEST LOWER QTS TO 3500/250 PSI FOR 5/5 MIN 20:30 - 00:00 3.50 WHIP N DPRB 15,641.00 WEXIT RIH WITH CALLIPER LOGGING TOOL TO 15,250'MD j-80'/MIN PUMPING 0.6 BPM THROUGH PORTED X-OVER 2/16/2014 100:00 - 02:00 2.00 WHIP N DPRB 15,641.00 WEXIT CONTINUE RIH WITH CALLIPER BHA FROM 15,250' -LOG GR FORMATION TIE-IN,-56' CORRECTION -TAKE UP WT ABOVE WINDOW,UP WT=45K, BREAK OVER=49K RUN INTO OPEN HOLE TO 15,640' -WAIT FOR TIMER TO COMMENCE LOGGING RUN 02:00 - 02:30 0.50 WHIP N DPRB 15,641.00 WEXIT LOG UP FROM 15,640'TO 15,200' -18'/MIN PUMPING 0.6 BPM THROUGH PORTED X-OVER -LOG 40 ARM CALLIPER AND CCL 02:30 - 05:30 3.00 WHIP N DPRB 15,641.00 WEXIT POOH FROM 15,200'TO SURFACE -FLOW CHECK PRIOR TO POOH,NO FLOW -60'/MIN TO 10,000',THEN 100'/MIN TO SURFACE -FLOW CHECK AT SURFACE,NO FLOW 05 30 06:00 0.50 WHIP N DPRB 15,641.00 WEXIT PJSM AND LAY DOWN CALLIPER BHA Printed 2/26/2014 11:12:53AM North America-ALASKA-BP Page 9 r/R-23 Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292259900 Active datum:Orig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -- -- - ---- --- 06:00 - 06:30 0.50 WHIP N DPRB 15,641.00 WEXIT CREW CHANGE. DISCUSS CURRENT AND PAST OPERATIONS. CHECK RIG EQUIPMENT AND FLUIDSNOLUMES. CONTINUE TO LAY DOWN LOGGING ASSEMBLY. 06:30 - 07:00 0.50 WHIP N DPRB 15,641.00 WEXIT LAY DOWN/STANDBACK BHA. REMOVE PDS TOOLS FROM FLOOR. 07:00 - 12:30 5.50 WHIP N DPRB 15,641.00 WEXIT DOWN LOAD CALIPER DATA. TRANSMIT DATA FOR PROCESSING. EVALUATE DATA.NO CEMENT FOUND IN 7" LINER. DETERMINE LINER INTERVAL AT 15,575 IS ADEQUATE TO ANCHOR REPLACEMENT4-1/2 X 7"BAKER WHIPSTOCK 12:30 - 13:30 1.00 WHIP N DPRB 15,641.00 WEXIT MU WHIPSTOCK AND SETTING TOOL ON 'INTEQ MWD TOOLS. STAB COIL. TEST TOOLS. GET ON WELL. PRESSURE TEST QTS TO 2500 AND 3500 PSI. GOOD TEST. CHART SAME. 13:30 - 18:00 4.50 WHIP N ' DPRB , 15,641.00 WEXIT RUN IN HOLE. CIRC AT MIN RATE THROUGH OPEN EDC. CONTINUE TO TREAT BRINE TO RESTORE 11.8 PPG WEIGHT TO SYSTEM. _ 18:00 - 19:00 1.00 WHIP! N DPRB 15,641.00 WEXIT ALLOW FOR CREW CHANGE AND PRE-TOUR WALKAROUNDS !CONTINUE RUNNING IN HOLE WITH WHIPSTOCK BHA -LOG TIE-IN WITH-54'CORRECTION,ORIENT WHIPSTOCK TO 30°LOHS. 19:00 - 19:30 0.50 WHIP N DPRB 15,641.00 WEXIT SET WHIPSTOCK -CONTINUE RIH TO 15,575',PU TO NEUTRAL WT,CLOSE EDC -BRING PUMPS UP TO 1.45 BPM AND 2900 PSI,SET WHIPSTOCKAT30°LOHS. -SET 5K DOWN TO CONFIRM WHIPSTOCK SET. 19:30 - 22:30 3.00 WHIP N DPRB ' 15,641.00 WEXIT POOH WITH WHIPSTOCK BHA. -FLOW CHECK JUST ABOVE WHIPSTOCK NO FLOW -POOH 60'/MIN TO 10,000',100'/MIN TO SURFACE -FLOW CHECK ON SURFACE,NO FLOW. 22:30 - 23:30 1.00 WHIP N DPRB 15,641.00 WEXIT PJSM AND LAY DOWN WHIPSTOCK RUNNING BHA 1-POP OFF,UNSTAB COIL,MOVE INJECTOR OVER BUNHOLE -PICK UP BHAAND BREAK OFF BTT WHIPSTOCK RUNNING TOOL -LAY DOWN BHA 23:30 - 00:00 0.50 WHIP N DPRB 15,641.00 WEXIT PJSM AND PERFORM SLACK MANAGEMENT -STAB ON WELL,CLOSE SWABS,AND PUMP BACK E-LINE SLACK Printed 2/26/2014 11:12:53AM North America-ALASKA-BP Page 10 ote3., Operation Summary Report Common Well Name:MPF-78 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/5/2014 End Date: X3-013YH-C:DRILL(2,195,935.00) Project:Milne Point Site:M Pt F Pad Rig Name/No.:NORDIC 2 Spud Date/Time:9/16/1995 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292259900 Active datum:Orig Rig on MPF-78©47.54usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/17/2014 00:00 - 04:00 4.00 WHIP N DPRB 15,641.00 WEXIT CONTINUE SLACK MANAGEMENT -POP OFF WELLAND CUT 27'COIL -MEG AND OHM TEST E-LINE,TESTS GOOD -DRESS COIL END AND INSTALL CTC,PULL TEST TO 33K -HEAD UP BAKER,MEG AND OHM TEST, TESTS GOOD -PRESS TEST CTC TO 250/3500 PSI FOR 5/5 MIN,GOOD TEST STAB ON WELLAND PUMP SLACK FORWARD -PRESS TEST BAKER CHECKS TO 250/3500 PSI FOR 5/5 MIN,GOOD TEST -POP OFF WELLAND MOVE OVER BUNG HOLE 04:00 - 05:00 1.00 STMILL N DPRB 15,641.00 WEXIT PJSM AND PICKUP WINDOW MILL BHA -PU 3.80"WINDOW MILL WITH DIAMOND STRING REAMER AND X-TREME MOTOR -WSL VERIFY MILL GAGE,3.80"GO,3.79" NO-GO -PICK UP BAKER MWD TOOLS AND MAKE UP MILL -STAB COIL AND STAB ON WELL TEST LOWER QTS TO 250/3500 PSI FOR 5/5 MIN,TEST GOOD 05:00 - 06:00 1.00 STMILL N DPRB 15,641.00 WEXIT RIH WITH WINDOW MILL BHA -100'/MIN PUMPING 1.08 BPM THROUGH OPEN EDC 06:00 - 06:30 0.50 STMILL N I DPRB 15,641.00 WEXIT CREW CHANGE. DISCUSS CURRENT OPERATIONS AND EQUIPMENT/FLUID STATUS. MAKE RIG CHECKS AND ROUNDS. CONTINUE TO RUN IN HOLE WITH MILLING BHA. 06:30 - 08:00 1.50 STMILL N DPRB 15,641.00 WEXIT LOG GR TIE IN FROM 15,300'. SUBTRACT 56' CORRECTION. 08:00 - 09:30 1.50 STMILL N DPRB 15,641.00 WEXIT DISPLACE WELL TO 9.2 PPG FLO VIS. MAINTAIN 4500 PSI BHA DURING DISPLACEMENT. 09:30 - 15:00 5.50 STMILL N DPRB 15,641.00 WEXIT RIH.TAG WHIPSTOCK AT 15,559'. MILL AHEAD FROM 15,559'. -3163 PSI FS AT 2.53 BPM IN/OUT. 200-250 PSI MTR WORK. -1.31 K#WOB. IA/OA:0 PSI/61 PSI. PVT:111 BBLS. -WHP/BHP/ECD:352 PSI/4510 PSI/12.11 PPG -TIME MILL AHEAD AT 0.1'INCREMENTS PER 6 MIN. -11:22 AT 15,559.2'MD,MOTOR STALL.PICK UP.RESUME MILLING TO 15,561.3'MD. 15:00 - 18:00 3.00 STMILL N DPRB 15,641.00 WEXIT CONTINUE TO MILL AHEAD FROM 15,561.3'. -3110 PSI FS AT 2.53 BPM IN/OUT. 200-250 PSI MTR WORK. -3.2-3.7K#DHWOB. -18:00 AT 15,561.6'MD,DHWOB BUILD TO 4.7K,MOTOR WORK ONLY 50-75 PSI. -PICK UP TO NOT EXCEED MAX WEIGHT ON MOTOR. Printed 2/26/2014 11:12:53AM Tree: Cameron 2 9/16" 5M Orig. K elev. = 47.54' (N 27E) Wellhead: 11" x 11" 5M FMC Gen MPU F-78 Orig. GL. elev. = 12_2: 5, w/2 7/8" FMC tbg. hng., 2 7/8" u RT To Tbg. Spool = 32.78 (N 27E) EUE 8 rd on top and bottom, 2.5" CIW BPV profile 20" 91.1 ppf, NT8OLHE 113' KOP @ 500' • Max. hole angle = 72 to 74 deg.f/ 4100'- 12,500'. Hole angle through perfs= 33 deg. 9 5/8", 40 ppf, L-80 Btrc. 7919' A TUBING DATA: 4-1/ u, la.a-s,,.-so WoQ re j TeAm. CASING DATA: 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. =0.0383 bpf) Tandem Seal Section GSB3DBFERHL H6 SSCV SBSB PFSA Stimulation Summary 11/15/95 -37M # 16/20 behind pipe, screened out to surface. 04/07/96 - Re-frac- 123.5 M# 16/20 r - X -I/2.4 T+l"/r Pkv- 152' behind pipe. Perforation Summary \ -Y24 1241 00 15391 Ref log: 11/06/95 CCUGR/Press Size SPF Interval (TVD) Kup'B'Sand _ 2.4116 44*1P kAz/4/t4) 1555V 4.5" 5 15,590'-15,604' (7313'-7323') 441 Intake- 15,433' MD = 7,194' TVD 32 gm AlphaJet charges (EHD =0.50", TTP =32.0") @35/ 145 deg. phasing k.�`��r�1N Mid perf=7371'TVD �•••♦e Size SPF Interval (TVD) 15663' and - WirtPriutl-- (t2 U0/1.3J 15("CO Kup'A Sand 3-3/8" 6 15,649'-15,737' (7360'-7430') y..♦.'.. Re-Perfs 10/13/06 1 Fish: 27-E lost a 5/16" socket 1" 4.5" 5 15,670'-15,690' (7374'-7390') 4.5" 5 15,700'-15,730' (7398'-7421') +.♦.''.� long down hole 4/12/96. Jumbo Jet"Big Hole" charges @ 60 . 7534'TVD deg. phasing, EHD = 0.76",TTP = 6.4" t�.•••• 15,959' P 9� ,.__. __ 7" Float collar(PBTD) 7" , 26 ppf, L-80, BTC shoe 16,042' DATE REV BY COMMENTS 10/03/95 JBF Cased Nabors 27E/ 4/10/96 Completion 4ES 07/11/96M. Linder RWO by Polar/ 7/18/97 RWO 4 Es MILNE POINT UNIT 06/26/98 MDO ESP RWO Nabors 5S/ 5/19/99 RWO 4 es WELL F-78 10/11/01 B. Hasebe ESP RWO w/Nabors 4ES API NO: 50-029-22599 10/14/06 REH 4ES RWO w/RE-PERF BP EXPLORATION (AK) * • • oF r„, THE STATE Alaska Oil and Gas ` ' ' fALAs a c Icy f®n Com j d iss stn jtritt GOVERNOR SEAN PARNELL .,r,,,, 333 West Seventh Avenue (( R Anchorage, Alaska 99501-3572 �FALAS �' SCANNED �'C L .1 $ , 9 Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader ' O5 - I BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Kuparuk River Sands Pool, MPF-78 Sundry Number: 313-593 Dear Mr. McMullen: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration 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. Sincerely, Cathy P. Foerster Chair DATED this (o day of December, 2013. Encl. . , • STATE OF ALASKA Tbn) RECEIVED ki ALASKA OIL AND GAS CONSERVATION COMMISSION .17 APPLICATION APPLICATION FOR SUNDRY APPROVAL' NOV 14 013 20 AAC 25.280 4q--5 l2 61 ‘,3 A�, 1. Type of Request: OG C ❑Abandon N Plug for Redrill ' ❑Perforate New Pool ❑ Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑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. ❑Exploratory ❑Stratigraphic 195-144 • 3. Address: 'N Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22599-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPF-78 Will planned perforations require a Spacing Exception? ❑Yes N No 9. Property Designatior 10.Field/Pool(s): ADL 025509&355018 • Milne Point Unit/Kuparuk River Sands 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 16070' • 7715' • 15959' 7615' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 78' 20" 35'- 113' 35'- 113' Surface 7884' 9-5/8" 35'-7919' 35'-4497' 5750 3090 Intermediate Production 16009' 7" 33'- 16042' 33'-7689' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 15590'- 15737' ' 7313'-7427' 2-7/8",6.5# L-80 15462' Packers and SSSV Type: None Packers and SSSV None MD(ft)and TVD(ft): 12. Attachments: * 13.Well Class after proposed work: N Description Summary of Proposal L 1 BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic.N Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation November 30,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ∎_ Suspended . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Nathan Sperry,564-4258 Printed Name: John McMullen Title: Engineering Team Leader Email: Nathan.Sperry@bp.com M Signature: Z S 1/� Phone: 564-4711 Date: t t (19 t r( '5 ommission Use Only t Conditions of approval: Notify Commission so that a representative may witness ` — C q � Sundry Number. 2 J J ❑Plug Integrity L2j BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: �1 0 p t-t°5- f 1-0 5-- Or 5 1 /� f C < <! �v ! a C z ,-tit r 7 �,10;-a v-t'd per- �G .4-it G257)12(t) Spacing Exception Required? ❑Yes No Subsequent Form Required: ) —,p) �- PP y A APPROVED BY Approved 6 : � COMMISSIONER THE COMMISSION Date: /2 —6 — /3 Form 10-403 Revised 1A/2012 App i o{,I.alAff r 12 months from the date of approval ?143 {t`o(/l 3 SubRit In Duplicate DEC 1 3 Z _ • • To: Alaska Oil & Gas Conservation Commission From Nathan Sperry ID P CTD Engineer Date: November 08, 2013 Re: MPF-78 Sundry Approval Sundry approval is requested to plug the MPF-78 perforations as part of the pre-rig prior to the drilling and completion of proposed MPF-78A, AL1 &AL2 coiled tubing sidetracks. History and current status: MPF-78 was drilled, perforated, and fractured in September-1995 &was completed with an ESP in 1996. Over the life of the well there have been multiple ESP replacements. The dates and failure reasons of the ESP replacements are as follows: July 1997 (downhole electrical short), June 1998 (scale build-up leading to excessive temperature), May 1999 (motor burnt out due to scale), October 2001 (motor burnt out due to lack of lube oil), and October 2006 RWO (solids production causing pump wear)which also included reperfing 15670-15690' MD. The well has been placed on a scale inhibitor treatment program. Since then oil production has declined and water production has increased. The well is no longer a competitive producer. Proposed plan: Sidetrack MPF-78 to the MPF-78A, AL1 &AL2 locations by Nordic 2 Coiled Tubing Drilling rig on or around February 1, 2014 using the managed pressure drilling technique. This coil sidetrack will add an off take point to the west, reducing well spacing in the area. The well will be supported by injectors MPF-70 and MPF-70A(to-be-drilled). The MPF-78A sidetrack will exit the existing 7" liner and kick off in Kuparuk A3 sand and land in Kuparuk Al sand. This tri-lateral sidetrack will be completed with 2-7/8"TH511 slotted liner and blanks over faults/swept zones with solid liner tie back into the parent wellbore. This Sundry covers plugging the existing MPF-78 perforations via the pre-rig coil cement iob and a liner top packer(alternate plug placement per 20 AAC 25.112(i) set post rig). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. cdh G!/i . 74c / g( &- '/f rOovee - y44, e ` %1f9/ t,e/'fl- ¢ IA/e11 ,ato q Ti",`t�A'tr4/ 19(006491. eftA £4 fkaol Q/7 ot4e 11?l1coi Fwser qhd feaD1. ,roar i 5 BOOr7`7'61q OA He /do( i9` "4'9 Pre-Rig Work(scheduled to begin November 30th, 2013) 1. V Pull BPV 2. _ S Pull DCK& run dummy GLV's. 3. S Pull ball and rod. Pull RHC plug body. 4. S Measure static bottom hole pressure. 5. S Caliper from TD to 15,200' 6. S Drift for whipstock to 15,700' 7. E Set 4-1/2"x7"whipstock at 15,602' MD 30° LOHS C Squeeze 25 bbl, 15.8 ppg cement past whipstock&squeeze 5bbls into 8. formation. (TOC @ 15,587') g F MIT-T to 2,400 psi. 10. V Set BPV(only if MIT-T fails). 11. V PT MV, SV, WV 12. D Install 16" mouse hole. Level pad. 7h is 5 v1-1-4 2 Rig Work(scheduled to begin February 1st, 2014) Z3�� i 1. MIRU and test BOPE 250 psi low and 3,500 psi high. /������� 2. Mill 3.80"window at 15,602' and 10' of rathole. ��° pd b 3. Drill A lateral: 4.125" OH, 1509' (30°/12° deg DLS planned) 4. Run 2-7/8" Slotted liner with aluminium KO billet, top at 16,100' MD. 5. Drill AL1 lateral: 4.125" OH, 1005' (12 deg DLS planned) 6. Run 2-7/8" Slotted/solid liner, top at 16,000' MD. 7 TD 7. Drill AL2 lateral: 4.125" OH, 1100' (12 deg DLS planned) 8. Run 2-7/8" Slotted/solid liner, top at 15,370' MD. 9. Freeze protect well to 2500' MD 10. Set TWC; RDMO Post-Rig Work: 1. Slickline to set KB liner top packer. 2. RWO to run new ESP completion. 3. Re-install wellhouse, flowline. • Nathan Sperry CTD Engineer 564-4258 CC: Well File Joe Lastufka Tree: Cameron 2 9/16" 50 M F-78 Orig.•elev. = 47.54'(N 27E) Wellhead: 11" x 11" 5M FMC Gen •�'�� 78 Orig. GL. elev. = 16.6' 5,w/2 7/8" FMC tbg. hng., 2 7/8" 1 RT To Tbg. Spool = 32.78 (N 27E) EUE 8 rd on top and bottom, 2.5" 0 0 .E CIW BPV profile 0 l 20" 91.1 ppf, NT8OLHE 113' % E KOP @ 500' % Camco 2 718"x 1" 142' Max. hole angle= 72 to 74 deg. f/ 1 sidepocket KBMM GLM 4100' 12,500'. 0 Hole angle through perfs = 33 deg. 0 9 5/8", 40 ppf, L-80 Btrc. 7919' A •• • • • • • • TUBING DATA: 2 7/8"6.5 ppf, L-80,8 rd EUE tbg. 0 (drift ID = 2.347", cap. = 0.00592 bpf 0 CASING DATA: 0 7"26 ppf, L-80, Btrc. production casing 0 ( drift ID =6.151", cap. = 0.0383 bpf) j Camco 2 7/8" x 1" 0 sidepocket KBMM GLM 15'207 / ' Tandem Seal Section % HES XN-Nipple (2.25" id) 15,350' GSB3DBFERHL H6 SSCV SBSB PFSA $ i • • Tandem Pumps: 36GC2200/ • 122GC2200 GPMTAR 1:1 15,393' Stimulation Summary • Tandem Gas Separator 15,420' 11/15/95-37M# 16/20 behind pipe, % = GRSFTXARH6) screened out to surface. 0 Tandem Seal Section 15,425' 04/07/96 Re-frac 123.5 M# 16/20 GSB3DBFERHL H6 SSCVSBSBPFSA GSB3DBLT ABiHSN FHA CL5 behind pipe. # ilk 266 HP KMH motor, 15,439' 2345 v./69 amps. Perforation Summary Ref log: 11/06/95 CCL/GR/Press Centrilift PumpMate w/ ® : Six Fin Centralizer 15,462' Size SPF Interval (TVD) Kup'B'Sand 4.5" 5 15,590'-15,604' (7313'-7323') _ Intake - 15,433' MD= 7,194' TVD 32 gm AlphaJet charges (EHD = 0.50", TTP = 32.0") @35/ 145 deg. phasing Mid-perf= 7371'TVD _ 15663' and Size SPF Interval (TVD) 1 Kup'A'Sand 3-3/8" 6 15,649'-15,737' (7360'-7430') Re-Peas 10/13/06 Fish: 27-E lost a 5/16" socket 1" 4.5" 5 15,670'-15,690' (7374'-7390') 4.5" 5 15,700'-15,730' (7398'-7421') — long down hole 4/12/96. Jumbo Jet"Big Hole" charges @ 60 7534'TVD deg. phasing, EHD = 0.76",TTP = 6.4" 7" Float collar (PBTD) 15,959' 7" , 26 ppf, L-80, BTC shoe 16,042' DATE REV.BY COMMENTS 10/03/95 JBF Cased Nabors 27E/ 4/10/96 Completion 4ES 07/11/96 M. Linder RWO by Polar/ 7/18/97 RWO 4ES MILNE POINT UNIT 06/26/98 MDO ESP RWO Nabors 5S/ 5/19/99 RWO 4 es WELL F -78 10/11/01 B. Hasebe ESP RWO w/Nabors 4ES API NO: 50-029-22599 10/14/06 REH 4ES RWO w/RE-PERF BP EXPLORATION (AK) ■ Tree: Cameron 2 9/16"5M MPF-78 11" x 11" 5M FMC Gen Orig. K.B. elev. = 4754' (N 27E) 5, w/2 7/8" FMC tbg. hng., 2 7/8" Orig. GL. elev. = 16.6' EUE 8 rd on top and bottom, 2.5" RT To Tbg. Spool = 32.78 (N 27E) CIW BPV profile 20" 91.1 ppf, NT8OLHE 113' KOP @ 500' Max. hole angle = 72 to 74 deg.f/ 4100' - 12,500'. Hole angle through perfs= 33 deg. 9 5/8", 40 ppf, L-80 Btrc. 7919' 73° sail angle CASING DATA: 7"26 ppf, L-80, Btrc. production casing (drift ID =6.151", cap. =0.0383 bpf) -15,220'MD,4.5"HES X-Nipple(3.813 id) Tandem Seal Section GSB3DBFERHL H6 SSCV SBSB PFSA • —15,290'MD, 4.5"HES RCH LCH RCPT Stimulation Summary I ><1 —15,307'MD 4-1/2"x 7"HES pkr. 11/15/95 -37M# 16/20 behind pipe, —15,327'MD,4.5"HES X-Nipple w/RHC(3.813 id) screened out to surface. 04/07/96- Re-frac- 123.5 M#16/20 I I -15,402 MD 4-1/2"WLEG behind pipe. Perforation Summary Ref log: 11/06/95 CCL/GR/Press Size SPF Interval (TVD) Kup'B'Sand 4.5" 5 15,590'-15,604' (7313'-7323') 32 gm AlphaJet charges (EHD = 0.50", TTP = 32.0") @35/ 145 deg. phasing 15663' and - Size SPF Interval (TVD) Note:Tree saver rubber(6"x 1"x 1") Kup'A'Sand 3-3/8" 6 15,649'-15,737' (7360'-7430'; left in the hole 9/25/95 Re-Pads 10/13/06 — Top of 25 bands&4 Flat Guards 4.5" 5 15,670'-15,690' (7374'-7390') Fish: 27-E lost a 5/16"socket 1" 4.5" 5 15,700'-15,730' (7398'-7321') Jumbo Jet"Big Hole" charges @ 60 12265' 7534'TVD deg. phasing, EHD = 0.76",TTP = 6.4" long down hole 4/12/96. 15,959' Ak 7" Float collar (PBTD) 7" , 26 ppf, L-80, BTC shoe 16,042' DATE REV BY COMMENTS 10/03/95 JBF Cased Nabors 27E/ 4/10/96 Completion 4ES 07/11/96 M. Linder RWO by Polar/ 7/18/97 RWO 4 ES MILNE POINT UNIT 06/26/98 MDO ESP RWO Nabors 5S/ 5/19/99 RWO 4 es WELL F -78 10/11/01 B. Hasebe ESP RWO w/Nabors 4ES API NO: 50-029-22599 10/14/06 REH 4ES RWO w/RE-PERF BP EXPLORATION (AK) ' Tree: Cameron 2 9/16"5M IA-78A, AL1, AL2 • Wellhead: 11" x 11" 5M FMC Gen proposed CTD sidetrack Orig. K.B. elev. = 47.54' (N 27E) 5,w/2 7/8" FMC tbg. hng., 2 7/8" Orig. GL. elev. = 16.6' EUE 8 rd on top and bottom, 2.5" RT To Tbg.Spool = 32.78 (N 27E) CIW BPV profile 20"91.1 ppf, NT8OLHE 113' KOP @ 500' Max. hole angle =72 to 74 deg.f/ 4100'- 12,500'. Hole angle through perfs= 33 deg. 9 5/8", 40 ppf, L-80 Btrc. 7919' —73° sail angle CASING DATA: 7"26 ppf, L-80, Btrc. production casing (drift ID =6.151",cap.=0.0383 bpf) -15,220'MD,4.5"HES X-Nipple(3.813 id) Tandem Seal Section GSB3DBFERHL H6 SSCV SBSB PFSA I -15,290'MD, 4.5"HES RCH LCH RCPT Stimulation Summary gl 15,307'MD 4-1/2"x 7"HES pkr. 11/15/95-37M# 16/20 behind pipe, I� 15,327'MD,4.5"HES X-Nipple w/RHC(3.813 id) screened out to surface. —15,370'MD TOL/TOC 15.8 ppg 04/07/96 Re-frac 123.5 M#16/20 /�, -15,402 MD 4-1/2"WLEG behind pipe. Tows at 15,602'MD Planned LTP Cemented in place,perf's squeezed TD-17,100' Perforation Summary F-78AL2 Ref log: 11/06/95 CCL/GR/Press D-17,105' Size SPF Interval (TVD) F-78A 1 Kup'B'Sand 1 ' Top OHWS 16,000', 4.5" 5 15,590'-15,604' (7313'-7323') 0= / MPF-78A 32 gm AlphaJet charges (EHD =0.50", TOWS 16,100'MD TD-17,111' TTP =32.0") @35/ 145 deg. phasing 15663' and Size SPF Interval (TVD) Note:Tree saver rubber(6"x 1"x 1") Kup'A'Sand 3-3/8" 6 15,649'-15,737' (7360'-74301 left in the hole 9/25/95 Re-Parts 10/13/06 - Top of 25 bands&4 Flat Guards 4.5" 5 15,670'-15,690' (7374'-7390') 4.5" 5 15,700'-15,730' (7398'-7321') Fish: 27-E lost a 5/16"socket 1" Jumbo Jet"Big Hole" charges @ 60 12265' 7534'TVD deg. phasing, EHD =0.76",TTP =6.4" long down hole 4/12/96. 15,959' Ak 7" Float collar(PBTD) 7" , 26 ppf, L-80, BTC shoe 16,042' DATE REV BY COMMENTS 10/03/95 JBF Cased Nabors 27E/ 4/10/96 Completion 4ES 07/11/96 M. Linder RWO by Polar/ 7/18/97 RWO 4 ES MILNE POINT UNIT 06/26/98 MDO ESP RWO Nabors 5S/ 5/19/99 RWO 4 es WELL F-78 10/11/01 B. Hasebe ESP RWO w/Nabors 4ES API NO: 50-029-22599 10/14/06 REH 4ES RWO w/RE-PERF BP EXPLORATION (AK) • • Page 1 of 1 Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRD)Type Work Code in RBDMS f1. When a Form 10-403 is submitted requesting approval to plug a well for redrill,the initial reviewer(Art or Steve D.)will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked,we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). d 2. On the Form 10-403 if"Abandon" is checked in Box 15(Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill" 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D.will also review the list of suspended wells for accuracy. Thanks, Steve D. T__- 4: \T' T T■TTCTTT DT TT!-1 c«DT: T1DT A1411(111 • bp BP Exploration (Alaska) Inc. ,. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 ,t December 30, 2011 st FEB 7, 21/1fL Mr. Tom Maunder 1 qc I L i Alaska Oil and Gas Conservation Commission F- 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPF -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPF -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator S • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPF -Pad 10/29/2011 I Corrosion Initial top of Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement Vol. of cement pumped cement date inhibitor sealant date ft bbls ft gal MPF -01 1950450 50029225520000 10.2 N/A 10.2 N/A 122.4 8/7/2011 MPF -02 1960700 50029226730000 4 N/A 4 N/A 35.7 8/8/2011 MPF -05 1970740 50029227620000 1.3 N/A 1.3 N/A 13.6 8/9/2011 MPF-06 1960020 50029226390000 1.2 N/A 1.2 N/A 15.3 8/2/2011 MPF-09 1971040 50029227730000 5.0 N/A 5.0 N/A 54.4 8/92011 MPF -10 1960940 50029226790000 1.7 N/A 1.7 N/A 20.4 8/2/2011 MPF -13 1950270 50029225490000 0.2 N/A 0.2 N/A 8.5 10/6/2011 MPF -14 1952120 50029226360000 0.1 N/A 0.1 N/A 8.5 10/6/2011 MPF -17 1971960 50029228230000 4.1 N/A 4.1 N/A 37.4 8/6/2011 MPF -18 1961000 50029226810000 8.3 N/A 8.3 N/A 91.8 8/2/2011 MPF -21 1961350 50029226940000 1.8 N/A 1.8 N/A 15.3 8/6/2011 MPF -22 1952010 50029226320000 4 N/A 4 N/A 13.6 8/1/2011 MPF -25 1950160 50029225460000 0.3 N/A 0.3 N/A 6.8 10/29/2011 MPF -26 1970840 50029227670000 1.8 N/A 1.8 N/A 11.9 8/1/2011 MPF -29 1961170 50029226880000 6.7 N/A 6.7 N/A 56.1 8/9/2011 MPF -30 1951840 50029226230000 0.8 N/A 0.8 N/A 6.8 8/1/2011 MPF -33 2010620 50029226890000 23 Need top job MPF -34 1971970 50029228240000 4.1 N/A 4.1 N/A 13.6 8/1/2011 MPF -37 1950250 50029225480000 0.2 N/A 02 N/A 8.5 10/62011 MPF -38 1951680 50029226140000 0.3 N/A 0.3 N/A 6.8 10/5/2011 MPF-41 1970950 50029227700000 0.8 N/A 0.8 N/A 8.5 8/9/2011 MPF-42 1970200 50029227410000 1.8 N/A 1.8 N/A 13.6 8/1/2011 MPF-45 1950580 50029225560000 8 N/A 8 N/A 78.2 8/11/2011 MPF-46 1940270 50029224500000 Sealed Conductor N/A N/A N/A N/A N/A MPF-49 1970030 50029227320000 2.3 N/A 2.3 N/A 18.7 8/11/2011 MPF -50 1970580 50029227560000 1.7 N/A 1.7 N/A 6.8 7/31/2011 MPF -53 1951080 50029225780000 2.8 N/A 2.8 N/A 11.9 9/19/2011 MPF -54 1961920 50029227260000 1.7 N/A 1.7 N/A 10.2 8/1/2011 MPF -57A 2031670 50029227470100 1.3 N/A 1.3 N/A 13.6 8/11/2011 MPF-58 1961560 50029227060000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -61 1951170 50029225820000 62 Need top job MPF -62 1951610 50029226090000 2.0 NA/ 2.0 N/A 13.6 9/1/2011 MPF-65 1970490 50029227520000 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -66A 1961620 50029226970100 0.8 N/A 0.8 N/A 8.5 7/31/2011 MPF -69 1951250 50029225860000 0.8 N/A 0.8 N/A 8.5 8/4/2011 MPF -70 1951530 50029226030000 1.7 N/A 1.7 N/A 15.3 7/31/2011 MPF -73A 2001980 50029227440100 1.5 N/A 1.5 N/A 13.6 8/11/2011 MPF -74 1961080 50029226820000 1.7 N/A 1.7 N/A 13.6 7/31/2011 MPF -77 1951360 50029225940000 0.2 N/A 02 N/A 6.8 10/5/2011 "4 MPF -78 1951440 50029225990000 0.7 N/A 0.7 N/A 5.1 7/31/2011 MPF -79 1971800 50029228130000 0.6 N/A 0.6 N/A 6.8 8/3/2011 MPF-80 1982170 50029229280000 0.5 N/A 0.5 N/A 3.4 8/3/2011 MPF-81 2000660 50029229590000 0.9 N/A 0.9 N/A 8.5 8/3/2011 MPF -82 2091350 50029229710000 1.7 N/A 1.7 N/A 15.3 8/3/2011 MPF -83 2000930 50029229630000 1.2 N/A 12 N/A 13.6 8/3/2011 MPF -84B 2001760 50029229310200 1.2 N/A 1.2 N/A 10.2 8/3/2011 MPF-85 1982500 50029229360000 0.1 N/A 0.1 N/A 7.7 9/1/2011 MPF -86 2010870 50029230180000 0.8 N/A 08 N/A 6.8 , 8/12/2011 MPF -87A 2032130 50029231840100 1.3 N/A 1.3 N/A 11.9 8/132011 MPF -88 2031930 50029231850000 1.3 N/A 1.3 N/A 15.3 8/3/2011 MPF -89 2050900 50029232680000 12 N/A 12 N/A 10.2 8/3/2011 MPF -90 2012110 50029230510000 1.8 N/A 1.8 N/A 18.7 8/3/2011 MPF -91 2051100 50029232710000 1.7 N/A 1.7 N/A 11.9 8/132011 MPF -92 1981930 50029229240000 0.8 N/A 0.8 N/A 5.1 8/132011 MPF -93 2050870 50029232660000 0.3 N/A 0.3 N/A 7.7 9/1/2011 MPF -94 2011700 50029230400000 1.8 N/A 1.8 N/A 13.6 8/13/2011 MPF -95 1981790 50029229180000 0.5 N/A 0.5 N/A 3.4 8/13/2011 MPF -96 2081860 50029234060000 0.1 N/A 0.1 N/A 6.0 9/1/2011 MPF -99 2061560 50029233320000 1.3 N/A 1.3 N/A 11.9 8/11/2011 \,oiL";, i 1. Operations Performed: liflChorô(ji.! "Ü;lIYik"~",1 o Abandon ~ Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Alter Casing ~ Pull Tubing o Perforate New Pool o Waiver ~ Other o Change Approved Program o Operation Shutdown 181 Perforate o Time Extension Change Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 181 Development o Exploratory 195-144 3. Address: o Stratigraphic o Service 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22599-00-00 7. KB Elevation (ft): 45' 9. Well Name and Number: MPF-78 8. Property Designation: 10. Field / Pool(s): ADL 355018 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 16070 feet true vertical 7715 feet Plugs (measured) None Effective depth: measured 15959 feet Junk (measured) None true vertical 7615 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 90' 30" 90' 90' Surface 7884' 9-5/8" 7919' 4497' 5750 3090 Intermediate Production 16009' 7" 16042' 7689' 7240 5410 Liner S(;AWW\![;r; ç. C \,.¡,' " '. ·t ., t) ..~ (;., Perforation Depth MD (ft): 15590' - 15737' Perforation Depth TVD (ft): 7313' - 7427' 2-7/8",6.5# L-80 15467' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: 13. Representative Dailv AveraCle Production or Injection Data Oil-Bbl Gas-Met Water-Bbl CasinCl Pressure Tubina Pressure Prior to well operation: 0 0 0 0 0 Subsequent to operation: 0 0 0 0 0 14. Attachments: o Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development o Service 181 Daily Report of Well Operations 16. Well Status after proposed work: 181 Well Schematic Diagram 181 Oil o Gas o WAG OGINJ DWINJ o WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SUndry Number or N/A if C.O. Exempt: Contact Howard West, 564-5471 Printed Name Sondra Stewman Title Technical Assistant /"":Jt Prepared By Name/Number: i -, ,,'),''', "\ Date to' I q·C{ CSondra Stewman, 564-4750 Signa1µre . ' ".,' \",,({f/"lT7r;::':t Phone 564-4750 I STATE OF ALASKA a ALAS Oil AND GAS CONSERVATION COM~ION Ocr REPORT OF SUNDRY WELL OPERA TIONSllaska Oil & G as R~r: Form 10-404 Revised 04/2006 ORIG1NAL RBDMS 8Ft OCT 2 0 ZOQ6 Submit Original Only Tree: Cameron 2 9/16" Wellhead: 11" x 11" 5M C Gen 5, w/2 7/8" FMC tbg. hng., 2 7/8" EUE 8 rd on top and bottom, 2.5" CIW BPV profile 20" 91.1 ppf, NT80LHE I 113 KOP @ 500' Max. hole angle = 72 to 74 deg. fl 4100' - 12,500'. Hole angle through perfs = 33 deg. 95/8",40 ppf, L-80 Btrc. I 7919' I TUBING DATA: 2 7/8" 6.5 ppf, L-80, 8 rd EUE tbg. ( drift ID = 2.347", cap. = 0.00592 bpf CASING DATA: 7" 26 ppf, L-80, Btrc. production casing (drift ID = 6.151", cap. = 0.0383 bpf) Tandem Seal Section GSB3DBFERHL H6 SSCV SBSB PFSA Stimulation Summary 11/15/95 - 37M # 16/20 behind pipe, screened out to surface. 04/07/96 - Re-frac - 123.5 M# 16/20 behind pipe. Perforation Summary Ref log: 11/06/95 CCUGRlPress Size SP (TVD) Interval Kup 'B' Sand 4.5' 5 15,590'-15,604' (7313'-7323') 32 gm AlphaJet charges (EHD = 0.50", TTP = 32.0") @35/145 deg. phasinç Size SP Interval Kup 'A' Sand 3-3/8" 6 15,649'-15,737' (7360' - 7430 Re- Perfs 1 0/13/06 4.5" 5 15,670'-15,690' (7374'-7390') 4.5" 5 15,700'-15,730' (7398'-7321') Jumbo Jet "Big Hole" charges @ 60 deg. phasing, EHD = 0.76", TIP = 6.4" DATE 1 0103/95 07í11/96 06/26/98 10/11/01 10/14/06 REV. BY JBF M. Linder MDO B. Haseb REH COMMENTS Cased Nabors 27E 1 4/10/96 Completion 4ES RWO by Polar I 7/18/97 RWO 4 ES ESP RWO Nabors 5S 1 5/19/99 RWO 4 es ESP RWO wI Nabors 4ES 4ES RWO w/RE- PERF MILNE POINT UNIT WELL F - 78 API NO: 50-029-22599 MPU F-78 or~g.. elev. = 47.~4' (N 27E) Ong. elev. = 16.6 RT To Tbg. Spool = 32.78 (N 27E) Cameo 2 7/8" x 1" sidepocket KBMM GLM Cameo 2 7/8" x 1" sidepocket KBMM GLM HES XN-Nípple (2.25" id) æÐ 15,207' 15,350' Tandem Pumps: 36GC22001 I 122GC2200 GPMTAR 1:1 15,393' Tandem Gas Separator GRSFTXARH6) Tandem Seal Section GSB3DBFERHL H6 sseVSBSBPFSA GSB3DßL T ABiHSN FSA CL5 266 HP KMH motor, 2345 v.l69 amps. Centrilift Pump Mate wI Six Fin Centralizer 15,420' 15,425' 15,439' 15,462' Intake - 15,433' MD = 7,194' TVD Mid-perf = 7371' TVD 15663' md Fish: 27-E lost a 5/16" socket 1" long down hole 4/12/96 7" Float collar (PBTD) I 7" ,26 ppf, L-80, BTC shoe I 7534' TVD 15,959' I 16,042' I BP EXPLORATION AK Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-78 MPF-78 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/5/2006 1 0/13/2006 Spud Date: 9/16/1995 End: 10/13/2006 10/5/2006 11 :00 - 12:30 1.50 RIGD P PRE Scope down & Lower derrick. 12:30 - 14:00 1.50 MOB P PRE Move Rig off MPI·03 well. P/U matting boards & Herculite. Clean cellar area & location. Install guard around wellhead. 14:00 - 18:00 4.00 MOB P PRE Move rig from MPI-03 to MPF-78. 18:00 . 21 :00 3.00 RIGU P PRE Spot Rig sub over MPF-78 wellhead. Spot in Camp, pits & pipe shed. Begin rigging up equip. 21 :00 . 23:00 2.00 RIGU P PRE Raise & scope up derrick. con't to RlU equip. ACCEPTED RIG @ 2300 Hrs. 23:00 - 00:00 1.00 PULL P DECOMP RlU lines to tree. Install 2nd annulus valve. RlU lines to tiger tank. 10/6/2006 00:00 . 00:30 0.50 WHSUR P DECOMP P/U lubricator. Pull BPV. UD lubricator. 00:30 - 01 :00 0.50 KILL P DECOMP Pressure test kill lines 1000/3500 psi. Tested good. 01 :00 - 01 :30 0.50 KILL P DEcOMP Hold PJSM & reviewq Kill operation wI all hands. 01 :30 - 05:00 3.50 KILL P DECOMP Circulate well wI seawater. SITP 1270 psi. SlcP 1370 psi. Bled well pressure to 450 psi. Began pumping 3 BPM @ 1450 psi. CP 880 psi. Had oil returns after 25 bbls. con't pumping 3 BPM pressure went from 1680 psi to 1315 psi. Cp went from 880 down to 740 psi. SID after 7000 stks. TP 680 psi. CP 770 psi. Recovered 290 bbls of 99% oil. Con't pumping 3 BPM TP 1060 psi. CP 410 psi. Atr 9000 stks increased rate to 4 BPM, TP 1400 psi. CP 290 psi. Complete circulation @ 9500 stks. (560 bbls.) Had seawater returns. Con't to pump to 590 bbls appears to be 99% seawater. SD & monitor welllSITP 370 psi. ISICP 380 psi. 05:00 - 06:00 1.00 KILL P DECOMP Monitor well & record build up pressures. 06:00 . 07:00 1.00 KILL P DEcOMP Continue to monitor Well. SITP = 66 psi. SlcP = 680 psi. 07:00 - 08:30 1.50 KILL P DECOMP Order out 11.0 Brine per disussion with Town Eng group. Wait on Brine. Maintain and service Rig. 08:30 - 10:30 2.00 KILL P DECOMP Circulate Well with remaining hot Sea Water to further clean-up ESP Cable and any migrating oil at 4.0 bpl/1570 psi. 10:30 - 16:00 5.50 KILL P DEcOMP Continue to monitor Well. Continue to wait on Brine. Perform Derrick inspection and clear of ice build-up. Off load 1 st and 2nd load of 11.0 Brine in Pit. Continue to wait on final load to arrive on location. 16:00 - 19:00 3.00 KILL P DECOMP Final load of Brine arrives on Location. Begin to swap Well over to 11.0 Brine at 4.0 bpm/1200 psi. SITP 700 psi. SlcP 720 psi. Open well. Pump 4 BPM. TP 1460 psi, CP 220 psi. Pumped total of 650 bbls. Pump 10.9 ppg in. Had 10.7 ppg returns. SID TP & CP 10 psi. monitor well. 19:00 - 20:00 1.00 KILL P DECOMP Open well well & circulate to pits. Pumped 4 BPM @ 1600 psi. FI. Wt. in 10.9 ppg. FL Wt. out 10.8+ ppg. Pumped 75 bbls. SID & monitor well. Well breathing, then died. Monitor well 20 min. 20:00 - 21 :00 1.00 WHSUR P DECOMP Dry rod TWC. 5314 turns, BIO 1/4 turn. Travel 1 1/2". test plug from bottom. Pump 1 BPM 60 psi, for 10 min. Test from top 3500 psi, 10 min. Charted same. 21 :00 - 21 :30 0.50 WHSUR P DECOMP Blow down & break down circulating lines. RID test equip. 21 :30 - 22:30 1.00 WHSUR P DECOMP Bleed off tubing void. N/D tree & adapter flange. 22:30 - 00:00 1.50 BOPSU P DEcOMP N/U BOPE. 10/7/2006 00:00 - 00:30 0.50 BOPSU P DECOMP Fill BOP stack. RlU test equip. 00:30 - 04:00 3.50 BOPSU P DECOMP Test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Chuck Sheve wI AOGCC. No Failures. Rig down test equipment. Printed: 10/13/2006 2:25: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-78 MPF-78 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/5/2006 1 0/13/2006 Spud Date: 9/16/1995 End: 10/13/2006 Pick-up Lubricator pull TWC. Lay down same. Pick-up Landing Joint. BOLDS. PUll Tubing Hanger to floor with no problems at 91 K. 07:00 - 07:30 0.50 PULL P DEcOMP Cut ESP Cable. Secure with 3 extra bands just above LaSalle Clamp. Fill wellbore with 11.0 Brine. 16 bbls = Static FL at 530'. 07:30 - 08:00 0.50 PULL P DEcOMP Pick-up 2 7/8" singles from Pipe Shed. Tagged fill at 15,671'. Re-tag at same spot and set down 5K. Fill is solid. Fill is accross -2/3rds of the Kupuark A interval. Fill is also completly covering the proposed planned add perf section. 08:00 - 08:30 0.50 PULL P DECOMP Single down extra Tubing. 08:30 - 10:30 2.00 PULL P DEcOMP Rig up to circulate. Circulate and condition well bore at 4.0 bpm/1400 psi. Fluid loss average for 5 minutes = 1 bbl. Returns = 10.95 Ib/gal 10:30 - 16:00 5.50 PULL P DECOMP Monitor Well. Fluid level slowely dropping. Finish rigging-up to pull 2 7/8" ESP Completion. Begin to trip out with 2 7/8" ESP Completion, keeping hole full. With 80 stands out (-7450'), stopperd to change ESP Cable Reels in Spooling Unit. 16:00 - 18:00 2.00 PULL P DECOMP Continue to trip-out with 2 7/8" ESP Cmpletion. 18:00 - 18:30 0.50 PULL P DECOMP Service rig, Check PVT Alarms & inspect derrick. 18:30 - 23:30 5.00 PULL P DEcOMP con't to POOH & stand back 2 718" tubing. Pulled 161 stands + 2 singles of 2 7/8" tubing, 2 GLM assys. 2 - 10' pups, & "XN" nipple. Bent & replaced 1 jt of tubing. 23:30 - 00:00 0.50 PULL P DEcOMP Pull & drain ESP. 10/8/2006 00:00 - 02:00 2.00 PULL P DECOMP POOH, drain & inspect ESP. Top pump locked up. Motor lead very badly damaged. Flat guards badly corroded. Recovered 368 - LaSalle Clamps, 3 - Flat Guards & 5 - Protectolizers. 02:00 - 03:30 1.50 PULL P DECOMP Clear & clean rig floor. RId elephant trunk & drain hose. 03:30 - 06:00 2.50 PULL P DEcOMP Hold PJSM. M/U muleshoe on bottom jt of 2 7/8" tubing & RIH. 06:00 - 06:30 0.50 PULL P DECOMP Lub Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 12:30 6.00 PULL P DECOMP Trip in with Mule Shoe and 485 Joints of 2 7/8" Tubing (original string). Continue to single in with 2 7/8" Tubing from Pipe Shed. Tag fill at 15,644' 4es md. 12:30 - 16:00 3.50 PULL P DEcOMP Rig-up to wash through top of fill. Broke through crust at 3 bpm/850 psi. Reverse circulate at 4 bpm/750 psi and clean-up joint down. Loss rate = 10 bbls in 5 minutes. Continue to Reverse Circulate on down with no problems. Returns are soild Carb-O-Lite. Reduce clean-up rate to 3 bpm. Loss rate = 5 -7 bbls in 5 minutes. Have cleaned-out to 15,755' 4es md. 16:00 - 20:00 4.00 PULL P DECOMP Continue to Reverse Circulate to add some sump area. Continue to clean-out down to 15,877' 4es md. Losing 50- 60%. Called it good. 20:00 - 21 :00 1.00 PULL P DECOMP Single down 19 Jts. (extra Tbg). Park Mule Shoe at -15,300' Monitor Well. Well flowed back 10 bbls due to formation balloning then died. 21 :00 - 00:00 3.00 PULL N WAIT DECOMP Shut-down due to high winds. Winds steady at 45 mph with gust to 60 mph. Maintain Rig. Monitor Well and allow fluid to stabilize. 10/9/2006 00:00 - 06:00 6.00 PULL N WAIT DECOMP Continue to maintain rig and WOW Winds. 45 - 50 mph with gusts to 65 mph. 06:00 - 06:30 0.50 PULL N WAIT DECOMP Lub Rig. Check PVT Alarms. 06:30 - 07:00 0.50 PULL N WAIT DECOMP Check fluid level after 9 hour shut-in. Filled Well with 7 bbls of Printed: 10/13/2006 2:25:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-78 MPF-78 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 10/5/2006 10/13/2006 Spud Date: 9/16/1995 End: 10/13/2006 10/9/2006 06:30 - 07:00 0.50 PULL N WAIT DEcOMP 11.0 Ib/gal Brine. Static FL = 230'. Shut-in Well. 07:00 - 15:30 8.50 PULL N WAIT DECOMP Continue to WOW. Winds at 50·55 mph and gusting to 65 mph. Peak wind gust recorded at MPU was 70+ mph. 15:30 - 16:00 0.50 PULL N WAIT DECOMP Check fluid level after second 9 hour shut-in. Filled Well with 13 bbls of 11.0 Iblgal Brine. Static FL = 430'. Shut Well in. 16:00 - 00:00 8.00 PULL N WAIT DECOMP Continue to WOW. 10/10/2006 00:00 - 03:30 3.50 PULL P DECOMP PJSM. Filled wellbore, 11 bbls to fill. Circulate bottoms up @ 3 bpm I 825 psi, 530 bbls pumped. 03:30 - 06:00 2.50 PULL P DECOMP POOH w/2 7/8" tubing. 06:00 - 06:30 0.50 PULL P DECOMP Service rig. 06:30 - 10:00 3.50 PULL P DECOMP Continue to POOH w/2 7/8" EUE 8 md tubing & mule shoe, UD mule shoe. 10:00 - 11 :00 1.00 PERF P INTERV Clear I clean rig floor, rig up to pick up TcP guns. 11 :00 - 13:30 2.50 PERF P INTERV PJSM. Pick up TcP guns. 13:30 - 22:00 8.50 PERF P INTERV TIH with TcP Gun Assembly, Firing Head, 5/8" Ball Disconnect, 3 Joints of 2718" Tubing, 10' Pup Joint, 494 Joints of 2 7/8" Tubing. OAL = 15,767.91 to the bottom of the Bullnose on the TCP Gun Assembly. Schlumberger E-line on location at 18:00 hrs, spot the Unit and Whale next to the Pipe Shed. At 21 :00 hrs, begin picking up singles from Pipe Shed - pick up a total of 12 joints. 22:00 - 22:30 0.50 PERF P INTERV Pre Job Safety Meeting with Nabors, Schlumberger E-line and Schlumberger TCP personnel. 22:30 - 23:30 1.00 PERF P INTERV RU Schlumberger E-line to 2 7/8" Tubing String. Fill hole to check on fluid loss. It took 7.5 bbls to fill - 1,300'. 23:30 - 00:00 0.50 PERF P INTERV Begin RIH with Schlumberger E-line with 1 11/16" GRlCCL combo for depth correlation. 10/11/2006 00:00 - 01 :00 1.00 PERF P INTERV Continue RIH with Schlumberger E-line with 1 11/16" GRlCCL combo for depth correlation. Had problems getting through spot at 14,400'. Work a couple of times and fell through. Continue RIH until find RA tag. 01 :00 - 01 :30 0.50 PERF P INTERV Begin correlating depth to tie-in log (Western Atlas Temp/Press Log dated 11/06/95) using the GR signature. Tie in to said log and RA tag shown at a depth of 15,571'. To place the top shot of perfs at a depth of 15,670', the RA tag should be at a depth of 15,534'. Therefore we will shift the Tubing string 37' shallower to be on depth. 01 :30 - 02:30 1.00 PERF P INTERV POH with Schlumberger E-line. The tough spot at 14,400' was not seen on the way out of the hole. 02:30 - 03:30 1.00 PERF P INTERV On surface with E-line tools. RD Schlumberger E-line. Clear and clean Rig Floor. 03:30 - 05:00 1.50 PERF P INTERV POH with Tubing String laying down 1 joint in the Pipe Shed. MU Headpin and pump through Tubing to ensure free. Broke circulation at 3 bpm 11,000 psi. Break off Headpin and drop 5/8" Aluminum Ball. MU Headpin. Fill up backside with 11.0 ppg brine. Continue POH to 37' mark. Pump ball down with a rate of 1 bpm 1150 psi. Ball sat and pressured up quickly detonating the Gun Assembly. Charted the process. Pressure increased too quickly to see how much it increased before dropping out. Pumped a total of 83.5 bbls. 05:00 - 06:00 1.00 PERF P INTERV Break off Headpin. Lay down 4 Joints of Tubing in the Pipe Shed to get above perfs. 06:00 - 10:00 4.00 PERF P INTERV CBU to clean gas free returns @ 3 bpm 11150 psi. Got gas cut Printed: 10í13í2006 2:25: 18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-78 MPF-78 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: Rig Release: Rig Number: 1 0/5/2006 1 0/13/2006 Spud Date: 9/16/1995 End: 10/13/2006 10/11/2006 06:00 - 10:00 4.00 PERF P INTERV returns as fluid reached the surface. 10:00 - 14:00 4.00 PERF P INTERV PJSM. POOH w/2 7/8" tubing & perforating assembly. 14:00 - 16:00 2.00 PERF P INTERV PJSM. Cut and slip drilling line. 16:00 - 17:30 1.50 PERF P INTERV PJSM. Continue to POOH. 17:30 - 18:30 1.00 PERF P INTERV On surface with top of TCP Assembly. Pre-tour safety meeting with night crew. Service Rig. PJSM with Schlumberger TCP to discuss breaking down of Gun Assembly and possibility of trapped pressure in the guns. 18:30 - 19:30 1.00 PERF P INTERV RD Schlumberger TCP Gun Assembly. The Assembly contained about a cup of what appears to be pretty uniformly shaped frac sand. Some trapped formation gas but bled off easily through bleed port. 19:30 - 20:00 0.50 RUNCO RUNcMP Clear and clean Rig Floor in preparation for running the new ESP Completion. 20:00 - 00:00 4.00 RUNCO RUNCMP Load new ESP components into Pipe Shed. PU and service new ESP Assembly with Centrilift reps. Pull ESP Cable over Sheave and attach to Assembly. 10/12/2006 00:00 - 06:00 6.00 RUNCO RUNCMP TIH with new ESP Completion on 2 7/8", 6.5# L-80 EUE 8rd Tubing from the Derrick. Utilizing new LaSalle Clamps on the Tubing String instead of ones that came out of well. Stopping every 2,000 ft to check the conductivity of the ESP cable and pump through it to ensure free of debris, pumping at a rate of 1 bpm 11,050 psi. 06:00 - 09:00 3.00 RUNCO RUNCMP PJSM. Make reel to reel splice 81 stands in @ 8008'. 09:00 - 15:30 6.50 RUNCO RUNCMP PJSM. Continue in hole wI ESP completion as before, checking conductivity of ESP cable & circulating to clear pump every 2000' @ 1 bpm 11050 psi. 15:30 - 16:00 0.50 RUNCO RUNCMP PJSM. P/U landing joint, make up tubing hanger. Install ESP penetrator. Make field connection splice. 86K up wt, 40K down wt. Installed (369) La Salle clamps, (3) flat guards & (6) Protectrolizers. 16:00 - 17:30 1.50 RUNCO RUNCMP 1 1/2 hour safety stand down. MP Safety Coordinator Bob Kardon & Mark 0 Malley present. Reviewed each of (5) incidents, (recordable accidents), that occurred over the last year, and discussed root causes. Emphasized well control, communication, and that each hand is obligated to stop ops and conduct a huddle up at any time during any operation if any concerns arise as to the manner in which operations are being conducted. 17:30 - 19:00 RUNCMP Land Tubing Hanger with FMC rep. RILDS with FMc rep. Lay down Landing Joint in the Pipe Shed. 19:00 - 19:30 RUNCMP Set TWC with FMC rep. 19:30 - 20:00 RUNCMP RU Test Equipment and test TWC from above and below. Test from above to 3,500 psi for 10 mins charted - OK. Test from below by injecting 11.0 ppg brine at a rate of 3 bpm for 10 mins charted - OK. 20:00 - 21 :30 1.50 BOPSU P RUNCMP PJSM. ND BOPE and RD Test Equipment. 21 :30 - 22:30 1.00 WHSUR P RUNcMP NU Production Tree and Adapter Flange. 22:30 - 00:00 1.50 WHSUR P RUNCMP Test Tree to 5,000 psi - no good. Suspect the TWC is no longer holding. RU Lubricator with Well Site Maintentance rep and change out TWC. Re-test Tree to 5,000 psi - good. 10/13/2006 00:00 - 02:00 2.00 WHSUR P RUNcMP Pull TWC and set BPV with Well Support Tech. RD Lubricator. Secure the cellar. Rig was released at 02:00 hrs on Printed: 10/13/2006 2:25:18 PM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPF-78 MPF-78 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 1 0/5/2006 Rig Release: 10/13/2006 Rig Number: Spud Date: 9/16/1995 End: 10/13/2006 10/13/2006 00:00 - 02:00 2.00 WHSUR P RUNCMP 10/13/2006. Printed: 10/13/2006 2:25: 18 PM Re: MPU F-78 ESP RWO e e Dave, Thanks for the note. You have accurately described the BOP arrangement used on 4ES for many years. Having shear capable rams and VBRs has been the mitigation method allowed where height limitations preclude adding an additional ram body. As you also note, it would also be necessary to allow the well to swap out nearly completely to formation fluid before 3000 psi at surface could be approached. The stack arrangement is acceptable. A copy of this email should be at the rig. Also, although you may encounter similar situations on other wells, BP should plan to contact the Commission in such cases so that an exception such as this can be obtained. Call or message with any questions. Tom Maunder, PE AOGCC SCANNED ~ 1 'nn~, (~)) ¿^ ;.;..'....'w:-' Reem, David C wrote, On 10/5/2006 2:26 PM: Tom, as I mentioned in our phone conversation, 4ES is going to rig up on Milne well F-78 to change out a failed ESP. While there it is our intent to re-perforate part of the Kuparuk. A bottomhole pressure survey conducted today indicates that our maximum surface pressure that we could see would be greater than 3000 psi were we to allow the entire wellbore to swap over to reservoir gas. 4ES's BOP stack is configured (top --> bottom) as follows: 13-5/8" x 13-5/8" 5K annular preventer, 13-5/8" x 13-5/8" 5K blind/shear rams, flow-cross, 13-5/8" x 13-5/8" 5K variable-bore pipe-rams. We will be pulling 2-7/8" tubing from the well and plan on using this tubing as a work-string for tubing conveyed perforating. All BOP rams will be tested using a 2-7/8" test joint. As you know, this rig's floor is not tall enough to allow installation of another set of pipe rams in our stack. As such, we are asking for an variance to the regulation stipulating the additional set of pipe rams for a maximum surface pressure greater than 3000 psi. Call with any questions or if further details are required. Thanks. Dave Reem WellslWorkover Engineer 564-5743 (w) 632-2128 (c) 1 of 1 10/10/20067:59 AM h,.sred riilJjng TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily susPend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose Setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8,' x 7" annulus available for the injection of liquid wastes. There are no other well annulii on this pad for injection.. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ANNULAR INJECTION DATA ENTRY SCREEN Asset UilD.e. .......................................... Rig Name J~.~b.9.r.~..~.7.F,,.. ........................... Inj Well Name M...P...F.:.7...~, ..................................... Sur Csg Dep 7..0.{~.5...i ............. Legal Desc ~,?,3Z'.~.L,..~.5.5.5.'.~.EL,..~.e~..6,.T..1.3N,i.B.1.QE .................................... Research ....................................................................................................................... ~QB.B~,C.[E0...(;.O.P..~..~.tJ B. ML'~. EI~..~..O..&.Q.~C.C ............. ;~:.~.6.-.~.7.. ........................................................................................... Permit Start ........ .9.:.12.'.9.,5 ........ Permit End ....... .1.;~/.:~.1L~.5. ....... .............................................................. SCANNED NoV .~ ;3 ~0~2: Cumulative Data Rig ComPletion Formation Intermittant Final Well Total Mud/Ctg Wash Fluids Fluids Freeze Freeze ......... !~.47.6 ................... Z,.4.5.6. ..................... .4~). ....................... ZZ.5. ..................................................... I~.5. ....................... .1..4.~ ........... Daily Data -- U'P¢:'?(~ ................... ~070'~/~)',~ ' 80 '80 ............................... ~'i5'~'~ ........ ' ............... ~"~'{)'~'""~Li'~'~ MPF-70 ~0/07/95 -~ 40 140 -- MPF-70 ~ 0/08/95 405 405 MPF-70 10/09/95 170 170 MPF-70 10/10/95 500 500 MPF-70 10/11/95 781 781 MPF-70 10/12/95 1,570 1,570 M P F-70 10/13/95 45 40 85 .-70 10/14/95 330 330 ........... ....... MPF-70 10/17/95 665 665 MPF-70 10/18/95 255 255 MPF-70 10/19/95 100 65 165 MPF-70 .... !0120195 0 0 MPF-70 !10/21/95 802 .... 1802 MPF-70 .10/22/95 380 ..... i380 - MPF-70 !10/23/95 175 775 950 ............................................................. ~l--fi-F'---?~ .............. i'~7~§ ............. ;i'~§- ........................................................................................................................ ~'~ .................. ~§ I rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-51'93 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 14 1998 Alaska Oil & Gas Cons, Commission Anchorage On October 28, 1998 you requested an update from Shared service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with Our records and are able to provide you with the following data: Individual Annular Disposal Logs from the ssD database which coincide with the approved wells on your attached AOGCC Annular Log. The SSD records are proVided to yoU in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/N-25, 1-59/0-24 · Exploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & K-05, K-02, 1t-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, 1{-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated, frOm these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disPosal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a SUndry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of recOrds from July 25, 1995 through the present. From those records, we show.the following wells not listed on your report were used for annular dispoSal: ,, ,.Annular Disposal Letter .'. 12/14/98 ! · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdoueh//3 - ~z~° ~_~ ,~.~ ' · Ml~e Pointwells~-06,~-05,~-06, Jz13, L-24 - · PBUwells 18-30, 18-31, 14-~,~-43, E-34, E-36, G-~A,~dS-33-~x'~°~ ~-o~ 'D3-2a 'qq.o~ ~dividu~ logs are provided to ~ou fo~ these ~ogs ~s w~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED Alaska Oii & aas Cons. Commissio,n ^nch0ra~e 1. e6ed I U~d0 ~6~ ~ 96/~ ~ ~Z I ................ 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Z~; L'6 ~B~'6 =10 L El 'N~ Ll'9 oeS '-I=IN~, L~Z~ "1SN,1766 L L 999 9B-_-IclIAI =IZ~ sJoq~l~ uedo 96/LE;/~ L 96/9~//_ 9/_ 0/_ Z88'9 ~0'Z BOLEI 'N~L~'9 oeS '-13~,~179~ '-ISN, L~6 L L~99 Z~-_-Id~ B/.~ sJoqel~ uado 96/Z ~ ~ 96/~ L/'& L 0/_ 9917'9 989'9 ~rl ~0 L H 'NE; LJ.'90 oeS L 1798 ~-_-Idl/4 ~]/~ s~oq~l~ L~odel:! e^!lelnuJno B66 [ Jeqtueoeo I!lUn ~66 L 'G~ setunloA UO!lOeJUl Jelnuuv oo! s Shared 5'.ei~vice Drilling Ann1~i~'r Injection Volumes July 25, 1995, until December 1998 Cumulative Report Sudace Casing Cum Mud Rig Inj Well Depth Legal Desc Cum Total & Ctgs Nabors 28E B-33 3504' 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 Nabors 28E E-34 3664 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 Nabors 28E E-36 3648 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 Nabors 28E E-37 3810 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 Cum Rig Cum Compl Cum Form Cum Inlerm Cum Final Disposal Period Annulus Wash Fluids Fluids Freeze Freeze Start End Status 857 195 80 5/1/96 12/31/96 Broached 1.420 858 40 110 8/23/95 12/31/95 Open 1,293 3,096 365 100 7/25/95 12/31/95 Open 374 80 9/16/95 12/31/95 Open Nabors 28E E-39 3638 3358'NSL, 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 80 8/28/95 12/31/95 Open Nabors 28E G-04A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E 5,937 1,798 1,824 2,315 10/20/95 12/31/95 Open Nabors 28E G-21 3509 2911'NSL, 2368'WEL. Sec 12,Il 1N, R14E 11,430 3,956 3,072 4,270 70 62 9/8/95 12/31/95 Open Nabo!s 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E 20.261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open Nabors 28E 8-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open 115 2/8/96 2/8/97 Open Nabors 28E S-42 3077 Sec 35, T12N, R 12E 168 100 68 3/13/96 3/13/97 Open Nabors2ES H-35 3157 4535'NSL 1266'WEL Sec21 T11N R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 Open N.ab.°.r~..~.E.~ ............. Hi'~ .................................... ~..o. ............................ ~4~.7...8.~N.~.L~!~.2~6..~.w.~.L.~.s..e.~2.~!~..T".!~!~..N.~`~..R~!~3~E.~ .......................... .1...,..4..5..2.' ......................................... .8.5_7 ................................. !...o....o. ................................. .4..?. ......................................................................................................................................... ..8..5 ............ .1.(?~/95 ....................... !.~!3.?.9..5. ............................ .o..?e..? .............. NOV Page 3 -~-' STATE OF ALASKA '~ ALASKA .__,L AND GAS CONSERVATION COMM,..,JION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well [] Other Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 45' [] Exploratory 7. Unit or Property Name 3. Address [] Stratigraphic Milne Point Unit P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. Well Number 2237' NSL, 2555' WEL, SEC. 6, T13N, R10E, UM MPF-78 At top of productive interval 9. Permit Number / Approval No. 195-144 4014' NSL, 716' WEL, SEC. 30, T14N, R10E, UM 10. APl Number At effective depth 50-029-22599-00 4224' NSL, 700' WEL, SEC. 30, T14N, R10E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 4272' NSL, 699' WEL, SEC. 30, T14N, R10E, UM Sands 12. Present well condition summary Total depth: measured 16070 feet Plugs (measured) true vertical 7715 feet Effective depth: measured 15959 feet Junk (measured) true vertical 7615 feet Casing Length Size Cemented MD TVD Structural Conductor 90' 30" 260 sx Arcticset (Approx.) 90' 90' Surface 7884' 9-5/8" 1555 sx PF 'E' 250 sx 'G', 250 sx PF 'E' 7919' 4497' Intermediate Production 16009' 7" 231 sx Class 'G' 16042' 7689' Liner Perforation depth: measured 15590'- 15604', 15649'- 15737'.~\ ~' ...~} ~ true vertical 7313' - 7323', 7358' - 7427' ;:':,':i 200! Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 15479' /~las~(a 0il & Gas Cons. ComrnJssJor~ Anchorage Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 15. Attachments 16. Status of well classifications as: [] Copies of Logs and Surveys run [] Oil [] Gas [] Suspended Service [] Daily Report of Well Operations 17. I hereby certify that the fore~.ing is true and correct to the best of my knowledge Signed ~~~__ Title TechnicalAssistant Date -- Prepared By Name/Nurnbec Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 Submit In Du ~ PEORATIoN Page1 of 1 Summary Report Legal Well Name: MPF-78 Common Well Name: MPF-78 Spud Date: 9/16/1995 Event Name: RE ENTER Start: 10/5/2001 End: Contractor Name: NABORS Rig Release: Rig Name: NABORS 4ES Rig Number: ~? Date ~ Hours~iActi~ity ~ode ~PT !:phase ~!~?~'~ I~~'°?~ :~ ~:~~:~ ~i ~ Description of Operations 10/6/2001 01:00 - 03:30 2.50 MOB P DECOMP RAISE AND SCOPE DERRICK. ACCEPT RIG AT 01:00 HRS. RU LINES TO TREE. 03:30 - 04:00 0.50 KILL P DECOMP PULL BPV. TBG = 650 PSI. CSG = 700 PIS. 04:00 - 04:30 0.50 KILL P DECOMP TEST LINES TO 3,500 PSI. 04:30 - 08:00 3.50 KILL P DECOMP CIRCULATE AND CONDITION WELL WITH HOT SEA WATER. 08:00 - 09:00 1.00 KILL P DECOMP SHUT IN AND MONITORED WELL. 09:00 - 14:00 5.00 KILL :P DECOMP ORDERED 9.0 BRINE. FILLED PITS WITH SAME. 14:00 - 16:30 2.50 KILL P DECOMP CIRCULATED WELL WITH 9.0 BRINE. 16:30 - 17:00 0.50 PULL P DECOMP SET TWC. 17:00- 18:00 1.00 PULL P DECOMP N/D TREE. 18:00 - 21:00 3.00 PULL 3 DECOMP N/U BOPs. 21:00 - 00:00 3.00 PULL 3 DECOMP TESTED BOPs AND CHOKE MANIFOLD TO 250 PSI LOW AND 3,500 PSI HIGH. BOP TEST WAS WITNESSED BY CHUCK SCHEVE, AOGCC REPRESENTATIVE. 10/7/2001 00:00 - 00:30 0.50 PULL ~ DECOMP COMPLETE BOPE TEST. 00:30 - 01:30 1.00 PULL 3 DECOMP RU LUBRICATOR. PULL TWCV. 01:30 - 02:30 1.00 'PULL ~ DECOMP PU LANDING JT. PULL AND LD TBG HANGER. 02:30 - 12:30 10.00 PULL ~ DECOMP POOH WITH 2 7/8" TBG AND ESP ASSY. 12:30 - 15:00 2.50 PULL ~ DECOMP CUT AND REMOVED ESP CABLE. INSPECTED AND LAID DOWN ESP ASSY. 15:00 - 15:30 0.50 PULL P DECOMP CLEARD RIG FLOOR. 15:30 - 18:00 2.50 PULL P DECOMP P/U AND SERVICED ESP. 18:00 - 00:00 6.00 PULL P DECOMP RIH WITH 2 7/8 COMPLETION. 10/8/2001 00:00 - 02:00 2.00 REST P DECOMP RIH WITH 2 7/8 COMPLETION. RAN 80 STANDS. 02:00 - 05:00 3.00 REST P DECOMP MADE SPLICE IN ESP CABLE. 05:00 - 10:00 5.00 REST P DECOMP CONTINUED TO RIH WITH 2 7/8 COMPLETION. 10:00 - 10:30 0.50 REST P DECOMP MADE UP HANGERAND LANDING JOINT. 10:30 - 12:30 2.00 REST P DECOMP MADE EFT SPLICE AND TESTED CONNECTION. 12:30- 13:00 0.50 REST ~P DECOMP LANDED HANGER. TBG WT UP 80K, WT DOWN 40K. RILDS. 13:00 - 13:30 0.50 REST P DECOMP SET TWC AND TESTED SAME. DRAINED STACK. BLOW DOWN HARDLINES. 13:30- 15:00 1.50 REST ~ DECOMP N/D BOP. 15:00 - 16:00 1.00 REST ~ DECOMP N/U TREE. 16:00 - 16:30 0.50 REST ~ DECOMP TESTED ADAPTOR FLANGE AND TREE TO 5,000 PSI. 16:30 - 17:30 1.00 REST 3 DECOMP P/U LUBRICATOR. PULLED TWC. SET BPV. L/D i LUBRICATOR. 17:30- 18:00 0.50 REST P DECOMP HB&R FREEZE PROTECTED WELL. BULLHEADED 15 : BBLS DIESEL IN TBG AND 65 BBLS IN ANNULUS. SECURED CELLAR AND TREE. RELEASED RIG AT 18:00 HRS ON 10-8-01. ! Printed: 10/15/2001 12:37:34PM THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001, M E PL A'~T E IA L UN D W E R T H IS M ARK E R C -3_OP. AM~iLNEDO C ...... STATE OF ALASKA ALASKA ,J~L AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: I--IOperation Shutdown F-lStimulate ~] Plugging i~ Perforate F-] Pull Tubing [-IAIter Casing [~ Repair Well I~Other 2. Name of Operator ]5. Type of well: 6. BP Exploration (Alaska)Inc. I [~ Development [] Exploratory 7. 3. Address ~1Stratigraphic P.O. Box 196612, Anchorage, Alaska 99519-6612 E]Service 4. Location of well at surface 8. 2237' NSL, 2555' WEL, SEC. 6, T13N, R10E 9. At top of productive interval 4013' NSL, 764' WEL, SEC. 30, T14N, R10E At effective depth 4223' NSL, 750' WEL, SEC. 30, T14N, R10E At total depth 4272' NSL, 748' WEL, SEC. 30, T14N, R10E Datum Elevation (DF or KB) KBE = 47.54' Unit or Property Name Milne Point Unit Well Number MPF-78 Permit Number / Approval No. 95-144 10. APl Number 50-029-22599 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 16070 feet Plugs (measured) true vertical 7714 feet Effective depth: measured 15959 feet Junk (measured) true vertical 7615 feet Casing Length Size Structural Conductor Surface Intermediate Production Liner 90' 30" 7884' 9-5/8" Cemented 260 sx Arcticset (Approx.) 1555 sx PF 'E' 250 sx 'G', 250 sx PF 'E' 16009' 7" 231 sx Class 'G' MD 'I-VD 90' 90' 7919' 4497' 16042' 7689' Perforation depth: measured true vertical 15590'-15604', 15649'-15737' 7313'-7324', 7358'-7427' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 to 15383' Packers and SSSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure A.~ch0rarl~ 14. Prior to well operation: Representative Daily Average Production or Iniection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Subsequent to operation: 5. Attachments I16. Status of well classifications as: I-1 Copies of Logs and Surveys run I J~) Oil l--I Gas [--J Suspended [] Daily Report of Well Operations 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~,~ ~ Terrie Hubble.· . Title Technical Assistant III Prepared By Name/Number: Service Terrie Hubble, 564-4628 --~-'%%1" Submit In Duplicat Form 10-404 Rev. 06/15/88 Facility Date/Time 16 May 99 17 May 99 18 May 99 19 May 99 Progress Report M Pt F Pad Well MPF-78 Page 1 Rig Nabors 4ES Date 20 May 99 01:00-06:00 06:00-10:00 10:00-17:30 17:30-23:00 23:00-23:30 23:30-00:30 00:30-03:00 03:00-06:00 06:00-06:30 06:30-09:00 09:00-13:30 13:30-01:30 01:30-06:00 06:00-06:30 06:30-08:30 08:30-13:30 13:30-16:30 16:30-18:00 18:00-20:00 20:00-00:00 00:00-02:30 02:30-03:00 03:00-05:00 05:00-06:00 06:00-09:00 Duration 5hr 4hr 7-1/2 hr 5-1/2 hr 1/2 hr lhr 2-1/2 hr 3hr 1/2 hr 2-1/2 hr 4-1/2 hr 12 hr 4-1/2 hr 1/2 hr 2hr 5hr 3hr 1-1/2 hr 2hr 4hr 2-1/2 hr 1/2 hr 2hr lhr 3hr Activity Rig moved 50.00 % Rig moved 100.00 % Fill pits with Brine Circulated closed in well at 15300.0 ft Installed Hanger plug Rigged down Xmas tree Rigged up BOP stack Tested BOP stack Held safety meeting Retrieved Tubing hanger Circulated at 15339.0 ft Pulled Tubing in stands to 15339.0 ft Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Rigged up sub-surface equipment - ESP Ran Tubing in stands to 3000.0 ft Serviced ESP Ran Tubing in stands to 5700.0 ft Circulated at 7500.0 ft Ran Tubing in stands to 15338.0 ft Installed Tubing hanger Rigged down BOP stack Installed Xmas tree Freeze protect well - 13.000 bbl of Diesel Cleared Sand traps MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christenson~ DATE: May 17, 1999 Chairman THRU: Blair Wondzell, P. I. Supervisor FROM: Lawrence M Wade¢;~~ SUBJECT: Petroleum Inspector FILE NO: awqgeqgf. DOC BOP Test Nabors 4S BPX MPU F-78 PTD 95-144 May 17,1999: i left the office at midnite to witness a BOP test at Milne Pt on Nabors 4S. On arriving they were just finishing nippling up and we proceeded to test. Everything passed except for the floor valve. It was replaced with another and the new one held. Because of the recent rig layoffs the crew was very experienced and seemed to work well together and in a safe manner. SUMMARY: Witnessed a BOP test on Nabors 4S, 1 failure, 3.5 hours. Attachments- awqgeqgf, xis cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: Drlg Contractor: Nabors Rig No. 4S PTD # 95-144 Rig Ph.# Operator: BPX Rep.: Larry Myers Well Name: F-78 Rig Rep.: Gene Sweatt Casing Size: 7" Set @ 16,042 Location: Sec. 2 T. 13N R. gE Meridian Test: Initial X Weekly Other Test Pressures 250/5000 5/17/gg Umiat MISC. INSPECTIONS: Location Gen.: ok Housekeeping: ok (Gen) PTD On Location n/a Standing Order Posted Well Sign X Drl. Rig X Hazard Sec. X FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F 250/5000 250/5000 250/5000 F 250/5000 P BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. 250/3000 1 250/5000 250/5000 I 250/5000 1 250/5000 2 250/5000 1 250/5000 P n/a P/F P MUD SYSTEM: Visual Alarm Trip Tank X X Pit Level Indicators X X Flow Indicator X X Meth Gas Detector X X H2S Gas Detector X X CHOKE MANIFOLD: No. Valves 11 No. Flanges Manual Chokes 1 Hydraulic Chokes I Test Pressure P/F 250/5000 P 22 250/5000 P Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 4 5oo 3,000 [ 1,800 minutes 28 sec. minutes 12 sec. X Remote: X Psig. Number of Failures: 1 ,Test Time: 3,5 Hours. Number of valves tested 15 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Wdtten or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Floor valve failed. Was replaced with another which held. Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Larry Wade F1-021L (Rev. 12J94) awqgeqgf.)ds STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2237' NSL, 2555' WEL, SEC. 6, T13N, R10E At top of productive interval 4013' NSL, 764' WEL, SEC. 30, T14N, R10E At effective depth 4233' NSL, 750' WEL, SEC.30, T14N, R10E At total depth 4272' NSL, 748' WEL, SEC. 30, T14N, R10E 5. Type of well: [~],Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KB) KBE = 47.54' 7. Unit or Property Name Maine Point Unit 8. Well Number MPF-78 9. Permit Number / Approval No. 95-144 10. APl Number 50- 029-22599 11. Field and Pool Maine Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 16070 true vertical 7714 Effective depth: measured 15959 true vertical 7615 Casing Length Structural Conductor Surface Intermediate Production Liner feet feet feet feet Size Plugs (measured) Junk (measured) Cemented 96' 30" 260 sx Arctic Set (Approx.) 7884' 9 5/8" 1555 sx PF 'E', 250 sx 'G' 250 sx PF 'E' 16009' 7" 231 sx Class 'G' MD TVD 113' 113' 7919' 4497' 16O42' 7689' Perforation depth: measured true vertical 15649' - 15737', 15590' - 15604' (Subsea) 7313' - 7382', 7268' - 7278' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 15280' Packers and SSSV (type and measured depth) ORIGINAL 13. Stimulation or cement squeeze summary RECEIVED 14. Intervals treated (measured) Treatment description including volumes used and final pressure J U L 2. ,~ '~9 N~ska 0il & Gas Cons. 6ommissiotl Anchorage Representati~.~Daily Average Production or Injection Data Prior to well operation: Subsequent to operation: OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run ~.Daily Report of Well Operations 16. Status of well classifications as: [~ Oil I---I Gas I---] Suspended Service 7. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ';~;"'J/~~/¢-'/'/'~~ ~-~'. /~-¢¢j.¢,-.~-~_~- Title Staff Technical Assistant Date Prepared By Name/Number: Jeanne L. Haas, 564-5225 Facility Date/Time 20 Jun 98 21 Jun 98 22 Jun 98 23 Jun 98 24 Jun 98 Progress Report M Pt F Pad Well MPF-78 Page 1 Rig Nabors 5S Date 15 July 98 06:00-06:15 06:15-03:30 03:30-05:00 05:00-06:00 06:00-06:15 06:15-11:00 11:00-13:00 13:00-17:30 17:30-18:00 18:00-18:15 18:15-20:30 20:30-01:30 01:30-02:30 02:30-06:00 06:00-06:15 06:15-07:00 07:00-08:00 08:00-09:30 09:30-11:30 11:30-15:00 15:00-19:00 19:00-20:00 20:00-23:30 23:30-06:00 06:00-06:15 06:15-07:00 07:00-09:30 09:30-15:30 15:30-18:30 18:30-19:30 19:30-21:30 21:30-23:00 23:00-00:30 00:30-06:00 Duration 1/4 hr 21-1/4 hr 1-1/2 hr lhr 1/4hr 4-3/4 hr 2hr 4-1/2 hr 1/2 hr 1/4 hr 2-1/4 hr 5hr lhr 3-1/2 hr 1/4 hr 3/4 hr lhr 1-1/2 hr 2hr 3-1/2 hr 4hr lhr 3-1/2 hr 6-1/2 hr 1/4 hr 3/4 hr 2-1/2 hr 6hr 3hr lhr 2hr 1-1/2 hr 1-1/2 hr 5-1/2 hr Activity Held safety meeting Rig moved 100.00 % Bleed down well Circulated at 15400.0 ft Held safety meeting Bullhead well Removed Xmas tree Installed BOP stack Pulled Tubing on retrieval string to 15378.0 ft Held safety meeting Retrieved Tubing hanger Pulled Tubing in stands to 7500.0 ft Serviced ESP Pulled Tubing in stands to 1700.0 ft Held safety meeting Pulled Tubing in stands to 1500.0 ft Circulated at 1500.0 ft Pulled Tubing in stands to 0.0 ft Rigged down sub-surface equipment - ESP Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Held safety meeting Installed ESP Ran Tubing in stands to 6900.0 ft Held safety meeting Ran Tubing in stands to 8000.0 ft Functioned ESP Ran Tubing in stands to 15339.0 ft Functioned ESP Installed Tubing hanger Removed BOP stack Installed Xmas tree Displace treatment Rigged down Drillfloor / Derrick STATE OF ALASKA ALASI',J-~, OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing []Alter Casing [] Repair Well [] Other ESP Changeout 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2237' NSL, 2555' WEL, Sec. 6, T13N, R10E, UM At top of productive interval 4013' NSL, 764' WEL, Sec. 30, T14N, R10E, UM At effective depth 4223' NSL, 750' WEL, Sec. 30, T14N, R10E, UM At total depth 4272' NSL, 748' WEL, Sec. 30, T14N, R10E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE = 48' 7. Unit or Property Name Milne Point Unit 8. Well Number MPF-78 9. Permit Number / Approval No. 95-144 10. APl Number 50- 029-22599 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical 16070' feet 7714' feet 15959' feet 7615' feet Length Size 90' 30" 7884' 9 5/8" 16009' 7" Plugs (measured) Junk (measured) Cemented MD TVD 15649'-15737',15590'-15604' 7358'-7427',7313'-7324' 260 sx Arctic Set (approx.) 90' 90' 1555 sx PF 'E', 250 sx 'G', 7919' 4497' 250 sx PF 'E' 231 sx Class 'G' 16042' 7689' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 15409' Packers and SSV (type and measured depth) None 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Chip Alvord /~,~ ~ ~ Title Engineering Supervisor Date *" Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Duplicate,~ SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPF-78 Rig Name: N-4ES AFE# 339051 Accept Date: 07/11/97 Spud Date: - Release Date: 07/14/97 JULY 12, 1997 RIG ACCEPTED @ 2000 HRS 07/11/97. MOVE RIG FROM MPU F-69 TO F-78, RIG UP LEVEL DERRICK & SAFE OUT EQUIPMENT. PULL BPV & RIG LINES TO TREE & TT. FILL PITS W/SEA H20 & TEST LINES TO 3000 PSI. TBG. PSI 30. ANNULUS 450 PSI & DISPLACE WELL BORE INFLUX W/SEA H20 & MONITOR SAME (OK) @ 3 BPM PSI 2600. INSTALL TWC & ND TREE & NU BOP'S. JULY 13, 1997 CONT. NU BOP'S. TEST BOP'S TO 250 LOW & 5000 HIGH (TEST WAIVED BY DOUG AMOS W/AOGCC). PULL TWC & MU LANDING JT & BOLDS. ATTEMPT TO PULL HANGER TO FLOOR PULLING 89% OF TENSIL & UNABLE CIRC. N-VIS TO SLICK SEA H20 & ADD 4 DRUMS OF LUBE TEX LESS THAN 1% BY VOLUME & GO TO 90% OF TENSIL & BEGIN TO GET TRAVEL MTR. FREE @ APP 80% OF YIELD. POOH W/ESP ASSY. HAD HANG UP @ 13700' 8 STDS. OUT OF WORK FREE. LD ESP ASSY. FOUND PIN 3" LONG BY 3,4" DIAMETER ON PHD AS ASSY WAS PULLED TO FLOOR & IT HAD CHARACTERISTIC THAT LOOKS AS IF IT WAS WHAT HAD THE ASSY STUCK (POSSIBLE SHORT @ SPLICE @ HANGER WAS THE ELECTRICAL PROBLEM RECOVERED ALL LASALLE CLAMPS & PROTECTALIZERS. RIG HES W/ROLLER STRING TO GET A TD TAG. JULY 14, 1997 RIH W/3.75" SWEDGE & TAG @ 15857' RIG DN HES. MU & SERVICE ESP ASSY. TIH W/ESP ASSY. MAKE MID-LINE SPLICE. TIH W/ESP ASSY. MAKE MID-LINE SPLICE. RIH W/ESP COMP. CHG. SPOOLS & SPLICE CABLE. CONT. TO RIH W/ESP COMP & MU HGR & PENETRATOR. SPLICE HANGER & PENETRATOR & TEST SAME. LAND TBG. HGR & RILDS & INSTALL TWC. ND BOP'S & NU COMP TREE. TEST ADAPTER FLG. & TREE TO 5000 PSI & FINAL ESP CABLE CHECK. JULY 15, 1997 RIG UP LINE TO TREE, TEST, TREEZE PROTECT WELL TO 2000' W/DIESEL & RIG DOWN LINES & SECURE TREE. RIG RELEASED @ 1000 HRS 07/14/97. Page 1 of ! PERMIT 95-144 AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS ~f/MWD SPERRY'S FM EVAL Page: 1 Date: 02/25/98 RUN RECVD 04/10/96 95-144 CN/DENS - MD ~'~SEPIA ~?~0'O- I(~q 01/24/96 95-144 CN/DENS - TVD Jzf SEPIA 01/24/96 95-144 EWR/GR - MD 01/24/96 95-144 EWR/GR - TVD ~SEPIA 95-144 GR/CCL ~SEPIA 01124/96 04/16/96 95-144 CL/PERF SEPIA 1 05/03/96 95-144 PLS 1 05/03/96 95-144 PLS/STATIC 9192-9495 1 07/19/96 95-144 GR/CCL 10 -407 DAILY WELL OPS 1 07/19/96 ~ f'~ ,.~ :' / / Are dry ditch samples Was the well cored? Are well tests required? yes Well is in compliance ~ Initial COMMENTS required? yes ~And received? yes. yes '0~Q~Analysis & description received? ~_~Received? ~e_~u__m~~ ~O ye~5~-Tr~ ANNULAR INJECTION DATA ENTRY SCREEN A s s e t .Miine ........................................ Rig Name .~ab3r. s.2.7..E ........................... Inj Well Name JVI,P.I~.,;ZB .................................. Permit Sur Csg Dep .7..0.~.5 .............. Cumulative Data Legal Desc 223.Z'.~SL,..2.5,55:~/F_L,..S~c..6,,.T..1.31~l,...B.1.QE ........................ Research ........................................................................................................................ COP~ EC~'JED..CO .P..Y..S UI~ M L'I3L'E D..T.O, AQG CC. ............. 2.:.2/~.:.9.Z ..................................................................................... Start ...... 9.~..1.2.:.9.5 ..... Permit E n d ....1.2 J..3..1.J..9.5... Rig Completion Formation Intermittant ; Final Well Total :: Mud/Ct(] Wash : : Fluids:;: FlUids ' Freeze ;::Freeze i Source Well MPF-70 ....MPF-70 MPF-70 MPF-70 MPF-70 MPF-70 MPF-70 MPF-70 MPF-70 MPF~70 ! Date of t Injection Daily Data Mud, Ctgs, Cmt II ' ~l----~;~i-'--~'Freeze : : :R® ~ 't--'--"----Annulus COntaminated Rig Wash ~ Drg MUd Fluids I Fluids FlUids ] Protection [ piOtect On I TOtal PressUre! Status I Comments comPlicalions 1995 Summan/ 140 4O5 170 5OO 781 MPF-70 MPF-70 MPF-70 10/10/95 ..!_.~../...~_..!../_9_...5.._ 110/12/95 10/13/95 10/14/95 10/1 5/95 260 I 10/16/95 46O 10/17/95 _6.65 10/18/95 ,..2.55 10/19/95 100 10/20/95 0. 10/21/95 802 10/22/95 380 10/23/95 175 10/24/95 418 ..... STATE OF ALASKA ALASt... OIL AND GAS CONSERVATION C..,',4MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 95-144 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22599 4. Location of well at surface ................. 9. Unit or Lease Name 2237' NSL, 2555' WEL, SEC. 6, T13N, R10E i ~.;~:i'..~; ~'i¥"_~,; : ~--i~.~7,./~.?.i;~i~ Milne Point Unit Attop of productive interval ~ ~ ¥'*~'~b~ ;- 10. Well Number '~ ~~~ MPF-78 4013' NSL, 764' WEL, SEC. 30, T14N, R10E~ ,,,-~r.:.~,,,;..,.;~.~:,_, ~ :~ .~:~,. : ~:. At total depth 4272' NSL, 748' WEE, SEC. 30, T14N, R10EI~. ......... i ,~ a ~~"~: ~' , 11. Field and Pool Milne Point Unit / Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 47.54'I ADL 355018 12. Date Spudded 113. Date T.D. Reached 114. Date Comp., Susp., or Aband.115. Water depth, if offshore 16. No. of Completions 09/16/95I 09130/95I 07/10/96I N/A MSL One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+-I-VD) 19. Directional Survey 20. Depth where SSSV set~l. Thickness of Permafrost 16070 7714 FT~ 15959 7615 FT [] Yes [] No N/A MD ! 1800' (Approx.) 22. Type Electric or Other Logs Run MWD, Gyro, LWD, GR, RES, NED, DEN 23. CASING, LINER AND CEMENTING RECORD CASING SE-FrING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 30" 91.1# NTSOLHE Surface 90' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# NTSOLHE 35' 7919' 12-1/4" 1555 sx PF 'E', 250 sx 'G', 250 sx PF 'E' 7" 26# L-80 33' 16042' 8-1/2" 231 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 4-1/2" Gun Diameter, 5 spf 2-7/8", 6.5#, L-80 15413' MD TVD MD TVD 15649' - 15737' 7358' - 7427' 15590' - 15604' 7313' - 7324' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 15649' - 15737' Frac'd w/37,000# 16/20 Carbolite Behind Pipe 15649' - 15737' Frac'd w/123,500# 16/20 Carbolite Behind Pipe Freeze Protect with 77 Bbls of Diesel 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) May 18, 1996 I Electric Submersible Pump Date of Test Hours Tested PRODUCTION FOR O~L-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing PressureCALCULATED I~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Sub~it~o~e ~h~P~ ED ORIGINAL Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate Geologic Mark · 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Kuparuk D 15378' 7153' Kuparuk C 15589' 7312' Kuparuk B 15603' 7323' Kuparuk A 15642' 7353' Kuparuk A3 15649' 7358' Kuparuk A2 15669' RECEIVED Kuparuk A1 15697' 7395' S F_.P ,5 0 ' 996 Miluveach 15739' 7429' Naska Oil & Gas Cons. commissiot~ Anchorage 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is true. and co~rrect to the best of my knowledge Signed 'Rm Schofield //-, Prepared By Name/Number: Terrie Hubbl~, 56,~-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Inj. Well Name IMP :F~61:i' Legal Desc (Sec, T, R) SurfCsgDep 16585 I Well Cum Total Cum Mud/Ctg[~i~ [ Cum Brinel~i~ ? I cum Waterf~i~ 1cum ~'es'~" VOLUME (BBLS ~t4ethod of displosal=pumping down outer annulus SOURCE WELL DATE OF DIESEL/~R~ZEI/ / NUMBER INJECTION MUD/CTGS BRINE WATER PROT. Daily Cum. Total COMPLICATIONS, COMMENTS MP F-69 8 / 31 / 9 5 2 0 UP F-69 9 / 1 / 9 5 2 60 MR F-69 9/2/9 5 2 65 MP F-69 9/3/95 ~o~ I ; MP F-69 9/6/95 4~o.oo I ~~1 MP F-eS 9/7/95 3~.00 ! ~~1 MP F-69 9/8/95 1~7.00 ! ~~1 MP F-69 9/9/9 5 188.00 I BP F-69 9/10/95 293.00 P F-69 ~,~,~ 0.00 I ~1 aP F-78 9/1 3/95 113.00 Inj. Well Name o Legal Desc ~ c~_ (Sec, T, R) !.i..I L~J Well Cum Total Cum Mud/Ctg[iii~iiiil 1 Cum Brine Cum Water Cum Dies/FP VOLUME (BBLS Method of displosal=pumping down outer annulus I SOURCENuMBERWELL INJECTIoNDATE OF MUD/CTGS BRINE WATER DIESEL/PRoT.FREEZEI Daily Cum. Total COMPLICATIONS, COMMENTS ! UP F-78 9 / 1 6 / 95 0 MR F-78 9/1 7/95 110.00 UP F-78 9/18/95 250.00 ] i ", ...... ~,~,~,,i,,~,::,~, MR F-78 9/1 9/95 200.00 aP F-78 9/2 0/95 350.00 BP F-78 9/21/95 443.00 MP F-78 9/23/95 1790.00 I M P F-78 9 / 24 / 95 307.00 M..-~ 9/~/e~ ~.oo I ~'~ ~'~;~ MP F-78 9/26/95 53O.OO 'P F-78 9/27/95 586.00 MR F-78 9/28/95 632.00 MP F-78 9/29/95~ 125.00 MR F-78 9/30/95 240.00 'MR F-78 10/1/95 130.00 MP F-78 10/2/95 1815.00 MP F-78 1 0/3/95 1050.00 75.00]~ :~]~]~]]~]~'.~ ~ ' ..... ~,,~,~i BP/AAI SHARED SERVICE DAILY OPERATION~ PAGE: 1 WELL: MPF-78 BOROUGH: NORTH SLOPE UNIT: UNKNOWN FIELD: UNKNOWN LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 09/16/95 01:00 SPUD: RELEASE: OPERATION: DRLG RIG: NABORS 27E WO/C RIG: NABORS 27E 09/17/95 ( 1) TD: 700' ( 0) 09/18/95 (2) TD: 2693' (1993) 09/19/95 (3) TD: 4365' (1672) 09/20/95 (4) TD: 5659' (1294) 09/21/95 (5) TD: 7160' (1501) DRILLING MW: 0.0 VIS: 0 FINISH SETTING PITS, PUT WELLHEAD & TBG SPOOL IN CELLAR. SET MOTOR COMPLEX, REMOVE JEEP, BERM PITS & MOTOR COMPLEX. LOWER PIPE CHUTE. FILL PITS WITH WATER. LAY PIPE SHED MATS. HOOK UP ELECTRICAL, AIR & WATER LINES. SET PIPE SHEDS & LEVEL. SET 20 HYDRIL ON CONDUCTOR. NU DIVERTER, SET DIESEL TANKS, PARTS HOUSE & WATER TANK. BERM. SET & BERM CUTTINGS TANK. LEVEL PIPESHED. MIX MUD, NU DIVERTER, RISER, FLOWLINE. SET MOUSEHOLE. TAKE 5" E DP OUT OF PIPESHED. LOAD BHA IN SHED. MU BHA, TAG CEMENT @ 49'. LD MWD, FUNCTION TEST DIVERTER. DRILL F/49' T/269'. LD HWDP, PICK UP BHA. NU BHA ORIENT MOTOR WITH MWD, UPLOAD MWD. KELLY UP, DRILL F/269 T/700' SHORT TRIP MW: 0.0 VIS: 0 DRILL F/700' T/961'. REPAIR CUTTINGS DRAG CHAIN & FLOWLINE. DRILL F/961' T/2223'. REPAIR CUTTINGS DRAG CHAIN. DRILL F/2223' T/2693'. PUMP SWEEP, CIRC HOLE CLEAN. MONITOR WELL, SHORT TRIP T/1800' TRIP FOR BIT MW: 0.0 VIS: 0 RIH T/2560'. KELLY UP, WASH TO 2693'. OK. NO FILL. DRILL F/2693' T/4365'. PUMP LO-HI VIS SWEEP. MONITOR WELL, PUMP DRY JOB. POOH T/2191'. HOLE SWABBING. KELLY UP, CIRC & WORK PIPE. SET BACK KELLY. POOH, CHANGE BIT. RIH, COAT STABILIZERS WITH EMI/192, DOWNLOAD MWD, CHANGE OUT PULSER. DRILLING MW: 0.0 VIS: 0 UPLOAD PULSER, RIH T/4301', KELLY UP, DO CHECK SHOT SURVEY. WASH T/4365'. OK. NO FILL. DRILL F/4365' T/5628'. PUMP SWEEP, CIRC HOLE CLEAN. SHORT TRIP T/4393'. OK. NO FILL. DRILL F/5628' T/5659'. TRIP FOR BIT MW: 0.0 VIS: 0 DRILL F/6005' T/6795' CIRC SWEEP, CHECK FOR FLOW. SHORT TRIP T/5845'. DRILL F~6795' T/7160'. PUMP SWEEP, CIRC HOLE CLEAN. CHECK FOR FLOW. PUMP DRY JOB. POOH, TRIED TO SWAB MOST OF THE WAY OUT OF HOLE @ DC. WELL ' MPF-78 OPERATION: RIG : NABORS 27E PAGE: 2 09/22/95 (6) TD: 7945' ( 785) 09/23/95 (7) TD: 7945' ( 0) 09/24/95 (8) TD: 7945' ( 0) 09/25/95 ( 9) TD:10015' (2070) 09/26/95 (10) TD:l1307' (1292) RIH AFTER SHORT TRIP MW: 0.0 VIS: 0 DOWNLOAD MWD. BREAKOUT BIT. LD MOTOR. PU NEW MOTOR, BIT. ORIENT MWD. RIH T/7086' MD. TAG UP SOLID. LD 3 JTS. REAM F/7034' T/7160'. DRILLING F/7160' T/7427'. REPAIR WASHED OUT MUD LINE BETWEEN PUMPS. DRILLING F/7427' T/7945'. CIRC & COND FOR SHORT TRIP. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. POOH SLM TO HWDP. MONITOR WELL. CLEAN FLOOR. BEGIN RIH. PREPARE ND DIVERTER MW: 0.0 VIS: 0 FINISH RIH T/7945' MD. SWEEP HOLE. CIRC & COND MUD. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. POOH WITH DP. LD BHA. CLEAR FLOOR. RU TO RUN 9-5/8" 40# NT80LHE CASING. LAND CASING @ 0130 HRS, 09/23/95 @ 7881' MD PUT WT 365K, SO WT 75K WITH 9.5 PPG MUD. BREAK CIRC. WORK UP TO 10.5 BPM. CIRC & COND HOLE @ 10.5 BPM. FULL RETURNS WHILE CIRC/COND. HALLIBURTON PUMPS 10 BBLS WATER. TEST LINES 3000 PSI. OK. HALLIBURTON PUMPS ADDITIONAL 65 BBL WATER. HALLIBURTON PUMPS 601 BBL TYPE 'E' PF CEMENT. HALLIBURTON DROPS BOTTOM & TOP PLUG. RIG TAKES OVER & DISPLACES WITH 584 BBL WATER. STEADY PRESSURE INCREASE FROM TIME CEMENT WENT AROUND SHOE. ESTIMATE FULL RETURNS DURING CEMENT JOB. BUMP PLUG @ 5840 STROKES AWAY. CIP @ 0615 HRS.,09/23/95. RIH TO DRILLOUT FLOAT EQP MW: 0.0 VIS: 0 BLEED OFF CASING PRESSURE. CHECK FLOATS. OK. FLUSH FLOWLINE WITH WATER. DRAIN STACK, LD LANDING JT & CASING RUNNING EQUIP. ND MOUSEHOLE, FLOWLINE, RISER & HYDRIL. WASH OUT HYDRIL. PERFORM TOP JOB. NU FMC GEN 5 SPLIT SPEED HEAD SYSTEM & XO. NU BOPE. SET RISER & FLOWLINE. RU ATLAS WIRELINE & GYRO DATA. WLIH T/7475' MD. LOG OUT OF HOLE. RD ATLAS WIRELINE. TEST BOPE. WITNESSING WAIVED BY BOBBY FOSTER @ AOGCC. MU BHA. ORIENT MWD. LOAD SOURCES. FINISH MU BHA. RIH LAYING CHANGING OUT HWDP WITH BAD HARDBAND. SLIP & CUT DRILLING LINE. ADJUST BRAKES. SET CROWNAMATIC. RIH WITH DP. BREAK CIRC. TEST CASING T/3000 PSI FOR 30 MIN. OK. BLEED OFF PRESSURE. LD 1 STD OF DP. RIH & PREPARE DRILLOUT FLOAT COLLAR, SHOE JTS, FLOAT SHOE & 10' NEW HOLE. CBU FOR SHORT TRIP MW: 0.0 VIS: 0 FINISH RIH T/7793' MD. PU KELLY. TAG FLOAT COLLAR @ 7833' DRILL FLOAT COLLAR, SHOE JTS, FLOAT SHOE & 10' OF NEW HOLE T/7955'. CBU. PERFORM LEAKOFF TEST T/12.6 PPG EMW WITH 8.5 PPG @ 4508'. DRILLING F/7955' T/10015'. CBU BEFORE SHORT TRIP. DRILLING MW: 0.0 VIS: 0 FINISH CBU. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. SHORT TRIP F/10015' TO 9-5/8" CASING SHOE. OK. FLOWCHECK WELL. OK. RIH. OK. NO FILL. DRILLING F/10015' T/ 11307' Anchorage WELL : MPF-78 OPERATION: RIG : NABORS 27E PAGE: 3 09/27/95 (11) TD:12221' ( 914) 09/28/95 (12) TD:14074' (1853) 09/29/95 (13) TD:15060' ( 986) 09/30/95 (14) TD:15812' ( 752) 10/01/95 (15) TD:16070' ( 258) 10/02/95 (16) TD:16070 PB: 0 10/03/95 (17) TD:16070 PB: 0 DRILLING MW: 0.0 VIS: 0 DRILLING F/11307' T/11324'. CBU. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. POOH. FLOWCHECK WELL @ SHOE. OK. FLOWCHECK @ HWDP. OK. CONT POOH WITH BHA. DOWNLOAD MWD. UNLOAD SOURCES. CHANGE BIT. CUTTERS GRADED 1,1. BIT WAS IN GAUGE. BIT HAD SOME CHIPPED CUTTERS AROUND THE BIT BETWEEN THE SHOULDER & GAUGE PADS. CHIPPING WAS ON THE BODY OF THE CUTTER BEHIND THE FACE OF THE CUTTER. CUTTERS ON NOSE & SHOULDER OF BIT WERE IN VERY GOOD CONDITION. LD BIT. CHANGE OUT BIT. RIH & CHANGEOUT PULSER. LD HYDRAULIC JARS. PU MECHANICAL JARS. FILL PIPE @ 4000' & 8000'. FINISH RIH. NO FILL. OK. DRILLING F/11324' T/11688'. DRILLING F/11688' T/12221' DRILLING MW: 0.0 VIS: 0 DRILLING F/12438' T/12755'. DRILLING F/12755' T/13257'. CIRC LO/HI VISC SWEEP AROUND. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. SHORT TRIP T/Il200'. HOLE IN GOOD SHAPE. RIH. OK. NO FILL. DRILLING F/13257' T/13508'. DRILLING F/13508' T/14074' REPAIR WASHOUT #1 PUMP MW: 0.0 VIS: 0 DRILLING T/14915'. REPLACE LINER AND SWAB ON MUD PUMP #1. DRILLING T/15060'. REPAIR WASHOUT ON FLANGE BETWEEN MUD END AND PULSATION DAMPNER ON MUD PUMP #1. DRILLING MW: 0.0 VIS: 0 CIRC SWEEP AROUND. HOLE CLEAN. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. SHORT TRIP 20 STDS. RIH. OK. NO FILL. DRILLING F/15060' T/15812' RIH MW: 0.0 VIS: 0 DRILLING F/15812' T/16070'. FINISH PUMPING SWEEP AROUND. FLOWCHECK WELL. OK. PUMP DRY JOB. POOH SLM. LD 9 SINGLES. CONT POOH TO CASING SHOE. NO CORRECTION TO SLM. PULL DP. SLIP & CUT DRILLING LINE. RIH. PREPARE RIH W/7" CASING MW: 0.0 BOPE TEST WAIVED BY JOHN SPAULDING WITH AOGCC. FINISH RIH. REAM LAST 9 SINGLES TO BOTTOM. OK. CIRC & COND MUD TO RUN 7" CASING. FLOWCHECK WELL. OK. PUMP DRY JOB. SET BACK KELLY. POOH. LDDP. LD BHA. DOWNLOAD LWD. REMOVE SOURCES. PULL WR. CHANGE TOP SET OF PIPE RAMS T/7" TEST DOOR SEALS. OK. CIRC & COND MW: 0.0 RU & RUN 7" CASING. CIRC @ 9-5/8" CASING SHOE. CONT TO RUN 7" CASING. MU HANGER & LANDING JT. LAND CASING. MU CEMENT HEAD. BROKE CIRC DUE TO LOST MUD WHILE RIH WITH CASING.. TRIED DIFFERENT RATES, COULD NOT INCREASE RETURNS. WELL ' MPF-78 OPERATION: RIG : NABORS 27E PAGE: 4 10/04/95 (18) TD:16070 PB: 0 MIRU MW: 0.0 HOWCO PUMP, TEST LINES, PUMP WATER, SPACER, RELEASE BOTTOM PLUG, PUMP CEMENT, FLUSH LINES, RELEASE TOP PLUG, PUMP DIESEL, BUMPED PLUG W/ CALCULATED STROKES, TEST CASING, CHECKED FLOATS. OK. RD HOWCO EQUIP. LD LANDING JT & CASING TOOLS. INSTALL PACKOFF & TEST. SET TUBING HANGER, INSTALL 2-WAY CHECK. CHANGE TOP RAMS TO 5". ND MOUSEHOLE, BLOWDOWN MUD LINES. ND FLOWLINE, RISER, CHOKE & KILL LINES. ND STACKE & SET BACK. NU TREE, FILL W/ DIESEL & TEST. PULL 2-WAY CHECK, INSTALL BP VALVE. SECURE WELL, CLEAN CELLAR & PITS. FINISH INJECTING, BLOW DOWN LINES. MOVE RIG TO MPF-70. RIG RELEASED @ 2200 HRS., 10/03/95. SIGNATURE: (drilling superintendent) DATE: S~='ERRY-SUN DRILLING SERVICES ANCHORAGE ALAS KA PAGE St-DARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 MWD SURVEY JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORD DEGREES DG/100 NORTH/SOUTH EAST INATES VERT. /WEST SECT. 0 .00 -47.54 100 100.00 52.46 200 199.98 152.44 300 299.97 252.43 400 399.95 352.41 0 0 0 48 0 57 1 2 0 49 N .00 E .00 .00N S 17.96 W .81 .67S S 69.99 W .79 1.63S 1 S 50.80 W .35 2.50S 2 N 81.44 W .79 2.97S 4 .00E .00 .22W -.70 .22W -1.80 .72W -2.87 .15W -3.55 500 499.93 452.39 600 599.84 552.30 700 699.62 652.08 800 799.27 751.73 900 898.82 851.28 1 38 2 55 4 34 4 58 5 5O N 10.62 W 1.58 1.45S 5 N 1.18 E 1.36 2.50N 5 N 7.49 E 1.70 9.00N 4 N 8.61 E .41 17.23N 3 N 10.36 E .90 26.52N 2 .13W -2.20 .34W 1.68 .77W 8.19 .60W 16.50 .03W 25.93 1000 998.11 950.57 1100 1097.17 1049.63 1200 1196.06 1148.52 1300 1294.52 1246.98 1400 1392.12 1344.58 7 43 8 0 9 2 11 1 14 3 N 10.67 E 1.87 38.14N N 11.80 E .32 51.55N 2 N 10.66 E 1.05 66.08N 5 N 14.47 E 2.09 83.06N 9 N 13.96 E 3.03 104.10N 14 .13E 37.73 .79E 51.39 .67E 66.19 .51E 83.55 .83E 105.14 1500 1488.71 1441.17 1600 1584.64 1537.10 1700 1679.48 1631.94 1800 1773.01 1725.47 1850 1819.58 1772.04 15 55 16 50 20 5 21 21 21 17 N 12.43 E 1.92 129.28N 20 N 11.47 E .95 156.87N 26 N 10.33 E 3.27 187.98N 32 N 10.17 E 1.27 222.80N 38 N 10.06 E .15 240.70N 42 .71E 130.92 .55E 159.08 .51E 190.72 .80E 226.09 .00E 244.27 1900 1866.13 1818.59 2000 1958.43 1910.89 2050 2004.19 1956.65 2100 2049.87 2002.33 2150 2095.27 2047.73 21 31 23 42 23 49 24 10 25 21 N 10.25 E .46 258.67N 45 N 10.37 E 2.18 296.48N 52 N 10.18 E .29 316.31N 55 N 10.98 E .97 336.30N 59 N 10.19 E 2.43 356.88N 63 .21E 262.51 .10E 300.94 .69E 321.07 .42E 341.39 .27E 362.32 2200 2140.24 2092.70 2250 2184.71 2137.17 2300 2228.65 2181.10 2350 2272.05 2224.51 2400 2314.97 2267.43 26 27 27 55 29 6 30 22 31 21 N 9.87 E 2.22 378.39N 67 N 9.87 E 2.96 400.90N 70 N 9.60 E 2.37 424.43N 75 N 9.75 E 2.54 448.88N 79 N 9.28 E 2.02 474.18N 83 .07E 384.16 .99E 407.00 .02E 430.86 .19E 455.66 .43E 481.31 2450 2357.33 2309.79 2500 2399.04 2351.50 2550 2440.23 2392.69 2600 2480.95 2433.41 2650 2520.99 2473.45 32 47 34 7 34 58 35 55 37 39 N 8.89 E 2.91 500.40N 87 N 8.72 E 2.65 527.64N 91 N 8.47 E 1.72 555.67N 96 N 8.64 E 1.93 584.35N 100 N 8.55 E 3.44 613.95N 104 .62E 507.86 .84E 535.43 .08E 563.78 .39E 592.78 .87E 622.72 RECEIVED S~-ERRY-SUN DRILLING SERVICES ANCHOPJ%GE ALASKA PAGE 2 SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/9 DATE OF SURVEY: 093095 MWD SURVEY JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPEP~ATOR: BP EXPLORATION FT. TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA VERTICAL DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2700 2560 2750 2599 2800 2637 2850 2674 2900 2712 .39 .19 .27 .96 .29 2512 2551 2589 2627 2664 .85 38 20 .65 39 52 .73 40 55 .42 41 13 .75 42 8 N 8.38 E 1.40 644.40N 109.40E N 9.21 E 3.23 675.56N 114.22E N 9.52 E 2.16 707.53N 119.49E N 8.95 E .96 739.96N 124.77E N 9.05 E 1.83 772.80N 129.97E 653.50 685.03 717.43 750.29 783.54 2950 2749 3000 2785 3050 2821 3100 2856 3150 2889 .38 .93 .46 .08 .73 2701 2738 2773 2808 2842 .84 42 6 .39 43 56 .92 45 28 .54 46 52 .19 48 31 N 8.93 E .17 805.93N 135.21E N 8.80 E 3.66 839.63N 140.47E N 8.80 E 3.06 874.39N 145.85E N 8.53 E 2.85 910.05N 151.28E N 8.20 E 3.32 946.63N 156.66E 817.07 851.18 886.35 922.42 959.40 3200 2922 3250 2953 3300 2984 3350 3014 3400 3042 .34 .93 .52 .12 .70 2874 2906 2936 2966 2995 .80 50 3 .39 51 33 .98 53 0 .58 54 23 .16 55 52 N 7.55 E 3.23 984.17N 161.85E N 7.43 E 3.01 1022.59N 166.90E N 7.73 E 2.92 1061.79N 172.12E N 7.55 E 2.79 1101.72N 177.47E N 7.30 E 2.99 1142.40N 182.77E 997.30 1036.04 1075.58 1115.87 1156.88 3450 3070 3500 3097 3550 3122 3600 3146 3650 3169 .42 .10 .37 .52 .88 3022 3049 3074 3098 3122 .88 .56 .83 .98 .34 56 47 58 42 60 32 61 42 62 34 N 7.40 E 1.87 1183.67N 188.10E N 7.15 E 3.82 1225.61N 193.45E N 6.97 E 3.71 1268.42N 198.75E N 7.05 E 2.30 1311.87N 204.09E N 8.25 E 2.76 1355.68N 209.98E 1198.48 1240.75 1283.87 1327.63 1371.83 3700 3192 3750 3214 3800 3235 3850 3256 3900 3276 .65 .51 .51 .21 .45 3145 3166 3187 3208 3228 .11 .97 .97 .67 .91 63 15 64 54 65 25 65 40 66 34 N 9.02 E 1.92 1399.69N 216.66E N 9.81 E 3.59 1444.04N 224.02E N 9.60 E 1.11 1488.77N 231.67E N 9.67 E .52 1533.64N 239.29E N 9.64 E 1.80 1578.71N 246.95E 1416.34 1461.30 1506.67 1552.17 1597.88 3950 3295 4000 3313 4100 3346 4200 3376 4300 3403 .77 .82 .91 .15 .53 3248 3266 3299 3328 3355 .23 .28 .37 .60 .99 67 57 69 42 71 38 74 21 73 50 N 10.26 E 3.01 1624.13N 254.92E N 9.89 E 3.57 1670.03N 263.08E N 8.82 E 2.18 1763.13N 278.41E N 7.92 E 2.85 1857.73N 292.32E N 8.74 E .94 1952.89N 306.25E 1643.98 1690.58 1784.92 1880.54 1976.71 4400 3431.53 4500 3460.24 4600 3490.34 4700 3521.01 4800 3551.68 3383.99 73 37 3412.70 73 0 3442.80 71 58 3473.47 72 18 3504.14 71 57 N 8.52 E .30 2047.80N 320.66E N 8.17 E .71 2142.57N 334.56E N 8.27 E 1.03 2236.95N 348.20E N 8.07 E .39 2331.17N 361.72E N 8.36 E .45 2425.37N .375.32E 2072.71 2168.50 2263.86 2359.04 2454.21 PAGE 3 ~-~.ERRY-SUN DRILLING SERVICES ~-., ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 MWD SURVEY JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDI DEGREES DG/100 NORTH/SOUTH EAST/ NATES VERT. WEST SECT. 4900 3582.40 3534.86 72 15 5000 3613.04 3565.50 72 3 5100 3643.00 3595.46 73 4 5200 3672.35 3624.81 72 47 5300 3702.17 3654.63 72 30 N 7.22 E 1.13 2519.65N 388 N 6.68 E .55 2614.14N 399 N 6.22 E 1.10 2708.94N 410 N 6.22 E .28 2803.97N 420 N 6.41 E .33 2898.84N 431 .22E 2549.37 .74E 2644.52 .45E 2739.86 .81E 2835.37 .31E 2930.75 5400 3732.21 3684.67 72 31 5500 3762.62 3715.08 72 3 5600 3794.37 3746.83 70 55 5700 3826.79 3779.25 71 14 5800 3857.86 3810.32 72 33 N 6.01 E .38 2993.66N 441 N 5.53 E .66 3088.44N 451 N 5.60 E 1.14 3182.82N 460 N 6.03 E .52 3276.93N 469 N 6.55 E 1.41 3371.40N 480 .63E 3026.05 .21E 3121.20 .40E 3215.89 .98E 3310.38 .40E 3405.35 5900 3887.78 3840.24 72 6000 3916.97 3869.43 73 6100 3945.36 3897.82 73 6200 3972.74 3925.20 74 6300 3999.65 3952.11 74 37 26 34 38 8 N 6.84 E .28 3466.17N 491 N 7.74 E 1.19 3561.03N 503 N 7.81 E .15 3656.04N 516 N 7.99 E 1.08 3751.30N 529 N 8.65 E .81 3846.59N 543 .52E 3500.72 .66E 3596.34 .63E 3692.21 .85E 3788.38 .79E 3884.69 6400 4028.39 3980.85 72 27 6500 4058.74 4011.20 72 11 6600 4089.54 4042.00 71 55 6700 4120.29 4072.75 72 16 6800 4150.96 4103.42 72 0 N 8.35 E 1.70 3941.31N 557 N 8.20 E .30 4035.60N 571 N 8.14 E .29 4129.77N 585 N 7.58 E .64 4224.03N 598 N 7.59 E .27 4318.38N 610 .94E 3980.46 .66E 4075.74 .18E 4170.88 .19E 4266.03 .75E 4361.19 6900 4182.35 4134.81 71 24 7000 4213.94 4166.40 71 45 7100 4244.58 4197.04 72 33 7200 4274.38 4226.84 72 45 7300 4304.48 4256.94 72 12 N 7.97 E .69 4412.45N 623 N 7.60 E .50 4506.45N 636 N 7.24 E .87 4600.85N 648 N 7.73 E .51 4695.49N 661 N 7.25 E .72 4790.03N 673 .61E 4456.12 .46E 4550.99 .75E 4646.16 .18E 4741.60 .62E 4836.95 7400 4335.39 4287.85 71 46 7475 4358.40 4310.86 72 28 7542 4379.26 4331.72 71 41 7638 4408.69 4361.15 72 18 7732 4438.02 4390.48 71 34 N 6.53 E .81 4884.45N 685 N 6.72 E .96 4955.35N 693 N 7.66 E 1.75 5019.39N 701 N 7.85 E .67 5109.17N 713 N 8.21 E .85 5198.26N 726 .02E 4932.01 .26E 5003.35 .34E 5067.88 .56E 5158.48 .13E 5248.44 7825 4467.17 4419.63 71 44 7871 4481.62 4434.08 71 25 7941 4504.48 4456.94 70 49 8036 4534.38 4486.84 72 16 8131 4562.88 4515.34 73 1 N 8.11 E .20 5285.30N N 8.23 E .74 5328.25N N 7.10 E 1.74 5394.50N N 8.12 E 1.85 5483.30N N 7.99 E .81 5573.63N 738.61E 5336.38 744.78E 5379.76 753.70E 5446.60 765.56E 5536.18 778.35E 5627.40 ?--~ERRY-SUN DRILLING SERVICES~'--' ANCHORAGE ALASKA PAGE 4 SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/9 DATE OF SURVEY: 093095 MWD SURVEY JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 8226 4590.27 4542.73 8321 4617.17 4569.63 8417 4644.66 4597.12 8512 4673.67 4626.13 8607 4703.83 4656.29 73 21 73 46 72 53 71 27 71 44 N 8.03 E .35 5663.42N 790.98E N 8.07 E .44 5753.74N 803.76E N 7.59 E 1.04 5844.72N 816.27E N 7.99 E 1.56 5934.12N 828.50E N 7.36 E .69 6023.95N 840.60E 5718.07 5809.30 5901.12 5991.34 6081.98 8702 4733.10 4685.56 8796 4761.18 4713.64 8892 4788.28 4740.74 8986 4814.72 4767.18 9081 4841.98 4794.44 72 11 73 10 73 48 73 41 73 1 N 8.34 E 1.10 6113.04N 852.89E N 9.25 E 1.38 6202.04N 866.66E N 9.21 E .67 6292.30N 881.33E N 8.67 E .56 6381.92N 895.42E N 9.00 E .78 6472.09N 909.44E 6171.90 6261.96 6353.40 6444.12 6535.37 9176 4870.70 4823.16 9269 4901.36 4853.82 9364 4933.48 4885.94 9460 4965.86 4918.32 9556 4997.99 4950.45 71 35 70 6 70 15 70 22 70 24 N 8.98 E 1.52 6561.02N 923.51E N 9.87 E 1.82 6648.13N 937.96E N 10.00 E .20 6735.89N 953.34E N 9.19 E .80 6825.12N 968.42E N 9.68 E .48 6914.06N 983.20E 6625.41 6713.69 6802.77 6893.25 6983.39 9650 5029.48 4981.94 9744 5059.42 5011.88 9837 5088.69 5041.15 9931 5118.33 5070.79 10026 5147.99 5100.45 70 36 71 59 71 39 71 26 72 9 N 8.51 E 1.19 7001.88N 997.26E N 8.28 E 1.50 7089.39N 1010.17E N 7.51 E .86 7177.69N 1022.42E N 6.64 E .91 7265.86N 1033.36E N 7.86 E 1.43 7355.30N 1044.74E 7072.33 7160.79 7249.93 7338.74 7428.88 10122 5176.99 5129.45 10214 5204.11 5156.57 10309 5231.32 5183.78 10404 5258.52 5210.98 10498 5286.12 5238.58 72 35 73 21 73 16 73 24 72 32 N 7.33 E .70 7445.78N 1056.81E N 8.13 E 1.17 7533.52N 1068.72E N 8.80 E .68 7623.31N 1082.08E N 8.34 E .49 7713.20N 1095.63E N 8.37 E .92 7802.38N 1108.72E 7520.15 7608.69 7699.46 7790.37 7880.51 10592 5314.02 5266.48 10686 5341.68 5294.14 10782 5369.28 5321.74 10876 5396.22 5348.68 10972 5423.90 5376.36 72 45 72 59 73 29 73 21 73 7 N 8.54 E .28 7890.66N 1121.85E N 9.87 E 1.38 7979.26N 1136.20E N 10.73 E 1.01 8069.43N 1152.59E N 10.54 E .24 8158.37N 1169.29E N 10.91 E .45 8248.69N 1186.40E 7969.76 8059.50 8151.11 8241.54 8333.40 11067 5452.53 5404.99 11162 5481.63 5434.09 11260 5510.54 5463.00 11353 5537.44 5489.90 11448 5565.36 5517.82 71 54 72 19 73 19 73 9 72 39 N 11.17 E 1.31 8337.88N 1203.80E N 10.90 E .52 8426.35N 1221.05E N 10.85 E 1.02 8518.17N 1238.69E N 10.40 E .49 8605.98N 1255.17E N 9.88 E .74 8695.36N 1271.15E 8424.18 8514.24 8607.66 8696.95 8787.71 P~ERRY-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 MWD SURVEY JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORD DEGREES DG/100 NORTH/SOUTH EAST I NAT E S /WEST VERT. SECT. 11542 5593.66 5546.12 11638 5623.66 5576.12 11732 5654.06 5606.52 11824 5684.44 5636.90 11919 5715.37 5667.83 72 5 N 10.11 E .64 8783.13N 1286 71 32 N 10.06 E .58 8873.05N 1302 70 43 N 9.41 E 1.08 8960.73N 1317 70 52 N 10.42 E 1.04 9046.68N 1332 70 56 N 9.09 E 1.33 9134.73N 1347 .62E .61E .66E .68E .82E 8876.80 8968.10 9057.04 9144.28 9233.59 12013 5745.53 5697.99 12108 5774.24 5726.70 12203 5802.86 5755.32 12298 5832.53 5784.99 12387 5860.30 5812.76 71 50 N 8.31 E 1.24 9223.30N 1361 72 45 N 8.33 E .96 9312.32N 1374 72 11 N 7.95 E .70 9402.07N 1387 71 28 N 6.84 E 1.34 9491.76N 1398 72 4 N 7.99 E 1.40 9575.41N 1409 .37E .39E .23E .87E . 76E 9323.19 9413.16 9503.82 9594.25 9678.58 12486 5890.82 5843.28 12579 5919.85 5872.31 12673 5949.84 5902.30 12767 5980.76 5933.22 12862 6013.24 5965.70 72 11 N 7.82 E .20 9669.17N 1422 71 28 N 6.88 E 1.23 9756.92N 1434 71 1 N 7.20 E .59 9844.59N 1444 70 35 N 8.48 E 1.36 9932.56N 1457 69 38 N 10.47 E 2.20 10021.14N 1471 .78E .10E .92E .03E .81E 9773.24 9861.69 9950.00 10038.79 10128.59 12959 6046.71 5999.17 13049 6076.99 6029.45 13140 6106.58 6059.04 13236 6137.01 6089.47 13330 6166.80 6119.26 69 56 N 9.04 E 1.42 70 39 N 10.01 E 1.29 71 30 N 10.50 E 1.05 71 26 N 9.66 E .83 71 37 N 10.43 E .80 10110.72N 1487.21E 10194.12N 1501.21E 10279.08N 1516.58E 10368.48N 1532.47E 10456.33N 1548.03E 10219.47 10304.01 10390.32 10481.08 10570.28 13425 6196.54 6149.00 13519 6226.50 6178.96 13614 6256.80 6209.26 13706 6285.99 6238.45 13802 6316.10 6268.56 71 45 N 10.43 E .15 71 22 N 10.07 E .54 71 21 N 10.00 E .08 71 41 N 8.49 E 1.60 71 37 N 9.44 E .95 10544.72N 1564.30E 10633.19N 1580.30E 10721.67N 1595.96E 10807.94N 1610.00E 10897.67N 1624.16E 10660.10 10749.96 10839.79 10927.19 11018.03 13897 6346.33 6298.79 13992 6377.17 6329.63 14088 6410.32 6362.78 14183 6446.43 6398.89 14278 6485.77 6438.23 71 20 N 8.48 E 1.00 70 43 N 7.51 E 1.16 68 36 N 6.63 E 2.38 66 38 N 7.19 E 2.15 64 31 N 6.65 E 2.28 10986.84N 1638.22E 11075.71N 1650.70E 11164.50N 1661.72E 11251.58N 1672.27E 11337.61N 1682.71E 11108.30 11198.04 11287.47 11375.16 11461.79 14372 6528.04 6480.50 14467 6574.42 6526.88 14561 6623.02 6575.48 14656 6675.14 6627.60 14751 6730.16 6682.62 62 2 N 6.25 E 2.67 59 50 N 6.25 E 2.30 57 39 N 5.28 E 2.50 55 31 N 4.95 E 2.27 54 1 N 5.57 E 1.66 11421.08N 1692.15E 11545.73 11504.05N 1701.24E 11629.12 11583.71N 1709.29E 11709.10 11662.39N 1716.33E 11787.95 11739.98N 1723.47E 11865.74 ?mERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 MWD SURVEY JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPEP~ATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS INCLN DIRECTION DG MN DEGREES DG/100 TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST VERT. SECT. 14845 6787.21 6739.67 51 30 N 6.01 E 2.70 11814.64N 14941 6848.19 6800.65 49 30 N 6.07 E 2.09 11888.21N 15036 6911.02 6863.48 47 18 N 7.48 E 2.57 11958.49N 15127 6973.72 6926.18 45 33 N 8.22 E 2.01 12023.79N 15222 7040.41 6992.87 44 55 N 6.38 E 1.53 12090.50N 1731.04E 11940.70 1738.82E 12014.60 1747.16E 12085.34 1756.15E 12151.26 1764.70E 12218.49 15318 7108.88 7061.34 44 4 N 5.90 E .95 12157.41N 15411 7177.63 7130.09 41 33 N 6.64 E 2.74 12220.74N 15506 7248.62 7201.08 40 48 N 5.81 E .98 12282.48N 15599 7319.89 7272.35 40 5 N 4.91 E .98 12342.98N 15693 7392.18 7344.64 38 50 N 4.34 E 1.39 12402.33N 1771.91E 12285.73 1778.85E 12349.39 1785.59E 12411.45 1791.27E 12472.12 1796.08E 12531.52 15786 7466.10 7418.56 35 48 N 3.42 E 3.32 12458.57N 15880 7545.37 7497.83 30 1 N 4.60 E 6.17 12509.76N 15946 7603.52 7555.98 25 57 N 1.45 E 6.57 12540.60N 16070 7714.35 7666.81 25 57 N 1.45 E .00 12594.52N 1799.91E 12587.71 1803.45E 12638.85 1805.14E 12669.60 1806.51E 12723.13 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 12723.42 FEET AT NORTH 8 DEG. 9 MIN. EAST AT MD = 16070 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 8.55 DEG. RECEIVED SEP o Alaska Oil & Gas Cons. Commissio~ Anchorage ~-~ERRY-SUN DRILLING SERVICES · ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 0 .00 -47.54 .00 N .00 E .00 1000 998.11 950.57 38.14 N .13 E 1.89 2000 1958.43 1910.89 296.48 N 52.10 E 41.57 3000 2785.93 2738.39 839.63 N 140.47 E 214.07 4000 3313.82 3266.28 1670.03 N 263.08 E 686.18 1.89 39.68 172.50 472.10 5000 3613.04 3565.50 2614.14 N 399.74 E 1386.96 6000 3916.97 3869.43 3561.03 N 503.66 E 2083.03 7000 4213.94 4166.40 4506.45 N 636.46 E 2786.06 8000 4523.35 4475.81 5449.15 N 760.69 E 3476.65 9000 4818.48 4770.94 6394.63 N 897.36 E 4181.52 700.78 696.07 703.02 690.59 704.87 10000 5139.85 5092.31 7330.27 N 1041.29 E 4860.15 11000 5431.90 5384.36 8274.59 N 1191.39 E 5568.10 12000 5741.25 5693.71 9210.37 N 1359.48 E 6258.75 13000 6060.58 6013.04 10148.24 N 1493.18 E 6939.42 14000 6379.57 6332.03 11082.53 N 1651.60 E 7620.43 678.63 707.95 690.65 680.67 681.01 15000 6886.38 6838.84 11932.01 N 1743.68 E 8113.62 16000 7651.41 7603.87 12563.90 N 1805.73 E 8348.59 16070 7714.35 7666.81 12594.52 N 1806.51 E 8355.65 493.19 234.98 7.06 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ,~-ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 8 SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 0 .00 -47 47 47.54 147 147.54 100 247 247.54 200 347 347.54 300 .54 .00 .00 .00 .00 .00 N .00 E .05 S .02 W 1.28 S .47 W 1.93 S 1.97 W 3.00 S 3.40 W .00 .00 .00 .01 .01 .02 .01 . 04 .02 447 447.54 400 547 547.54 500 647 647.54 600 748 747 . 54 700 848 847 . 54 800 .00 .00 .00 .00 .00 2.77 S 4.79 W .03 S 5.35 W 5.04 N 5.25 W 12.82 N 4.26 W 21.44 N 2.95 W .05 .01 .09 .04 .23 .13 .54 .31 .92 .38 948 947.54 900 1049 1047.54 1000 1150 1147 . 54 1100 1252 1247.54 1200 1354 1347 . 54 1300 .00 .00 .00 .00 .00 31.58 N 1.11 W 44.74 N 1.39 E 58.58 N 4.24 E 74.32 N 7.30 E 93.85 N 12.26 E 1.45 .53 2.34 .90 3 .34 .99 4.62 1.28 6.64 2.02 1457 1447.54 1400 1561 1547.54 1500 1666 1647.54 1600 1772 1747.54 1700 1880 1847.54 1800 .00 .00 .00 .00 .00 117.85 N 18.18 E 145.87 N 24.31 E 176.85 N 30.44 E 212.99 N 37.04 E 251.45 N 43.91 E 9.66 3.02 13.69 4.03 18.57 4.88 25.11 6.54 32.48 7.36 1988 1947.54 1900 2097 2047.54 2000 2208 2147.54 2100 2321 2247.54 2200 2438 2347.54 2300 .00 .00 .00 .00 .00 291.78 N 51.24 E 40.57 8.09 335.27 N 59.22 E 49.91 9.34 381.97 N 67.69 E 60.61 10.70 434.83 N 76.78 E 74.10 13.49 494.18 N 86.65 E 90.82 16.72 2558 2447.54 2400 2683 2547.54 2500 2813 2647.54 2600 2947 2747.54 2700 3087 2847.54 2800 .00 .00 .00 .00 .00 560.73 N 96.83 E 111.39 20.57 634.34 N 107.91 E 136.07 24.68 716.32 N 120.97 E 166.06 29.99 804.29 N 134.95 E 199.98 33.92 901.03 N 149.93 E 239.96 39.98 3239 2947.54 2900. 3408 3047.54 3000. 3602 3147.54 3100. 3828 3247.54 3200. 4102 3347.54 3300. · 00 1014.61 N 165.86 E 292.19 52.22 00 1149.48 N 183.68 E 361.08 68.90 00 1313.75 N 204.33 E 454.61 93.53 00 1514.77 N 236.07 E 581.44 126.83 00 1765.03 N 278.70 E 754.49 173.05 ~-'ERRY-SUN DRILLING SERVICES A/~CHOR3AGE ALASKA PAGE SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 JOB NTJMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 4456 3447.54 3400.00 4786 3547.54 3500.00 5115 3647.54 3600.00 5450 3747.54 3700.00 5765 3847.54 3800.00 2101.38 N 328.64 E 1008.95 2412.78 N 373.47 E 1239.08 2723.77 N 412.07 E 1468.05 3041.96 N 446.67 E 1703.38 3338.77 N 476.65 E 1918.03 254.46 230.13 228.97 235.32 214.65 6107 3947.54 3900.00 6463 4047.54 4000.00 6788 4147.54 4100.00 7109 4247.54 4200.00 7438 4347.54 4300.00 3663.37 N 517.64 E 2160 4001.08 N 566.68 E 2415 4307.94 N 609.36 E 2641 4610.20 N 649.94 E 2862 4921.22 N 689.24 E 3091 .17 .83 .39 .34 .42 242.14 255.65 225.56 220.96 229.08 7762 4447.54 4400.00 8079 4547.54 4500.00 8427 4647.54 4600.00 8749 4747.54 4700.00 9100 4847.54 4800.00 5226.54 N 730.21 E 3315 5524.04 N 771.38 E 3531 5853.99 N 817.50 E 3779 6157.80 N 859.53 E 4002 6490.07 N 912.29 E 4253 .32 .89 .74 .35 .34 223.90 216.56 247.85 222.61 250.99 9406 4947.54 4900.00 9705 5047.54 5000.00 10025 5147.54 5100.00 10366 5247.54 5200.00 10706 5347.54 5300.00 6774.48 N 960.11 E 7053.22 N 1004.91 E 7353.93 N 1044.55 E 7676.73 N 1090.28 E 7998.13 N 1139.49 E 4458 4658 4877 5118 5358 .64 .16 .55 .59 .79 205.30 199.52 219.39 241.04 240.20 11051 5447.54 5400.00 11388 5547.54 5500.00 11712 5647.54 5600.00 12020 5747.54 5700.00 12345 5847.54 5800.00 8322.89 N 1200.84 E 8638.79 N 1261.19 E 8942.34 N 1314.61 E 9229.35 N 1362.25 E 9536.41 N 1404.32 E 5604 5840 6064 6272 6498 .10 .92 .98 .65 .33 245.31 236.82 224.05 207.67 225.69 12666 5947.54 5900.00 12961 6047.54 6000.00 13269 6147.54 6100.00 13585 6247.54 6200.00 13901 6347.54 6300.00 9837.95 N 1444.08 E 10112.97 N 1487.57 E 10399.42 N 1537.74 E 10694.66 N 1591.20 E 10990.39 N 1638.75 E 6718 6914 7121 7338 7554 .53 .44 .99 .25 .06 220.19 195.92 207.54 216.27 215.81 14185 6447.54 6400.00 14413 6547.54 6500.00 14607 6647.54 6600.00 14781 6747.54 6700.00 14940 6847.54 6800.00 11254.13 N 1672.59 E 11457.59 N 1696.15 E 11621.99 N 1712.81 E 11763.79 N 1725.80 E 11887.45 N 1738.74 E 7738.28 7866.31 7959.51 8033.54 8093.13 184.22 128.03 93.19 74.03 59.60 · PAGE 10 '--~ERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA SHARED SERVICES DRILLING MILNE POINT / MPF-78 500292259900 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/12/95 DATE OF SURVEY: 093095 JOB NUMBER: AK-MM-950947 KELLY BUSHING ELEV. = 47.54 OPEP~ATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 15089 6947.54 6900.00 11997.33 N 1752.34 E 8142.37 15232 7047.54 7000.00 12097.57 N 1765.50 E 8184.58 15371 7147.54 7100.00 12193.69 N 1775.79 E 8223.67 15504 7247.54 7200.00 12281.55 N 1785.50 E 8257.15 15635 7347.54 7300.00 12366.18 N 1793.27 E 8288.39 49.23 42 .21 39.09 33 .48 31.24 15763 7447.54 7400.00 12445.00 N 1799.06 E 8315.87 15883 7547.54 7500.00 12510.97 N 1803.54 E 8335.83 15995 7647.54 7600.00 12562.02 N 1805.68 E 8348.16 16070 7714.35 7666.81 12594.52 N 1806.51 E 8355.65 27.47 19.96 12.33 7.49 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS gyro/data B.P. EXPLORATION F-PAD, MPF-78 ~ ~ MILNE POINT, ALASKA Gyro Multishot Survey in 7 5/8" casing Survey date · 23 September, 1995 Job number · AK0995G296 RECEIVED SLF 3 0 ~996 ~as .l&l Oil & Gas Cons. Commission Anchorage SR296.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 October 6, 1995 Directional Information B.P. Exploration (Alaska) Inc. Petrotechnical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, AK 99519-6612 Re: F-Pad, MPF-78, Milne Point, Alaska Enclosed please find one (1) original and six copies (6) of the completed survey of Well #MPF-78 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely ~- · .. ..- / .-' ..~;.-.'"'~?" Robert J. Sh°up Operations Manager RS/gr Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data CONTENTS JOB NUMBER :AK0995G296 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR296.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR296.DOC gyro/data DISCUSSION JOB NUMBER' AK0995G296 Tool 080 was run in F-pad well number MPF-78 inside of 7 5/8" casing on Atlas 15/32 wireline. survey was run without problems. The SR296.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0995G296 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR296.DOC gyro/data 2. SURVEY DETAILS SR296.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0995G296 CLIENT: B.P. EXPLORATION RIG: Mast Truck LOCATION: Milne Point WELL: MPF-78 LATITUDE: 70.5050 LONGITUDE: W S U RVEY DATE: SURVEY TYPE : DEPTH REFERENCE: MAX. SURVEY DEPTH: 23-Sept, 1995 MULTISHOT IN 7 5/8" casing ROTARY TABLE ELEVATION 46.0 asl 7475.0 SURVEY TIED ONTO: N/A SURVEY INTERVAL: 100' and 50' through the build section UTM CO-ORDINATES: TARGET DIRECTION: 8.55 GRID CORRECTION: CALCULATION METHOD: not applicable MINIMUM CURVATURE SURVEYOR: STODDARD SR296.DOC gyro/data 3, OUTRUN SURVEY LISTING SR296.DOC A Gyro d a t a D i r e c t i o na i Survey for B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, ALASKA Job Number: AK0995G296 Run Date: 23-Sep-95 13:54:05 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 46 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 8.550 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i o na I S u rve y B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, Job Number: AK0995G296 ALASKA MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DOGLEG CLOSURE DEPTH SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. 0.0 0.00 0.00 0.0 0.0 -46.0 0.00 0.0 0.0 0.0 - 7475.0 FT. GYRODATA SURVEY RUN IN 4 1/2" TUBING. MEASURED DEPTHS REFERENCED TO R.K.B. HEIGHT OF 46.0 FT. ABOVE SEA LEVEL. Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .81 197.97 100.0 -.7 54.0 .81 .7 200.0 .96 249.99 200.0 -1.8 154.0 .78 2.0 300.0 1.05 230.80 300.0 -2.9 254.0 .35 3.7 400.0 .83 278.56 400.0 -3.5 354.0 .78 5.1 500.0 1.64 349.38 499.9 -2.2 453.9 1.58 5.3 600.0 2.92 1.18 599.9 1.7 553.9 1.35 5.9 700.0 4.57 7.48 699.6 8.2 653.6 1.71 10.2 800.0 4.97 8.60 799.3 16.5 753.3 .41 17.6 900.0 5.85 10.36 898.8 25.9 852.8 .90 26.6 1000.0 7.72 10.67 998.1 37.8 952.1 1.87 38.2 1100.0 8.00 11.80 1097.2 51.4 1051.2 .32 51.6 1200.0 9.04 10.66 1196.1 66.2 1150.1 1.05 66.3 1300.0 11.02 14.47 1294.6 83.6 1248.6 2.08 83.6 1400.0 14.05 13.96 1392.2 105.2 1346.2 3.03 105.2 1500.0 15.93 12.43 1488.8 130.9 1442.8 1.92 130.9 1600.0 16.84 11.47 1584.7 159.1 1538.7 .95 159.1 1700.0 20.09 10.33 1679.5 190.7 1633.5 3.28 190.8 1800.0 21.36 10.17 1773.1 226.1 1727.1 1.26 226.2 1850.0 21.30 10.05 1819.6 244.3 1773.6 .15 244.4 1900.0 21.52 10.25 1866.2 262.5 1820.2 .47 262.6 198.0 216.8 227.4 234.4 254.2 · 67 S .22 W 1.63 S 1.22 W 2.49 S 2.71 W 2.96 S 4.13 W 1.44 S 5.11 W 3.1 51.57 N 2.81 E 4.9 66.10 N 5.69 6.5 83.08 N 9.53 ~ 8.1 104.11 N 14.84 E 9.1 129.29 N 20.72 E 9.6 156.89 N 26.56 E 9.8 187.99 N 32.52 E 9.9 222.82 N 38.81 E 9.9 240.72 N 42.00 E 9.9 258.68 N 45.22 E 295.2 2.51 N 5.32 W 332.2 9.00 N 4.75 W 348.3 17.24 N 3.58 W 355.6 26.54 N 2.02 W .2 38.16 N .14 E A Gyro da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, Job Number: AK0995G296 ALASKA Page MEASURED DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH 'feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 200 205 210 215 220 0.0 0.0 0.0 0.0 0.0 23.70 10.37 1958.5 23.82 10.18 2004.3 24.18 10.98 2049.9 25.35 10.19 2095.3 26.45 9.87 2140.3 301.0 321.1 341.4 362.4 384.2 1912.5 2.18 301.1 10.0 . 1958.3 .27 321.2 10.0 2003.9 .98 341.5 10.0 2049.3 2.43 362.5 10.1 2094.3 2.23 384.3 10.1 296.51 N 52.10 E 316.33 N 55.70 E 336.32 N 59.43 E 356.91 N 63.28 378.41 N 67.08 E 225 230 235 240 245 250 255 260 265 270 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 0.0 27.93 9.87 2184.8 29.11 9.60 2228.7 30.38 9.74 2272.1 31.36 9.28 2315.1 32.80 8.89 2357.4 34.12 8.72 2399.1 34.97 8.47 2440.3 35.93 8.64 2481.0 37.65 8.55 2521.1 38.34 8.38 2560.5 407.0 430.9 455.7 481.3 507.9 535.5 563.8 592.8 622.8 653.5 2138.8 2.97 407.2 10.0 2182.7 2.37 431.0 10.0 2226.1 2.53 455.8 10.0 2269.1 2.02 481.5 10.0 2311.4 2.91 508.0 9.9 2353.1 2.65 535.6 9.9 2394.3 1.73 563.9 9.8 2435.0 1.93 592.9 9.7 2475.1 3.44 622.9 9.7 2514.5 1.40 653.7 9.6 400.93 N 71.00 E 424.46 N 75.03 E 448.91 N 79.20 E 474.21 N 83.44 E 500.43 N 87.63 E 527.67 N 91.85 E 555.70 N 96.08 E 584.38 N 100.40 E 613.99 N 104.87 E 644.43 N 109.40 E 275 280 285 290 295 0.0 0.0 0.0 0.0 0.0 39.87 9.21 2599.3 40.93 9.52 2637.4 41.23 8.95 2675.1 42.14 9.05 2712.4 42.11 8.93 2749.5 685.1 717.5 750.3 783.6 817.1 2553.3 2591.4 2629.1 2666.4 2703.5 3.24 685.2 9.6 2.16 717.6 9.6 .95 750.4 9.6 1.83 783.7 9.5 .17 817.2 9.5 675.60 N 114.23 E 707.57 N 119.50 ~' 740.00 N 124.77 _ 772.84 N 129.98 E 805.97 N 135.22 E 305 310 315 320 325 0.0 0.0 0.0 0.0 0.0 45.47 8.80 2821.7 46.88 8.53 2856.3 48.52 8.20 2889.9 50.06 7.55 2922.5 51.56 7.43 2954.1 886.3 922.4 959.4 997.3 1036.0 2775.7 2810.3 2843.9 2876.5 2908.1 3.36 886.4 9.5 2.84 922.5 9.4 3.33 959.5 9.4 3.24 997.3 9.3 3.00 1036.1 9.3 874.33 N 145.88 E 909.99 N 151.32 E 946.58 N 156.69 E 984.12 N 161.88 E 1022.54 N 166.93 E A Gyro d a t a D i r e c t i ona i Survey B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, Job Number: AK0995G296 ALASKA Page MEASURED I DEPTH feet N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3300.0 3350.0 3400.0 3450.0 3500.0 3.00 7.73 2984.7 4.39 7.55 3014.3 5.87 7.30 3042.9 6.80 7.40 3070.6 8.70 7.15 3097.3 1075.5 1115.8 1156.8 1198.5 1240.7 2938.7 2968.3 2996.9 3024.6 3051.3 2.92 1075.6 9.2 2.80 1115.9 9.2 2.99 1156.9 9.1 1.87 1198.5 9.0 3.83 1240.8 9.0 1061.75 N 1101.68 N 1142.36 N 1183.64 N 1225.58 N 172.15 E 177.51 E 182.81 E 188.14 193.49 E 3550.0 3600.0 3650.0 3700.0 3750.0 0.55 6.97 3122.6 1 . 70 7 . 05 3146 . 7 2.58 8.25 3170.1 3.25 9.02 3192.9 4 . 90 9 . 81 3214 . 7 1283.8 1327.6 1371.8 1416.3 1461.3 3076.6 3100.7 3124.1 3146.9 3168.7 3.71 1283.9 8.9 2.31 1327.6 8.8 2.75 1371.8 8.8 1.92 1416.3 8.8 3.59 1461.3 8.8 1268.39 N 1311.85 N 1355.66 N 1399.67 N 1444.03 N 198.79 E 204.13 E 210.02 E 216.71 E 224.06 E 3800.0 3850.0 3900.0 3950.0 4000.0 5.42 9.60 3235.7 1506.7 5.67 9.67 3256.4 1552.2 6.57 9.64 3276.7 1597.9 7.96 10.26 3296.0 1644.0 9.71 9.89 3314.0 1690.6 3189.7 3210.4 3230.7 3250.0 3268.0 1.12 1506.7 8.8 .50 1552.2 8.9 1.81 1597.9 8.9 3.01 1644.0 8.9 3.56 1690.6 9.0 1488.76 N 1533.63 N 1578.70 N 1624.12 N 1670.03 N 231.71 E 239.33 E 246.99 E 254.96 E 263.12 E 4100.0 4200.0 4300.0 4400.0 4500.0 1.64 8.82 3347.1 4.36 7.92 3376.4 3.85 8.74 3403.7 3.63 8.52 3431.8 3.00 8.17 3460.5 1784.9 1880.6 1976.7 2072.7 2168.5 3301.1 3330.4 3357.7 3385.8 3414.5 2.18 1785.0 9.0 2.85 1880.6 8.9 .94 1976.8 8.9 .30 2072.8 8.9 .71 2168.6 8.9 1763.13 N 1857.73 N 1952.89 N 2047.81 N 2142.59 N 278.45 E 292.36 - 306.29 ~ 320.69 E 334.58 E 4600.0 4700.0 4800.0 4900.0 5000.0 1.97 8.27 3490.5 2.31 8.07 3521.2 1.96 8.36 3551.9 2.26 7.22 3582.6 2.06 6.68 3613.2 2263.9 2359.1 2454.2 2549.4 2644.5 3444.5 3475.2 3505.9 3536.6 3567.2 1.04 2263.9 8.8 .39 2359.1 8.8 .45 2454.3 8.8 1.12 2549.4 8.8 .56 2644.6 8.7 2236.97 N 2331.19 N 2425.39 N 2519.67 N 2614.16 N 348.21 E 361.74 E 375.34 E 388.24 E 399.76 E A Gyro da t a D i r e c t i o na I Survey B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, Job Number: AK0995G296 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 5100.0 73.07 6.22 3643.2 5200.0 72.79 6.22 3672.6 5300.0 72.51 6.41 3702.4 5400.0 72.53 6.01 3732.4 5500.0 72.06 5.53 3762.8 2739.9 2835.4 2930.8 3026.1 3121.2 3597.2 1.10 2739.9 8.6 3626.6 .29 2835.4 8.5 3656.'4 .33 2930.8 8.5 3686.4 .38 3026.1 8.4 3716.8 .66 3121.3 8.3 2708.96 N 410.48 E 2803.99 N 420.84 E 2898.86 N 431.34 ~ 2993.69 N 441.65 3088.46 N 451.22 E 5600.0 70.92 5.60 3794.6 5700.0 71.24 6.03 3827.0 5800.0 72.56 6.55 3858.1 5900.0 72.62 6.84 3888.0 6000.0 73.44 7.74 3917.2 3215.9 3310.4 3405.4 3500.8 3596.4 3748.6 1.14 3216.0 8.2 3781.0 .52 3310.5 8.2 3812.1 1.41 3405.5 8.1 3842.0 .28 3500.9 8.1 3871.2 1.19 3596.5 8.1 3182.84 N 460.41 E 3276.95 N 470.00 E 3371.43 N 480.41 E 3466.19 N 491.54 E 3561.06 N 503.68 E 6100.0 73.57 7.81 3945.6 6200.0 74.64 7.99 3973.0 6300.0 74.14 8.65 3999.9 6400.0 72.46 8.35 4028.7 6500.0 72.20 8.20 4059.0 3692.2 3788.4 3884.7 3980.5 4075.8 3899.6 .14 3692.4 8.0 3927.0 1.09 3788.6 8.0 3953.9 .81 3884.9 8.0 3982.7 1.70 3980.6 8.1 4013.0 .29 4075.9 8.1 3656.06 N 516.65 E 3751.32 N 529.87 E 3846.62 N 543.80 E 3941.34 N 557.96 E 4035.'63 N 571.66 E 6600.0 71.92 8.14 4089.8 6700.0 72.27 7.58 4120.6 6800.0 72.00 7.59 4151.2 6900.0 71.41 7.97 4182.6 7000.0 71.76 7.60 4214.2 4170.9 4266.1 4361.2 4456.2 4551.0 4043.8 .28 4171.1 8.1 4074.6 .64 4266.2 8.1 4105.2 .27 4361.4 8.1 4136.6 .69 4456.3 8.0 4168.2 .49 4551.2 8.0 4129.81 N 585.19 E 4224.07 N 598.20 4318.42 N 610.77 ~ 4412.49 N 623.62 E 4506.49 N 636.48 E 7100.0 72.56 7.24 4244.8 7200.0 72.76 7.73 4274.6 7300.0 72.21 7.25 4304.7 7400.0 71.78 6.53 4335.6 7475.0 72.48 6.72 4358.7 4646.2 4741.6 4837.0 4932.1 5003.4 4198.8 .88 4646.4 8.0 4228.6 .51 4741.9 8.0 4258.7 .72 4837.2 8.0 4289.6 .81 4932.3 8.0 4312.7 .98 5003.7 8.0 4600.89 N 648.77 E 4695.53 N 661.21 E 4790.08 N 673.64 E 4884.49 N 685.05 E 4955.40 N 693.28 E A Gy r o da t a D i r e c t i o na i Survey B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, ALASKA Job Number: AK0995G296 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL SUBSEA DEPTH DEPTH SECTION DEPTH feet deg. deg. feet feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet Final Station Closure: Distance: 5003.66 ft Az: 7.96 deg. A Gyro da t a D i r e c t i ona i Survey for B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, ALASKA Job Number: AK0995G296SS Run Date: 23-Sep-95 13:54:05 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.505000 deg. N Sub-sea Correction from Vertical Reference: 46 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 8.550 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i on a i S u rve y B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, Job Number: AK0995G296SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -46.0 0.00 0.00 0.0 0.0 0.00 0.0 - 7475.0 FT. GYRODATA SURVEY RUN IN 4 1/2" TUBING. MEASURED DEPTHS REFERENCED TO R.K.B. HEIGHT OF 46.0 FT. CLOSURE DIST. AZIMUTH feet deg. 0.0 0.0 ABOVE SEA LEVEL. Page HORIZONTAL COORDINATES feet 0.0 N 0.0 E 100.0 .88 221.90 146.0 -1.2 .80 200.0 1.00 241.16 246.0 -2.3 .58 300.0 .95 252.79 346.0 -3.2 .55 400.0 1.20 311.17 446.0 -2.9 1.15 500.0 2.23 354.82 546.0 -.4 1.47 600.0 3.68 4.10 646.0 4.7 1.51 700.0 4.76 8.01 746.0 12.1 1.10 800.0 5.38 9.43 846.0 20.9 .64 900.0 6.74 10.51 946.0 31.6 1.36 1000.0 7.86 11.21 1046.0 44.4 1.12 1100.0 8.51 11.24 1146.0 58.7 .68 1200.0 10.04 12.59 1246.0 75.0 1.58 1300.0 12.61 14.20 1346.0 94.9 2.58 1400.0 15.10 13.11 1446.0 119.5 2.41 1500.0 16.47 11.86 1546.0 147.7 1.34 1600.0 18.94 10.73 1646.0 179.5 2.45 1700.0 20.99 10.21 1746.0 215.9 1.85 1800.0 21.42 10.17 1846.0 254.6 .33 1900.0 23.41 10.35 1946.0 295.8 1.95 2000.0 24.15 10.91 2046.0 339.7 .91 2.0 206.6 3.7 221.7 5.1 230.6 5.3 243 .5 5.9 273.1 10.2 312.3 17.6 339.7 26.6 351.7 38.2 357.8 51.6 1.6 66.3 4.0 83.6 5.7 105.2 7.4 130.9 8.7 159.1 9.4 190.8 9.7 226.2 9.9 262.6 9.9 301.1 10.0 341.5 10.0 1.1 S .7 W 2.0 S 1.9 W 2.7 S 3.4 W 2.3 S 4.6 W 1.9 N 5.2 W 5.5 N 5.1 W 12.8 N 4.2 W 21.6 N 2.8 W 32.1 N 1.1 E 44.6 N 1.4 E 58.7 N 4.2 E 74.7 N 7.6 E 94.2 N 12.3 E 118.1 N 18.1 E 145.8 N 24.2 E 177.0 N 30.4 E 212.7 N 37.0 E 250.9 N 43.8 E 291.4 N 51.2 E 334.6 N 59.1 E A Gyro da t a D i r e c t i o na i S u rve y B.P. EXPLORATION WELL: F PAD, WELL NO. MPF-78 Location: MILNE POINT FIELD, Job Number: AK0995G296SS ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. VERTICAL VERTICAL DEPTH SECTION feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./, feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 26.64 9.87 2200.0 29.62 9.66 2300.0 32.41 8.99 2400.0 35.10 8.49 2500.0 38.09 8.44 2146.0 387.1 2246.0 440.8 2346.0 500.7 2446.0 567.9 2546.0 642.2 2.32 407.2 10.1 2.43 455.8 10.0 2.67 508.0 9.9 1.76 592.9 9.8 2.15 653.7 9.7 381.3 N 67.6 E 434.2 N 76.7 E 493.4 N 86.5 E 559.7 N 96.7 E 633.2 N 107.7 E 2600.0 41.00 9.39 2700.0 42.12 8.95 2800.0 46.46 8.61 2900.0 51.17 7.46 3000.0 55.98 7.31 2646.0 725.0 2746.0 814.0 2846.0 911.7 2946.0 1026.0 3046.0 1161.5 1.88 750.4 9.6 .32 817.2 9.5 2.99 922.5 9.5 3.06 1036.1 9.3 2.87 1198.5 9.1 715.0 N 120.7 E 802.9 N 134.7 E 899.4 N 149.7 E 1012.7 N 165.6 E 1147.0 N 183.4 E 3100.0 61.67 7.05 3200.0 65.55 9.63 3300.0 71.57 8.86 3400.0 73.32 8.34 3500.0 72.03 8.30 3146.0 1326.3 3246.0 1529.3 3346.0 1781.7 3446.0 2120.3 3546.0 2436.0 2.35 1327.6 8.8 .81 1552.2 8.9 2.22 1785.0 9.0 .50 2168.6 8.9 .43 2454.3 8.8 1310.5 N 204.0 E 1511.1 N 235.5 E 1760.0 N 277.9 E 2094.9 N 327.6 E 2407.3 N 372.7 E 3600.0 73.04 6.22 3700.0 72.32 5.79 3800.0 72.04 6.35 3900.0 73.58 7.81 4000.0 72.31 8.26 3646.0 2749.0 3746.0 3068.5 3846.0 3368.4 3946.0 3693.6 4046.0 4034.9 1.02 2835.4 8.6 .50 3121.3 8.4 1.06 3405.5 8.1 .16 3788.6 8.0 .90 4075.9 8.1 2718.0 N 411.5 E 3036.0 N 445.9 E 3334.6 N 476.4 E 3657.4 N 516.8 E 3995.2 N 565.8 E 4100.0 72.05 7.59 4200.0 72.57 7.26 4300.0 72.10 6.61 4312.7 72.48 6.72 4146.0 4345.0 4246.0 4649.9 4346.0 4964.1 4358.7 5003.4 .33 4361.4 8.1 .86 4741.9 8.0 .89 5003.7 8.0 .98 5003.7 8.0 4302.3 N 608.6 E 4604.6 N 649.3 E 4916.4 N 688.8 E 4955.4 N 693.3 E Final Station Closure- Distance: 5003.66 ft Az: 7.96 deg. gyro/data 4. QUALITY CONTROL RECEIVED SEP ~ 0 199~ /~laska Oil & Gas Cons. Commission AnchoTage SR296.DOC Quality Control Comparisons B.P. EXPLORATION WELL: MPF-78 Location: F PAD, MILNE POINT, ALASKA Job Number : AK0995G296 / AK0995G296 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN Depth Inc Inc Delta Az 500.0 1.51 1.64 -.136 340.18 1000.0 7.75 7.72 .023 10.65 1500.0 15o93 15.93 -.002 13.30 2000.0 23.70 23.70 .000 10.84 2500.0 34.14 34.12 .023 8.92 3500.0 58.81 58.70 .105 6.98 7400.0 72.18 71.78 .400 6.69 For Inclinations Greater than 10 degrees: Average Inclination Difference = .10539 deg. Average Azimuth Difference = .30377 deg. OUTRUN Az 349.38 10.67 12.43 10.37 8.72 7.16 6.54 Delta -9.199 -.015 .863 .474 .198 -.171 .154 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK0995G296 ,.- TOOL NUMBER: 080 MAXIMUM GYRO TEMPERATURE: 74.39c MAXIMUM AMBIENT TEMPERATURE: 74.39 c MAXIMUM INCLINATION' 74.64 AVERAGE AZIMUTH: 7.96 WIRELINE REZERO VALUE: no correction REZERO ERROR / K: n/a CALIBRATION USED FOR FIELD SURVEY: 8/21/95 CALIBRATION USED FOR FINAL SURVEY: 8/21/95 PRE JOB MASS BALANCE OFFSET CHECK: .15 POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES .20 USED .18 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOi~! LINE COMPARISONS: M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY FINAL SURVEY 7475 72.48 6.72 4358.6 4955.5N 693.3E 7475 72.48 6.72 4358.7 4955.40N 693.28E SR296.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0995G296 5 Survey statiOns were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 3000 43.94 43.94 43.94 43.94 43.94 AZIMUTH M.D. ft 1 2 3 4 5 3000 8.8 8.79 8.87 8.95 8.77 SR296.DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR296.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0995G296 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0098 DATA SECTION A0032 POWER SECTION A0027 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0074 A0079 A0071 BACKUP TOOL No. 731 GYRO SECTION A0054 DATA SECTION A0025 POWER SECTION A0052 COMPUTER POWER SUPPLY PRINTER INTERFACE A0122 A0074 A0082 A0035 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 15/32 RUNNING GEAR 3.0" System TOTAL LENGTH OF TOOL: 17.5 feet MAXIMUM O.D.: 3.12 INCHES TOTAL WEIGHT OF TOOL: 210 Lbs SR296.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0995G296 9/23/95 0930 1354 1720 2030 LEAVE FOR MILNE POINT. PU TOOL. ZERO TO r.k.b... START INRUN. pull out of the hole. rtn to Atlas SR296.DOC HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHOR.AGE AK, 99501. Date: 10 July 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PLS FINAL BL+RF/ Run ~ 1 1 PFC/PERF FINAL BL+RF°/Run ~ 1 1 PLS FINAL BL+RF ~-' Run # 1 1 PFC/PERF FINAL BL+RF~--'Run # 1 ---.-_____ ECC No. 6302.01 6512.04 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 A_nchorage, AK 99518 Or~7) 563-7803 Date: RECEIVED JUL 1 9 1996 Alaska Oil & ~s Cons. Commission MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: THRU: David Joh~ Chairman ~ Blair Wondzeli, ~ P. !. Supervisor 'r/5~(~ FROM: Chuck Scheve, (; $ SUBJECT: Petroleum Inspector DATE: July 6, 1996 FILE NO: aw9kgfdd.doc BOPE Test - Polar Rig 1 BPX - MPU - F -78 PTD # 95-144 Kuparuk River Field Fr. ida.¥,~ I traveled to BPX's MPU F-78 Well, being worked over by Polar Rig 1,and witnessed the initial BOPE test on this well. As the attached AOGCC BOPE test report shows~the test lasted 2 hours and there were no failures. The methane gas detection system was checked and was working well at the time of this test. The H2S detection system appeared to be operational but could n,..ot be tested due to the lack of proper fittings for the test gas. ~ ~,:. _ ~,~ j:Z~,.~ ~-.y ,~- Summary: I witnessed the initial BOPE test on Polar Rig 1 at Milne Point F Pad ~ Well 78 test time 2 hours 0 failures. Attach .ment; aw9kgfdd .X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: Workover: X DATE: Drlg Contractor: -Polar ~ Rig No. I PTD # 95-144 Rig Ph.# Operator: BPX Rep.: Lee Hinkle Well Name: F-78 Rig Rep.: Cliff Ehret Casing Size: 7" Set @ t5,931 Location: Sec. 6 T. 13N R. IOE Meridian Umiat Test: Initial X Weekly Other 7/6/96 659-2782 Test MISC. INSPECTIONS: Location Gen.: OK Housekeeping: 'oK (Gen) PTD On Location Yes Standing Order Posted Yes Well Sign NO Dri. Rig Hazard Sec. YES FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP N/A , Ball Type ~ Inside BOP '/V/,~ , , Quan. Pressure P/F N/A N/A 250/5,000 N/A P N/A BOP STACK: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Check Valve Quan. Test Press. I 250/3, 000 1 250/5,000 I ,2.50/5,000 250 ,;000 2 250/5,00~, CHOKE MANIFOLD: No. Valves .9 I No. Flanges . ~8 Manual Chokes 2 Hydraulic Chokes 0 N/A P/F P P P P P P N/A Alarm OK OK ,, OK OK Test Pressure P/F 250/5,000 P 250/5,000 Functioned Functioned P ACCUMULATOR SYSTEM: System Pressure 3,000 I Pressure After Closure f,350 I MUD SYSTEM: Visual 200 psi Attained After Closure minutes 20 sec. Tdp Tank OK System Pressure Attained I '. minutes ~5 sec. Pit Level Indicators OK Blind Switch Covers: Master: YES Remote: YES Flow Indicator OK Nitgn. Btl's: N/A Meth Gas Detector OK Psig. H2S Gas Detector OK ' Number'0fFail~i;es:''''' ................. ~ .......... :,~{¥i~i~~'~t~"~:":'":::'i~l~'~':~t;~'lv~ test~' 1;4 'RePair or"Repia~em'ent'of Failed Equipment will be made within ~ia~. Notify the Inspector and follow with'~-~'en or Faxed verification to Ithe AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 if your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 I .I F ' I I I I I [I I I I REMARKS: H2S could not be tested, fittings for test gas not on Ioca#on / Distribution: ofig-Well File c - Oper./Rig c- Database c ~ Tdp Rpt File c - Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: v~,rrtnessed By: Chuck Scheve FI-021L (Rev. 12/94) AWgKGFDD.XLS LARRY GRANT Attn. ALASKa. OiL + GAS CO?[SERVATiO~? 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 17 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Str/Madam~ Enclosed, please find the data as described below: W_~ ~ nECCmTO~ON ~ SBT FINAL BL+RF /1PFC/PERF FINAL BL+RF ~-PLS FINAL BL+RF ~ PFC/PERF FINAL BL+RF ~'1 PLS FINAL BL+RF ~_ GR/CCL FINAL BL+RF ~ PFC/PERF FINAL BL+RF ECC No. Run ~ 1 6500.01 Run # 1 Run # 1 6512.03 Run # 1 Run # 1 Run # 1 Run # 1 6644.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Received by: Suite 201 Anchorage, AK 99518 Or FA~X to (907) 563-7803 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 10 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 PFC/PERF FINAL BL+RF 1 SBT FINAL BL+RF I SBT FINAL BL+RF ECC No. Run # 1 6512.02 Run # 2 6630.01 Run # 1 6639.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 A~chorage,F~l(9?AK 99518 FAX o (9 7) 563-7803 Received by: ~ Date: ?' F:F '1 1996 WELL LOG TRANSMITTAL To: State of Alaska April 09, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Larry Grant 3001 Porcupine Drive Anchorage, Alaska 99501 RE: MWD Formation Evaluation Tapes - MPF-78 AK-MM-950947 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPF-78: 1 LDWG formatted LIS tape with verification listing. APIg: 50-029-22599-00 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To: State of Alaska January 23, 1996 Alaska Oil and Gas Conservation Comm. Attn: Larry Grant 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MP F-78, AK-MM-950947 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2"x 5" MD Resistivity and Gamma Ray Logs: ~ x TVD Resistivity and CJamma Ray Logs: c2i'x 5" MD Neutron and Density Logs: '/2"x 5" TVD Neutron and Density Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company LARRY GRANT ~ Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 21 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL / ~ DESCRIPTION ~A~ ECC No. 6511.00 1 LDWG TAPE+LI~q~ Run ~ 1 6512.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wire!ine Services 5600 B Street ~ Or F~ to (90?) 563-?S03 ~Ov ~0 I99~ LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 12 November 1995 Transmittal of Data Sent by: US MAIL Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION PFC/PERF FINAL BL&RF PFC/PERF FINAL BL&RF PFC/PERF FINAL BL&RF SBT FINAL BL & RF 1 PLS FINAL BL & RF ! PLS FINAL BL & RF ECC No. Run ~ 1 6511.01 Run ~ 1 6512.01 Run ~ 1 6516.00 Run # 1 Run ~ 1 6517.00 Run # 1 6518.00 Please sign and return to: Attn. Rodney D. Paulson -. Atlas Wireline Services Suite 201 Anchorage, AK 99518 Received by: //~'3&-~ / ,F'/f~w~ Date: 5600 B Street LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK:: 99501. Date: 9 November 1995 Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL MPF-78 DESCRIPTION 1 SBT-FINAL BL+RF 1 PLS FINAL BL+RF Run ~ 1 Run # 1 ECC No. 6511.00 6512.00 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ,Or FAX to (907) 563-7803 TONY KNOWLES, GOVERNOR AI_,,,~I~ZI~ OIL AND GAS CONSERVATION COMPreSSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501~3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 September 12, 1995 Tim Schofield, Sr Ddlling Engineer BP Exploration (Alaska) Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPF-78 BP Exploration (Alaska), Inc. Permit No 95-144 Surf Loc 2237'NSL, 2555'WEL, Sec. 06, T13N, R10E, UM Btmhole Loc 4214'NSL, 624'WEL, Sec. 30, T1.4N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to ddll the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before ddlling below the surface casing shoe must be'given so that a representative of the Commission may witness the test. Notice may be m field inspector 659-3607. David ~\ Chairman.._ BY ORDER OF COMMISSION /encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Typeofwork Drill[] RedrillCIIlb. TypeofwelI. Exploratoryl~ Stratigraphic Test[] DevelopmentOill"~ Re-Entry [] DeepenFII Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 45 f e et Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 355018 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 2237' NSL, 2555' WEL, SEC 06, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 4023' NSL, 646' WEL, SEC 30, T14N, RIOE MPF-78 2S100302630-277 At total depth 9. Approximate spud date Amount 4214' NSL, 624' WEL, SEC 30, T14N, RIOE 09/13/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 355017 624 feet No Close Approach feet 5083 15931' MD / 7580' TVD feet 16. To be completed for deviated wells i17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth 500 feet Maximum hole angle z2 o 'Maximum surface 2828 psig At total depth (TVD) 7305'/3536 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT8OLHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btm 8070' 31' 31' 8101' 4506' 1555 sx PF'E', 250 sx 'G', 250 sx PF'E' 8-1/2" 7" 26# L-80 Btm 15901' 30' 30' 15931' 7580' 231 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .... ~ ,,~ Surface R ~..~. CiVED Intermediate Production SEP 0 7 ]995 Liner Perforation depth: measured AlaSka, Oli & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis [] Seabed report[] 20 AAC 25.050 requirements FI 21. I hereby certify that thee for~egoing ~¢~true and correct to the best of my knowledge Signed "~ ._~ ~c~/'~',/~-,~,~l' Title Senior Drillin~lEngineer Date ~'/~/q_~" ' // Commission Use Only Permit...Number ' APl number _ ,..,_ IApproval date _ See cover letter /~.-.//'.~Z./~Z 5 0-c3 2. ~.-- -~-- ~ ~,z ~7' y I ~/- / o~ '" ~',,-%-- for other requirements Conditions of approval Samples required [] Yes [] No Mud Icg required []Yes [] No Hydrogen sulfide measures [] Yes i~ No Directional survey required J~ Yes [] No Required working pressure for BOPE [] 2M; 1-13M; ,[~5M; I-Il OM; i-115M; Other: Original Signed By by order of7//,'~ Approved by David W. Johnston Commissioner me commission Date Form 10-401 Rev. 12-1-85 Submit i~ dicate I Well Name: I MPF-78 I Well Plan Summary I Type of Well (producer or injector): I Kuparuk Producer Surface Location: 2237' FSL 2555' FEL Sec 06 T13N R10E UM., AK. Target Location: 4023' FSL 646 FEL Sec 30 T14N R10E UM., AK. Bottom Hole 4214' FSL 624' FEL Sec 30 T14N R10E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: ]330187 ] I Rig: I Nabors27E I IOperating days to drill and case: Il0 { I MD: ] 15931' I I TVD: 175S0' BKB I IKBE: 146. I Well Design (conventional, slimhole, ] Ultra Slimhole, 7" Longstring I etc.): Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1794' 1794' n/a MA n/a n/a n/a NA (Top Schrader) ' 3974' 1653 psi# / 8.0 ppg OA 6380' 4194' 1744 psi# / 8.0 ppg Base Schrader Bluff 7901' 4444 1848 psi# / 8.0 ppg Top HRZ 15128' 6969' n/a Base HRZ ' 7029' n/a Kupark D Shale 15422' 7189' n/a Kuparuk C ' 7314' 3043 psig/ 9.6 ppg Target KUP A3 15631' 7349' 3057 psi# / 9.6 ppg Total Depth 15932' 7580' n/a Casing/Tubing Program: Hole Csg/ Wt/Ft Grade Con Length Top Btm Size Tbg n MD/TVD MD/TVD O.D. 30" 20" 91.1# NT80LHE weld 80 32/32 112/112 12 1/4" 9 5/8" 40# L-80 btrc 8070' 31/31 8101/4506 8 1/2" 7" 26# L-80 btrc 15901' 30/30 15931/7580 N/A (tbg) 2-7/8" 6.5# L-80 EUE 15312' 29/29 15341/7127 8rd Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7305' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3536 psi is 2828 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: I Open Hole Logs: Surface Intermediate Final ICased Hole Logs: LWD GR/Resistivity None LWD GR/Resistivity/Neutron/Density None amission A gamma ray log will be obtained from surface to TD with LWD tools. Mud Logging is not required. API# 50- September 5, 1995 Mud Program: Special design considerations LSND freshwater mud. Special attention to gravel and coal in the surface hole, with appropriate viscosity and weight to control each. The use of frequent short trips as per pad data sheet are encouraged. Surface Mud Properties: Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 8.6 80 15 8 10 9 8 to to to to to to to 9.6 100 35 15 30 10 15 Production Mud Properties: Density Marsh. Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss 9.0 40 15 3 7 8.5 6-10 to to to to to to to 10.2 50 20 10 20 9.5 4 - 6 , Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: IKOP: 15°°' Maximum Hole Angle: [ 72 degrees Maximum Dog Leg: I _< 4 degrees Inclination in target: 40 De~ees Close Approach Well: None - See Traveling Cylinder report There are no close approach wells for drilling MPF-78 API# 50- September 5, 1995 Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. pit can be opened in emergencies by notifying Karen Thomas (564-4305) The Milne Point reserve with request. Fluid Handling: All drilling and completion fluids can be annular injected after allowing the cement on the 7" casing cement job to cure 6 hours following CIP. Request 1. 2. to AOGCC for Annular Pumping Approval for MPF-78: Approval is requested for Annular Pumping into the MPF-78, 9-5/8" x 7" casing annulus. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGOC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 5795' md (4446' tvd) which is below the Schrader Bluff Sands and into the Seabee formation which has a long established history of annular pumping at Milne Point. 4. The burst rating (80%) for the 9-5/8" 40# L80 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2302 psi for a 10.4 ppg fluid in this well. MASP = 4325 psig - ((fluid density ppg - 1.9) X 0.052 X 9-5/8" Casing Shoe TVD 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7-24-95 which demonstrates the confining layers, porosity, and permiability of the injection zone. 6. Pumping into the hydrocarbon reservior will not occur. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) ,, VOL (BBL) Milne Point F-1 0 35,000 1/1/95 - 12/31/95 Milne Point F-13 684 35,000 1/1/95 - 12/31/95 Milne Point F-25 230 35,000 1/1/95 - 12/31/95 Milne Point F-37 0 35,000 1/1/95 - 12/31/95 Miine Point F-45 0 35,000 1/1/95 - 12/31/95 Milne Point F-53 0 35,000 1/1/95 12/31/95 Milne Point F-61 0 35,000 1/1/95 - 12/31/95 FREEZE PROTECTION: Pay close attention to annulii being used for disposal so to avoid freezing. Sometimes the annulii are kept open by ensuring that an adequate volume (+60 bbls) is injected every 6-12 hours. This practice is more economical than pumping 60 bbls of diesel freeze protection every time the pumps are shut down; however, if this practice is used, it is important that the injection frequency into the annulus be adequate to prevent freeze ups -- the drillers must communicate to each other the last time the annunlus was injected into to avoid freezing. Anchorage: API# 50- September 5, 1995 DRILLING HAZARDS AND RISKS: See both the Milne Point F-Pad Data Sheet and L-Pad Data Sheet prepared by Pete Van Dusen for information on the No Point#1 (F-46), and review recent wells drilled on both F and L pads. Most of the trouble time on recent wells has been due to equipment mechanical problems with the BHA, rather than formation drilling problems. The MPU PE group will be perforating, hydraulic fracturing and cleaning out wells shortly after the rig drills and completes them. This will make the near rig area congested and as a result potentially hazardous. Ensure personnel use caution moving around adjacent production activities. Lost Circulation: No Point #1 (MPF-46) did not experience any lost circulation while drilling on F- pad. The max mud weight reached on that well was 10.3 ppg. They did experience some mud losses while cementing 7" casing. Lost circulation while drilling the production interval has been a problem on 4 different L-pad wells, the closest pad to F-pad, although none of them have BHLs in the F-pad drilling area. The Kuparuk sands and a number of shallower intervals typically are highly fractured. Wells L-07, L-08, L-09 and L-11 lost varying amounts of mud (from 70 to 220 bbls) drilling through or near the top of the Kuparuk sands. Be prepared to treat these losses initially with LCM treatments. There has not been any appreciable amount of lost circulation on any of the F Pad wellls to date. This is due to setting surface pipe deeper to cover the Schrader Bluff interval which might break down at the mud weights required to TD the well. Stuck Pipe Potential: Well MPF-53 was stuck coming out on the short trip at surface casing point. Proir to this incident there was only minor indications that the gravel and coal were present. It appears that we dragged the gravel up into the bottom of the curve and reduced our ability to move up or down. Then we lost the ability to circulate when the hole collapsed. Subsequent fishing operations were not successful and a very expensive BHA was lost in the hole from 2516 - 3342. While drilling No Point #1 the 6" BHA was stuck in 8-1/2" hole section for several hours at 6882 ss (13608' MD) before jarring free. They became stuck after tripping back to bottom following a bit trip. Lack of proper hole cleaning parameters appears to have contributed to this problem. Stuck pipe has occurred on 3 L-pad wells at the interface between the Kalubik and D-shale (called the Kuparuk cap rock). These wells and the corresponding depths at which they were stuck were: L-06 @ 6871' ss, L-07 @ 6859' ss, L-11 @ 6835' ss. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 97.5 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3536 psig (9.6 ppg equivalent MW). Trip Schedules are required for all trips. All trips will be performed with a trip tank or one pit isolated for use as a trip tank. Formation Pressure: The maximum expected pore pressure for this well is 9.6 ppg EMW (3057 psi @ 7305' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. WATER USAGE Have the water truck drivers track the water usage on a daily log. Send a copy of this log to Dennise Casey in the Anchorage Office on a monthly-basis. 0 .~. Ala~!,¢,-Olt Gas Co~-~s, : ~nch0rage API# 50- September 5, 1995 MP F-78 Proposed Summary of Operations . Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. Prepare location for rig move. 3. MIRU Nabors 27E drilling rig. . NU and function test 20" Diverter system. Ensure the diverter is as per AOGCC specifications and is approved by AOGCC supervisor. Build Spud Mud. . Drill a 12-1/4" surface hole to 8101' md (4506' tvd). (Note: This hole section will be LWD logged with GR/Res). Run and cement 9-5/8" casing. 8. ND 20" Diverter, NU and Test 13-5/8" BOPE. Run Wear Bushing. . RIH w/PDC bit and Double Power Section PDM (motor). Te, st the 9-5/8" casing to 3000 psig and plot pressure vs volume for LOT baseline. Drill out float equipment and 10 feet of new formation, Perform a LOT to a maximum of 12.5 ppg as per Recommended Practices Manual. Record pressure vs. cumulatrive volume for LOT test for well file. 10. Drill 8-1/2" hole to TD at 15932' MD (7580' TVD). (Note: This hole section will be logged LWD with Triple Combo (GR/Res/Neu/Dens). 11. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. 12. ND BOPE and NU dry hole tree. Release rig to MPF-70. Note: This well will be perforated, hydraulically fractured and cleaned out with a completion rig and prior to running the ESP completion. Following the stimulation the well will be left with a retrievable bridge plug (RBP) set 500' above the perforations and kill weight brine in the wellbore. 13. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. 14. PU and RIH with 2-7/8" EUE 8rd tubing with RBP retrieving tool. Release RBP and POH standing back tubing. 15. RIH with Electric Submersible Pump 0ESP) completion on 2-7/8" EUE 8rd tubing. 16. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. 17. RDMO with workover/completion rig. POST RIG WORK g~,tB=¢a Oil .& Gas Cons. Cornrnis¢o.n '-,: ~nchorafle. . Complete the handover form and turn it and the well files over to production. Turn over the well files along with the handover form. , A SBT/GR/CCL is not required on this well and will only be run if there are problems on the production cement job. o An adequate volume to cover 2000' of diesel needs to be injected down the 7" X 9-5/8" annulus before moving the rig off the well. Please note type and volume of freeze protection pumped down the outer annulus on the morning report. , The rig will not complete this well. PEs will perforate, frac and clean out this well with a completion rig. API# 50- September 5, 1995 MPF-78 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM- HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 75 bbls fresh water. LEAD CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 1555 THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS' 100-150 cc YIELD: 1.15 ft3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 TOP JOB CEMENT TYPE: Type E Permafrost ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 cu ft/sk. MIX WATER: 11.63 gal/sk APPROX NO SACKS' 250 CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Do not overdisplace by more than 1/2 the shoe joint. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is a standard 250 sacks is calculated to cover the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 4. 80'md 9-5/8", 40# capacity for float joints. 5. Top Job Cement Volume is 250 sacks. ~las¢ 0it & ~as Cons. ¢0mm,~,0n ..... gnch0raga API# 50- September 5, 1995 MPF-78 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON THIS WILL BE A SINGLE STAGE CEMENT JOB ACROSS THE KUPARUK INTERVAL ONLY: CIRC. TEMP: 140° F BHST 170 deg F at 7260' TVDSS. SPACER: 20 bbls fresh water. 70 bbls Alpha Spacer mixed as per Halliburton specifications weighted to 1.0 ppg above current mud weight. CEMENT TYPE: Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 231 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7-1/8"" x 8-1/4" Straight Blade Turbulators -- two per joint on the bottom 17 joints of 7" Casing (34 total). Use stop collars to fasten centralizers to casing joints. This will cover 300' above the top of the Kuparuk sands. 2. Run one 7-1/8" x 8-1/4" Straight Blade Turbulator a minimum of 60 feet inside the 9- 5/8"casing shoe to avoid hanging up on the shoe. This centralizer may be attached across a casing collar connection. 3. Total 7-1/8"" x 8-1/4" Straight Blade Turbulators needed is 35. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm until the plug bumps, but not more than to displace cement just above the production zone. Batch mixing is not necessary. CEMENT VOLUME: 1. The cement volume is calculated to cover 1000' md above the top of the Kuparuk Sands with 30% excess over a guage hole. API# 50- September 5, 1995 BPX-Shared Alaska State Plane: Milne Pt ' MPF MPF-78 As-Built MPF-78 Wp 1 TrBRTICAL VIEW ~CALE 500 ft. /~DIV1SiON TVD ~: ~L~ Services Drilling Zone4 TIE 1N 8 O.OD' 9,OD' e 0 N ~P/S'I'PJt. T 5og 0,00' 9,00' ~00 0 ~ 0 £ I,OD'/IOO ¢~ :~TP. RT BF ~UTL9 ~QQ 3.g0) 9,09* 900 9 ~ L ~ 1,50'/t00 ~ ~,O~'/LO0 IZS6 &7 N 11 £ d H~LL IBURTFIN SECT[ON REF: WEM~IEAD 0,00' 31 II H:D TiC IN D.DO' e DDO FL]) Kf]P / START Oi~ )U[LD E I.DD*/TOD F~c 3,90' ~ ODD I~I) ~T~RTCF GUILD · 1,50'/I00 F~ 7.50' ~ 1LDO HD SYA~T Dr I~ITLD O ~,gO'/LO0 Pt LL.50' ~ 1300 HD END DF ~[L~ ti.SO' E 1590 HD ~T~T flF C~VW- · ~.50'/10D F~ END DF DJZL} 1300 11,50" E,~g'/LO0 r~ g. Pen,,~Fro;t: tBTU 19.3G" ~ DF C~V~ 39Zn 7~, 00' B,67' ~. S~q~ 03~0 72,00' 8,67' B, Sc2w~de~ 790l 7~-,00' ~T~T IF L~763 7~.d0' 0.67' CURVC · ~.03'/I 0P Ft 1FLRZ 1~9 44.~t' END ~ ~ L~4~ 4R.OO' 7.g0' TXUD [~4~ 4D.O0' 7.00' ,, 1795 18~ N 30 E 3~14 16ZI N R~O E 397~ 3940 N 603 E 7t29 l~160 N 1841 C 719U 1~1~ N L847 ~4,00' e ~000N]) 39,00" ~ ~&09 ND 44.80' ~2JBdD ~D 49.00' R 30Off HO ~q,OO' ~ 3Z00 HD 3500 FL1] 7~.0~' e 39E0 ND END OF CURVE 3985 I Az I TV~] N/,T 8.67' 45~ 5558~ N tee7 El 7.00' 7~0 1646 Tm, net -~--_.~-.O0' ~ 790& N~ B. PROPO$~I) BF~ TV]) 7679. )ED 15931,55 V~ 1~677.65 ~. 12~30.4G LOBG,B6 i ,o~ e -'~ ' 9.o~. 0" t I I ._ -SDD 0 D 11007 ~LaP-D~(~3St 1~485 IDOD t~00 El)OD ESO0 3000 3530 4000 45'00 t~678 ~DDD 5500 GO00 I 5500 I 7D30 I 7500 I [ 8500 ~- 7~.00" R 13763 HD S1ARrB~'~t 2.03'/100 F~ r 7 In DS, E 1393~ i"iD, 7590 TVD .. 9003 "~f],O I tioga 11500 tESO0 13601 t DOO 20110 3fiDO O0 ]]ate Pto%~ed i.~9§ Cr e{x"ce d, ]~y Checke~[ By Approved ]ty ," VERTICAL SECT[ON PLANE: 8.56 Surwy Referc~,WEI2.,HF_.AD Ref~e,a~ World Coordi~lcs: Lat. '/0.30.30 N - Long. 149.39,~ lle, ge, m~ GRID ,.gyslem: Al~ka $1a~ Pl~e Zone: Alaa~ 4 ~ (]RID Coordinates: (R); 6035690.59 N 542005.21 Nor~ Aligned To: TRUE NORTH Vmilcal Sec~on Referent; WELLHEAD Closure R~o-cncc: WELLHF. A~ TVD Re/'etem:e: WELLIIF. AD BPX-Sbamd Servic~ Drilling Alaska State Phue: Zciw4 Miln_~ P1: MPF MPF-"/8 As-BuRr MPF.78 Wp! Halliburton Energy Services - Drilling Syslems PSL Proposal Report Calc#~ed u~i~g lhe Minimum C~ntatore Method Compu~ed u~ing WflV. CADDS REVZ 1. B Vertical Section Plane: 8.56 deg. GRID C_x~'i~atea (~) Cio~me. Vexfical Build Walk DLS Cum. EXlnc/ed ToUl Max ttor Min Hot Di~. Ve~ Dist. Dir. Se~io~ Rate Ra~. Dogleg R~~~ Errm' Fax~ Max Fax Er~r (n) (d~g.) (a) (~:,/tOOrO (dg/lOOa) (dr/lO00) (deg) (0) in) (n) (rt) (d~.) (n) 0.00 B 6035690,59 542005.21 0.00 It 60315690.59 542005.21 0.14 E 6035691.46 542005.34 0.55 B 6035694.04 542005.'74 3.49~ 9.00 3.49 1.23E 6035698.36 542006.39 7.8,5@ 9.00 7.85 2.2515 6035704.82 542007.38 14.390 9.00 14.39 3.68 E 6035713.86 542008.76 23.540 9.00 2,3,.54 5.52 E 6035/25.48 542010,53 35.30@ 9.00 35.29 '/.83 B 6035/40.09 542012.'/6 50.0~@ 9.00 50.07 0.000 0.00 0.00 0.000 0,00 0.00 0.87O 9.00 0.82 Sm'vey Tool 1000.00 6.00 9.00 954.52 999.22 100.00 23.25 N START OF BUILD @ ZOO deg/100 II. 1 LOO, OO 7.50 9.00 1053.83 1098.53 100.00 34.86N 1200.00 9.50 9.00 1152.72 1 I97.42 100.00 49.46N END Ola BUILD 1300.00 11.50 9,00 1251.04 1295.74 100.00 67.46N 10,68 E 6035755.10 542015.51 68.34~@ 9.00 68.30 1500.00 11.50 9,00 1447.03 I491.73 200.00 106.84N 16,92E 6035797.52 542021.52 108.17~ 9.00 [0&l? START OF CURVE @ 2_50 deg/lCX) fl 1500.00 11.50 9.00 1447.03 1491.73 0.00 106.SAN 16.92 E 6035797,52 5420c21,52 108.17@ 9.00 108.17 [~00.00 14.00 8.93 /544.56 1589.2fi 100.00 128.64N 20.36E 6035819.33 542024.84 130.~10 8,99 130.24 I?G0,OO 16.50 8.89 1641.03 1685.73 100.OO 154.62N 24.43H 6035845.34 542028.')7 156.540 8.98 156.54 1800.00 19.00 8,g5 1736,26 1780.96 100.OO 184.74N 29.13 E 6035875.48 5~2033.30 187,03~ 8.9~5 I87,02 B, Pemlaf/osl 1814.55 19.36 8.85 1750.OO 1794.70 14.54 189.46N 29.87E 6035880.21 542034.00 191.8~@ 8.96 191.80 1900,00 21,50 8.83 1830.07 1874.77 85.46 218.94N 34.45 E 6035909.70 54203&42 221.63@ 8.94 221.63 2000,00 24.00 8.81 19Z2.29 19~6.99 100.00 257.15N 40.38 B 603594'7.94 542044.13 260,30@ 8.92 260.30 0.00 0.00 0.00 0.0 O. OON 0.OO 0.00 0.OO 0.0 0.00N 1.00 0.OO 1,00 1.0 0.86N 1.00 0.00 ID0 2.0 3.45N 1.OO 0.00 1.00 3,0 7.75N 1.51) 0.00 1.50 4.5 14.21N 1.50 0_OO 1.50 6.0 23.25N LS0 0.00 1~50 7.5 34,$6N 2_00 0,00 2.00 9.5 49.45N 0.00 E 0.00 0.00 0.00 0.00 I}FltM-PBD O. iX) E 2.33 . . 2.33 0.00 O. fi~lBPI-Ibl-PBD 0.14 B 2.47 2.47 279.00 O. 83 BPHbl-PBD 0.~ E 2,64 2.63 279.00 0.98 BPHM-PBD 1.23~ 2.84 2,81 279.00 1.14 BPtfbI.PBD 2.26 E 3.07 3,00 279.00 1,29 BPHM-PBD 3.9q~ E 3__'36 3.2l 279.OO 1.46 BPHM-PBD ~.56]~ 3.71 3.42 279.00 1.62 BPI~'I-PBD 7~)E 4.16 3.154 279.00 1.80 BPHM-FBD 0,00 0.00 2.50 -0,07 2.5O -O.05 2.50 -0.03 ZOO ! 1.5 6'7.44N 10.TS E 4.72 3,88 279.OO 1,99 BPHM-PBD 0.00 II.5 106.81N 17.10E 5.96 4,41 279.00 2.31 BPHM.PBD 0.00 11.5 106.81N 17.1015 5.96 4.41 279.OO 2.31 BPItM-PBD 2.50 14,0 128.60N 20.59E 6.73 4.67 2T8.99 2.53 BFHM-PBD 2.50 16.5 154.57N 24.74 E 7.64 4.94 T/8.97 2.77 BPHM-PBD 2,50 19.0 184.68N 29..54 E 8,70 5.22 278.95 3.03 BPHM-PBD 2.50 -0,03 2.50 -0.(B 2.50 -0.02 2.50 19.4 189.4ON 30.29B 8.86 5.26 278.95 3.07 BPHM-PBD 2.50 21.5 218.86N 34..98E 9.89 5.52 278.93 3.32, BPHM-PBD 2.50 24.0 257.04N 41.06E 11.24 5.83 278.91 3.63 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report GRID Coordiaa~ Cioame Vertical Build Walk DLS CU~ Expeacd'fotal Max Hot Mia Hot Dlr. Vcrt Not~alng Eaa~ing DLst. Dix. ,~ction Rat~ Rate Do~lcg Rec. lang~ar Coo~ls F_~m ~ Max ~ F. axor (a) (n) (~) (a~.) (n) (~dtooa) (~r, ttoon) (~'1o~) (d~) (a) (n) (a) (r) (~.) (n) 2100.00 26.50 8,79 2012.73 2057.4~ 100.00 299,90N 46.90E ~359~.13 542050.41 302,960 8.91 909__95 2200.00 29.00 8.77 2101.22 2145.92 100.00 345.31N 54,01E 6036036.17 542057.26 349,51~ 8.89 349.51 2300.00 31,50 8.76 2197.59 2232.2~ [00.00 395.10N 61.69 E 6036086.00 542064.66 399,89~ 8.87 39938 Page Date~ 915/95 Wclllma, h ID; IViPF-78 Wpl 2400.00 34,00 8.75 2271.69 2316,39 100,00 448.56N 69.938 6036139.50 5420'/2.59 453.980 8,86 453,9/ 2500.00 36,50 8.74 2353.35 2398.05 100.00 505.60N 78.70E 6036196.58 542081.04 511.690 8,85 511,68 2600.00 39.00 8.73 2432.41 2477.11 100.00 566.11N 88.00E 6036257.13 542099.00 572.90@ 8.84 572.90 ~r'/00.00 41.50 8.73 2508.73 2553.43 100.00 629.96N 97.81 E 6036~21.04 542099.44 637,51~ 8,83 637.50 2800,00 44.00 8.72 2582.16 2626.86 I00.00 697.05N 10g.10 E 6036388.18 542109.35 705,3963 8,82 705.38 2900.00 46.50 8.71 2652.55 269/.25 100.00 767.25N 118.86E 6036458.43 542119.71 T/6,4L~ 8.81 776.39 30O0.00 49,00 8.71 2719.78 2764.48 IO0.00 840.41N 130.07[{ 6036531.64 542130,51 850.41@ 8.80 850.41 3100.00 51.50 8.70 2983.72 2828.42 1O0.00 916.40N 141.71 E 6036607.69 542141//1 9c2'/.29~ 8,79 927,28 3200.00 54.00 8.70 2844.25 2888.95 100.00 995.08N 153.74E 6036686.43 542153.30 1006.89@ 8.78 1006~88 3300.00 56.50 8.69 2901.24 2945.94 100.00 1076.29N 166.16 E 6036767.70 542165.26 1089,04~ 8.78 1089.04 3400,00 59.O0 8.69 2954.60 2999.30 100.00 1159.89N 171k94E 6036851.36 542177.56 1173.61@ 8.77 1173.60 3500.00 61.50 8.68 30ff4.22 3048.92 100.00 1245.70N 19LO5E 6036937.24 542190.18 1260.42~ 8,76 1260,41 3600.00 64.00 8.68 3050.00 3094.70 100.00 1333,58N 205.47E 6037025.19 542203.10 1349.32@ 8.76 1349.31 3700.00 66~50 8.68 3091.87 3136_~7 100.00 1423.35N 219.17 E 6037115.02 542216~29 1440.12@ 8.75 1440,12 '7' 0 3800.00 ~.00 8.67 3129,73 3174.43 100.00 1514.84N 2.33.13 E 6037206.58 542229.72 1532.67~ 8.75 1532.66 =3 3900,00 71.50 8.67 3163.52 3208.22 100,00 1607.87N 247.31E 6037299.68 542243.38 1626.78~ 8.74 1626.77 ~ END OP CURVE, _l 3920.01 72.00 8,67 3169.78 3214,48 20.01 1626.66N 250.181~ 6037318.48 542246.13 1645.78~ 8,74 1645,77 CE NA Sands 6380.12 72.00 8~67 39'30.00 39'/4.70 2460.11 3939.64 N 60Z79 E 6039633.21 542585.50 3985.49@ 8.'/0 35)85.47 2,50 -O.02 2.50 -0.01 2.50 4).01 2.50 -O.01 2-50 -0.01 2.50 -0.01 2.50 -0.0l 2.5O 4).01 2.50 4).01 2.50 -0.01 2.50 -0.01 2.50 -0.00 2.50 4).00 2.50 -O.00 2.50 --0.00 2.50 4).O0 2.50 -0.00 ZS0 -0.00 2.5O -0.00 2,50 26.5 299.17N 4'/.76E 12.'/4 6~15 278.89 3.97 BPI-IM-I~D 2.50 29.0 345.15N 55.09E 14.38 6,50 2"/g,~8 4.'34 BPHM-PBD 2.50 31.5 394.89N 63.02E 16.16 6.85 2'/8.86 4.74 BPHIVI-PBD 2.50 34.0 448,31N 71.54 E 18.08 7,22 278.85 5.17 BPHM-PBD 2.50 :36,5 505.30N 80,64 E 20.14 7.59 278.84 5,64 BPHM-I:'BD 2.50 39.0 565.75H 90.31B 22.32 7.98 278.83 6.14 BI:'I-~-PBD 2,50 41.5 629.55N 100.51 E 24.63 8.37 278.82 6.68 BPHM-PBD 2,50 44.0 696.57N 111.25E 27.07 8.77 278.81 7.26 BPHM-PBD 2.50 46.5 766.69N 12Z49 E 29.61 9.16 278.80 ?.88 BPHM-PBD 2.50 49.0 839.77N 134.22E 32.27 9.55 2'/8.99 8.54 BPHM-PBD 2.50 51.5 915.68N 146,41E 35.03 9,94 2'78.78 9.23 BPRM-PBD 2.50 54.0 994.26N 159.05 E 37.89 10.31 278.78 9.96 BPHM-PBD 2.50 56.5 1075.38N 172.11E 40.1L~ 10.67 278."/7 10.73 BPHM-PBD 2.50 59,0 1158.87N 1853511 43.90 IL02 278,76 11,53 BPHM-PBD 2.50 61.5 1244-58N 19937 E 47.O3 11.35 278.76 12,37 BPHM-PBD ZS0 64.0 133Z34N 213.52E 50.23 11.66 278,75 13.24 BPHM-PBD 9.50 66.5 I422.00~ 227,99 E 53.51 11.94 2'/8.75 14.14 BPHM-PBD 2.50 69.0 1513.36N 242.74E 56.85 12.~0 278.74 15.06 BPHM-PBD 2.50 71.5 1606.2'/N 257.74 E 60,24 12.44 278.74 16,01 BPHM-PBD 2,50 72,0 1625.03N 260.771t 60.93 12.48 278.74 16.20 BPHM-PBD 0.00 0.00 0.00 72.0 3934.93N 633.64 E 145.13 20.88 278.70 39.22 BPHM-PBD 7901.08 72.00 8.67 4400.00 4444.70 1520.95 5369.63N 820,79 E 6041064.29 542795,25 5432.000 8.69 5431.98 0,O0 0.00 ~, CAS'lNG POINT OD = 9 5/8 in, ID -- 8.84 ia, Weigkt = 40.00 ih/fi. o3 810i.00 72`00 8,67 4461-78 450~48 199.92 5557.59N 849.45E 6041252.41 542822,82 562Z14@ 8.69 5622,12 0.00 0.00 __l START OF CIJRVE @ 2.03 deg/100 Il CE 13762.65 72.00 8.67 6211.33 6236.03 5661.65 10880.64N 1660.94E 6046579.57 543603.22 11006.69@ {{.68 11006.66 0.00 0.00 ,,O 13862.65 69.97 8.59 6243.90 6288,60 100.00 109'/4.11N 1675.13E 60-t6673.1! 543616.85 II101.23@ 8.68 11101.20 -2.03 -0.08 ~.. 13962.65 67.95 8.5[ 6279.81 6324.51 100.00 11066.40N 1689.011] 60~6765.47 543630.19 11194.55@ 8.68 11194~3 -2.03 -0.08 c9 14062.65 65.92 8.43 6318.99 6363.69 100,00 1115'/.40N 1702-57E 60~6556.54 543643.21 11286.55~ 8.68 11286.53 -2.03 -0.08 14162.65 6339 8.35 6361.40 6406.10 100.00 11246.98N 1715.78E 6046946.19 543655.90 11377.11~ 8.67 11377,08 -2`03 4).0~ 14262,65 6136 8,26 6406.98 6451,68 100.00 11335.05N 1728.64E 60470'34.32 54366~.24 11466.10@ 8,67 11466.08 -2.03 -0.09 14362.65 59.84 8.18 6455,69 6500.39 100.00 11421.48N I741,I3E 6047120.82 54368(1.21 11553.43@ 8.67 11553.41 -2.03 -0.09 14462.65 57,81 8.08 650r/.4~ 6;552.15 100,00 11506.18N 1753.23 E 6047205.57 543691.81 11638.980 8.66 11638.96 -2.03 -0,09 14562,65 55.78 7.98 6562.21 6606.91 100.00 11589.02N 1764.92E 6047288,48 543703,02 11722.65~ 8.66 11722.63 -2.03 -0.10 14662.65 53.76 7.88 6619.89 6664.59 100.00 11669.92N 177~1.20E 6047369.43 543713.82 11804.32@ 8.65 11804.30 -2.03 -0.10 14762.65 51,73 7.78 6680.43 6725,13 100.00 11748,77N I787.04E 6047448.34 543724.19 11883.90@ 8,65 118K3.88 -2.03 4).11 1486Z65 49.70 7.66 6743.74 6788,44 100.00 11825.47N 1797.43E 6047525.09 543734.14 11961.29@ 8.64 11961.28 -2-03 -0. il 0.00 72,0 5363.01N 864.16E 19/229 26.13 278.(~9 53.94 BPHM-PBD 0.00 72.0 5557.59N 849,45E 0.00 0.00 0.00 0.O0 BPHM-FBD 0.O0 72`0 108,66.67N 1752.56B 398.44 46.48 278.68 111,14 BPI-RvI-PBD 2.03 74.0 10960.O2N 1767.55E 401.82 47.16 2'/8,68 111.9/ BPHIVI-PBD 2.03 76.1 11052,19N 1782.19E 405.16 47.89 278,68 112.77 BPHM-PBD 2.03 78.1 11143.08N 1796.49E 408.44 48.66 278.67 I13.52 BPHM-PBD 2.03 80,1 11232.56N 1810,4IE 411.67 49,49 278.67 114.24 IBPI-UVI-PBD 2.03 82-1 11320.53N 1823.95E 414.83 50.35 278.67 114.92 BPHM-PBD 2.03 84.2 11406.87N 1837.0811 417.93 51.25 278.66 115.56 BPIOd-PBD ZOO 86.2 11491.47N 1849.78E 420.96 52,18 278.66 116.15 BPHM-PBD 2.03 88.2 11574.24N 1862.05E 423.91 53.13 278,65 116.70 BPHM-PBD 2.03 90.3 11655.07N 1873,87E 426.79 54.1t 278.65 117.22 BPHM-PBD 2.03 92.3 11733.84N 1885.21E 429.58 55,11 278.64 I17.68 BPHM-PBI) 2.03 94.3 11810.48N 1896.08E 432.29 56.12 278.63 118.11 BPHM-PBD Halliburton Energy Services- Drilling Systems PSL Proposal Report W~tlpam ii): 1vO~-78 Wp~ 7- Measured Mci DflR Subsea TVD Coursa T O'T A L GRID Comdimles IMgth Dh'. Depm Leagl~ Reemagular Offsets Noflhing Ea~tiag (tO (~,g.)(~eg.) (n) (~ (n) (n) (n) (a) (n) 14962,65 47.68 7,54 6809.75 6854.45 100.OO 11899.92N 180c/,37E 6047599.59 543743.63 12036.390 8,64 l~0563S -2,03 -0.12 15062,65 45.65 7,41 6878.38 6,jr~.o~ t00-00 11972.00N 1816.84E 6047671.'/5 543752,6'/ 12109.1C'~ 8,63 12109.09 -2,03 -O. la f5128.57 44,31 7.32 6925.00 6969.70 65..92 12018.24N I82Z.81E 604771'/.99 543738.38 12155.69@ 8.62 I2155.68 -2.03 -0.14 15162.65 43.62 '/.27 6949.53 6994,23 34,08 12041.71N 1825.82E 604T/41,4'/ 543761.24 /2179.34@ 8,62 12179,34 -2.03 -0.14 15262.65 41.60 7,13 7023.12 7067.82 1OO,00 12108,8'/N 1834,30E 6047808,68 543'/69.33 12247,02@ 8.61 12247,02 -2.03 -0.15 END OF CURVE 15341.55 40.00 7.00 7082.85 7127.55 78.90 12160.04N 1840.64 B 604~859.87 543775,37 12298,554~ 8.6I 12298.55 -2,03 =0.16 TKUD 15422,6~ 40,00 7.00 7145.00 7189.70 81.13 12211,80N 1847-00E 6047911.67 543781.42 12350.69~ 8.60 12350,68 0.00 0.00 Targei (80.9/95) / TKUA3 1563135 40.00 7,00 7305.00 7349.70 ;~08.87 12345.05N ISdO.36E 6048045.00 543797.(10 12484.89~ 8.58 12484.89 0.00 0.00 CASING POINT OD = 7 ia, ID = 6,28 in, Weight = 26.00 lb/ft. 15931.55 40,00 7,00 7534.81 7579.51 300.00 I2536.45N 1886.86E 6048236,52 543819.37 12677.65~ 8.56 12677.65 0-00 0.00 CIo~me Vtalleal Build Walk DI.~ Cum. ~'lolal Max Hm' MiuHor Dh-, V~al Dist. Dlr. $oaiou Rate Rate Dog~e~ Reclaugular Comds Earn P.n'or Max Far F. axur (r,) (~eg.) (n.) (t~,tl00n) (aga0oa) (d~0ort) (deg) (n) (n) (n) (a) (aeg.) (rt) S m,,'ey Tool 2.03 96.3 11884.87N 1906.45E 434.92 57,13 278.63 118,50 BPH]VI-FI]D 2.03 98.4 Ii956D3N 1916.32E 437.45 58. I5 278.62 118.84 BPHM-PBD 2.03 ~9.7 121XIO, IIN 1922,54E 439.08 58,83 278.62 119.05 BPHM-PBD 2.03 100,4 12026.56N 1925.67 E 439,92 59.17 278.61 119.15 BPHM-PBD 2.03 102.4 12093.69N [934.49E 442.26 60.19 2/8.61 119.42 BPHM-PBD 2.03 104_0 E2144.82N 1941.0'/E 444.05 60..08 2/8.60 119,60 BPHM-PBD 0-00 104.0 12196.55N 1947,67 E 445.89 6i.43 278.59 119,98 BPHM-PBD 0.00 104.0 12329.T3N 1964.67 E 450.63 02,57 278.58 12036 BPHM-PBD 0,{10 104.0 12521.01N 1989.09 E 45'7.43 64.21 278.55 122.36 BPHM-PBD SF_P 0 7 i995 Oil A Bas Cons. Commission ..... --,~ finchorage.? · . ,EP 05 ~9~" 10:0?AM ALASKA HALLIBURTON X-Shared Services" "tilling laska State Plane: Zoneg .vfilne Pt : MPF 1VfPF- 78 As-Built ~IPF-?8 ~Fp 1 HALLIBUETO~ -- }[O~O~,~T.. ~ ('r~tm ~o~) 1500 1000 ~OQ 0 $00 ~OaO l~OO EO00 3OOO ::~00 ~OOO Date PLot~ , 9/..~,/95 Checked By ~j,e' Approved 3y ~ Tr,~veUm9 ~yUncter' - Nor,~'~t .l~ne Re.Fer, ence ii/eli - MPF-?8 Ali ~,ec'-blons uslnt~ ]~ 14~h~e Me-I;hod ~0 84O lO00 140 170 150 SEP 0 7 i995 Aiasl~a .0il .& 6as 0ohs, 6ornBissb. f~ , ~chorago 'rvi) N~ 15~3i.55 i&~_77.65 10:08RM RLRSKR Halliburton Travelling Cylinder Report Computed using WIN-CADD$ REV2.1.B Page 1 Date: 9/5t95 ~me: 8:53 am Normal Plane Method REFERENCE WELL: BPX-Shared Services Dr/lling Alaska State Plane: Zone4 Milae Pt: MPF MPF-78 As-Built M/'F-78 Wpl N/S and EfW are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 R.(MD) From 0.00 To 15931,$$ fL(MD) All Directions using BP High.side Method in Dec.De~ i All Depths and Distance are in FEET All distance~ are b~ween EXPECTED Positions Close Approach Status Offset l*lowing Zone Flowing Shut-in Enter Enter Well Safety Min. Safety Safety Shut-in Danger Clear Spread MD TVD D/st Dlst Zone Zone MPF-37 Spe 303.9 310.8 550 $50 8.3 1.4 MYF-77 Wp$ 101.0 104.~ 300 300 4_~ 0.8 MPF-69 MWD 98.1 108.1 800 800 12.0 IA} MPF-~I G-I 137.1 145~ 700 700 10.5 1.8 MPF-53ST M 57.0 94.4 3650 3116 46-5 9.1 No Point N 232.8 236.~ 300 300 4.5 0.8 MPF-45 Mwd 250.3 256.S 500 500 73 13 MPF-25 Rig 392.5 398.7 500 500 7-~ 1.3 MPF -13 G- 481.0 487~, $00 500 ,7.5 1.3 MPF-01 G-I 570~8 $77.0 500 $00 7_~ 13 Exit Danger Zone Exit Shut-in Zone Close Approach Status OK OK OK OK OK OK OK OK OK OK O't i995 Gas Cons. Commission 'Anchorage WELL PERMIT CHECKLIST COMPANY INIT CLASS WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev~ redrll [] serv [] ON/OFF ADMINISTRATION 1. Permit fee attached ................... N 2. Lease number appropriate ............... Y N 3. Unique well name and number .............. Y N 4. Well located in a defined pool .............. Y N 5. Well located proper distance from drlg unit boundary. N 6. Well located proper distance from other wells ..... N ' 7. Sufficient acreage available in drilling unit ..... N 8. If deviated, is wellbore plat included ........ N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... (.=Y! N~ 11. Permit can be issued without conservation order .... Y N 12. Permit can be issued without administrative approval..~ N 13. Can permit be approved before 15-day wait ....... N ENGINEERING Ai~PR DA~,/ / 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. 29. Conductor string provided ............... .~ N Surface casing protects all known USDWs ........ .y~ N CMT vol adequate to circulate on conductor & surf csg.. N CMT vol adequate to tie-in long string to surf csg . . ~ CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage or reserve pit ............. N If a re-drill, has a 10-403 for abndnmnt been approved. .Y N Adequate wellbore separation proposed ......... ~ N If diverter required, is it adequate .......... ~ N Drilling fluid program schematic & equip list adequate N BOPEs adequate ............ ~ ...... N BOPE press rating adequate; test to ~ psig., N Choke manifold complies w/API RP-53 (May 84) ..... ; .~ ~ Work will occur without operation shutdown ....... .~ N Is presence of H2S gas probable ............ Y~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y /~ _ 31. Data presented on potential overpressure zones ..... Y/ N ~.. /~ 33. Seabed condition survey (if off-shore) ....... ~ Y N 34. Contact name/phone for weekly progress reports . . ./.. Y N [exploratory only] ~ GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:%FORMS%cheklist rev 03/94 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. , No special effort has been made to chronologically organize this category of information. MPF-78 qS- lqq, MILNE POINT I,tOV 5 0 1995 .-~: ::.~-,::~ lga~ Oil & Gas Cons. uommisslon ' -- ) ~'q ' ' '~ ;' - :-~.-:~- 5"~7..i-,' ..: '. ,.' '- : · ' / ' . - /-;:,..., -. ~: ~ ~,::,- :,,:.. .. ,......~ / .......... . ....... ..,..~,..~...... .. __ ~ ..~%~%_~. . / ~::: ..... ~. * .. .~ ~- ~ -.... ~ .~-:',.:~. .: · ~ ~ ,. ~- .- ~ :~. - ;.' '"5 '".' .'- 2'-'."; .... ~' '- - '. - ..... , ,. tk ~ -t-,~--..----:- . , .... -:- ....... :,:~/- ..~ . . ~ ........... /~ ........ : ........................... _...~ ~ ~ . . ~:~.:~. 4-' "e:~ '<'~ ~::'::' .... ::::":~:"~":"~:"':":':-': :"~;"'q ':' ; ':-"::~--::' ~'"'~" Run 1' ~-,:...~ ~ · ~.';~'~,- -':;-::,~ :_--;_L': ~_ :-.--':. "' - ~:_- ~_::- ' ' · ~' ~ ' ~--::~ ~::..:-:: . -~- .---~.. :..:....: .... %- ~-.:.~.: :.. - .,] ~,.% ~ : :. ~..;..... .... . .:.. :,-:...:: .... = _~ ~- 06 November 1995 .~ .~/ ~,. ,..-: ..... .¢ : ........ , ..... ,-:.:--_--:,._~,.~_, _ · L' ~.L/ ~-- ::::::::: :::::::::::: ;--:-:.: :;: ..~2~:'::(~: - -.-:. -:-:.-:¢' ,. ~ --.:,-- .... ,. :.-.--.-.-,-...--.-.-.-., ..-:~:-.:.. ~RCH ~ ~ ~ ~"'":;'""'~'~' ~:'":'" ;.- .... ::~.~¢~ ...-.:- : ..~-- · _..: ~ ~" . ;~ . - ~.~---'. -~::.~-C'.;.';'-~(.:.~-;-.':~f;-~-~-':--:; ~ ':~ .'.:'~. a~~ ~ ;~ [ ~;.; :Y-?-'.;'; Yh_-k;'. ~_--~:- ~ '. :>--;.:":~: :- ~'.' >-'.'~:: ~ . : --~. -. "~ ' '. ," ; L::;,: :-: .- ..--?~ ,.-"-,.~F~ -;-, .. 13703 15744 ~pe Subfile 2 is type: L~ TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPF - 78 500292259900 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 20-NOV-95 6512.00 K. RICHARDS J. FOX 6 13N 10E 2237 2555 47.54 46.04 12.20 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 20.000 113.0 3RD STRING 9.625 7919.0 PRODUCTION STRING 7.000 16042.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: GR GRCH 1 1 06-NOV-95 WESTERN ATLAS LOGGING SERVICES EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: Marked Line GR. 91.10 40.00 26.00 *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MAGNETIC MARKS FOR DEPTH CONTROL. FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 13703.0 15744.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT * FORMAT RECORD : BP EXPLORATION (ALASKA) : MPF - 78 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA (TYPE# 64 ) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI * DATA RECORD (TYPE# 0) Total Data Records: 33 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1022 BYTES * 4 4 30 310 01 1 Tape File Start Depth = 15760.000000 Tape File End Depth = 13696.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8259 datums Tape Subfile: 2 123 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GRCH 15423.0 $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH GRCH 15480.5 15481.5 15491.0 15492.0 15497.0 15498.5 15508.0 15510.0 15517.5 15518.5 15536.5 15537.5 15540.0 15540.5 15549.0 15550.0 15585.5 15586.0 15591.0 15591.5 15595.0 15595.5 15604.0 15604.0 15605.5 15605.5 15609.5 15611.5 15611.5 15613.5 15626.0 15627.0 15628.5 15630.0 15638.5 15639.0 15652.5 15653.0 15677.5 15678.0 15700.5 15700.5 15713.0 15713.5 15718.0 15718.5 15721.5 15722.5 15728.5 15728.0 $ REMARKS: PASS 2 (REPEAT PASS). for each pass in separate files. STOP DEPTH 15738.0 (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH CN WN FN COUN STAT / ? ?MATCH. OUT $ : BP EXPLORATION (ALASKA) : MPF - 78 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units GRCH GR 68 1 GAPI * DATA RECORD (TYPE# 0) Total Data Records: API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1022 BYTES * 4 4 30 995 99 1 Tape File Start Depth = 15751.000000 Tape File End Depth = 15415.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1347 datums Tape Subfile: 3 62 records... Minimum record length: Maximum record length: 62 bytes 1022 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13703.0 $ LOG HEADER DATA STOP DEPTH 15753.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SBAR SBAR PCM GR P/T $ ROLLER SINKER BAR SINKER BAR ROLLER SINKER BAR PCM/CCL G~ RAY PRE S SURE / TEMPERATURE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 06-NOV-95 FSYS REV. J001 VER. 1.1 2241 05-NOV-95 15961.0 15747.0 13700.0 15744.0 1800.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 8255XA .000 16042.0 .0 SOURCE WATER/DIESEL 8.40 .0 182.0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE ~ORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS. ' PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF - 78 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 166 Tape File Start Depth = 15760.000000 Tape File End Depth = 13696.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49545 datums Tape Subfile: 4 242 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 15423.0 $ LOG HEADER DATA STOP DEPTH 15744.0 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT): TD LOGGER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SBAR SBAR PCM GR P/T $ ROLLER SINKER BAR SINKER BAR ROLLER SINKER BAR PCM/CCL GAMMA RAY PRE S SURE / T EMP ERATURE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM): FLUID LEVEL (FT): FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT): GAS/OIL RATIO: CHOKE (DEG): NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 06-NOV-95 FSYS REV. J001 VER. 1.1 2226 05-NOV-95 15961.0 15747.0 13700.0 15744.0 1800.0 YES TOOL NUMBER 8250EA/8248EA 8262XA 8255XA .000 16042.0 .0 SOURCE WATER/DIESEL 8.40 .0 182.0 0 .0 .000 .000 .000 .0 .00 .000 BLUELINE COUNT RATE ~'ORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS) . $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF - 78 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TEN GR 68 1 GAPI 4 1 4 1 F/MN 4 1 LB 4 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 27 Tape File Start Depth = 15751.000000 Tape File End Depth = 15415.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 8073 datums Tape Subfile: 5 103 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS 95/11/20 01 **** REEL TRAILER **** 95/11/21 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 21 NOV 95 9:22a Elapsed execution time = 1.59 seconds. SYSTEM RETURN CODE = 0 · 'ape Subfile 2 is type: LIS TAPE HEADER PRUDHOE mAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPER3XTOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 6580.00 MARK HANIK J. GAFFANEY MPF-78 500292259900 BP EXPLORATION (ALASKA) INC. SPERRY-SUN DRILLING SERVICES 06-MAR-96 MWD RUN 2 J. S TRAHAN J. GAFFANEY MWD RUN 3 J. S TRAHAN J. GAFFANEY MWD RUN 4 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: J. STRAHAN J. ROBERTSON WELL CASING RECORD MWD RUN 5 A. PIEPER J. ROBERTSON 6 13N 10E 2237 2555 47.54 46.04 12.20 OPEN HOLE CASING o,,,---_ DRILLERS 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 9.625 7919.0 8.000 16070.0 MWD - GR/EWR4/SLD/CNP. ALL DEPTHS ARE MEASURED BIT DEPTHS. MWD RUNS 1, 2, & 3 WERE DIRECTIONAL, GAMMA RAY (SGRC/ DGR), & PHASE-4 RESISTIVITY (EWR4) . MWD RUNS 4 & 5 WERE DIRECTIONAL, GAMMA RAY (SGRC/DGR), PHASE-4 RESISTIVITY (EWR4), COMPENSATED NEUTRON POROSITY (CNP), & STABILIZED LITHO DENSITY (SLD). ENVIRONMENTAL PARAMETERS USED FOR PROCESSING NUCLEAR LOG DATA: HOLE SIZE = 8.5" MUD FILTRATE SALINITY = 400 - 1000 ppm MUD WEIGHT = 8.4 - 10.1 ppg FORMATION WATER SALINITY = 14545 ppm FLUID DENSITY = 1.0 g/cc MATRIX DENSITY = 2.65 g/cc LITHOLOGY = SANDSTONE. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP RHOB NPHI $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH 197.0 189.0 7912.0 7912.0 BASELINE DEPTH GR 189.0 197.0 14330.0 14338.0 14747.5 14752.0 14917.5 14921.5 15012.0 15018.5 15228.0 15228.5 15246.0 15249.5 15275.0 15278.0 15290.5 15296.5 15380.0 15382.5 15482.0 15486.5 15516.5 15521.0 15540.0 15543.5 15587.5 15591.5 15631.0 15635.0 15650.5 15654.0 15671.0 15675.0 15674.0 15678.5 15699.5 15704.0 15712.5 15719.0 16063.5 16070.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: all bit runs merged. STOP DEPTH 15995.0 15968.0 15985.0 15976.0 (WALS, 06-NOV-95) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 49.0 4365.0 2 4365.0 7160.0 3 7160.0 7945.0 4 7945.0 11324.0 5 11324.0 16070.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. CN /??SHIFT. OUT : BP EXPLORATION (ALASKA) : MPF-78 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 1513 Tape File Start Depth = 16070.000000 Tape File End Depth = 189.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 381157 datums Tape Subfile: 2 1635 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 205.0 EWR4 197.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MA~XIMUMANGLE: STOP DEPTH 4314.0 4306.0 19-SEP-95 ISC 2.11 CIM 3.94 MEMORY 4365.0 49.0 4365.0 0 .9 74.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ TOOL NI/MBER P0404CRG8 P0404CRG8 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 12.250 .0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: SP~ 9.30 61.0 8.5 1300 8.2 1.900 1.440 2.100 2.500 74 .0 100.0 74 .0 74.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 REMARKS: CN WN FN COUN STAT MWD RUN 1. $ BP EXPLORATION (ALASKA) MPF-78 MILNE POINT NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 271 Tape File Start Depth = 4375.000000 Tape File End Depth = 175.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 67209 datums Tape Subfile: 3 336 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMNLARY VENDOR TOOL CODE START DEPTH GR 4315.0 EWR4 4307.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7110.0 7102.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEPJkTURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 21-SEP-95 ISC 2.11 CIM 3.94 MEMORY 7160.0 4365.0 7160.0 0 70.9 74.5 TOOL NUMBER P0404CRG8 P0404CRG8 12.250 .0 SPUD 9.30 57.0 9.0 1200 7.8 1.900 1.270 2.100 2.500 74.0 114.0 74.0 74.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 2. $ : BP EXPLORATION (ALASKA) : MPF-78 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 188 Tape File Start Depth = 7200.000000 Tape File End Depth = 4300.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 427566 datums Tape Subfile: 4 253 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 7026.0' EWR4 7011.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7897.0 7890.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 22-SEP-95 ISC 2.11 CIM 3.94 MEMORY 7945.0 7160.0 7945.0 0 71.4 72.7 TOOL NUMBER P0404CRG8 P0404CRG8 12.250 .0 SPUD 9.50 43.0 9.0 1200 8.2 1.900 1.280 2.100 2.500 74.0 113.0 74.0 74.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 3. $ : BP EXPLORATION (ALASKA) : MPF-78 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 65 Tape File Start Depth = 8000.000000 Tape File End Depth = 7000.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 83218 datums Tape Subfile: 5 130 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Tape Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 F I LE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 7879.0 11257.0 EWR4 7851.0 11230.0 SLD 7872.0 11246.0 CNP 7860.0 11238.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. CNP COMPENSATED NEUTRON SLD STAB. LITHO DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 26-SEP-95 ISC 2.11 CIM 3.94 MEMORY 11324.0 7945.0 11324.0 0 70.1 73.8 TOOL NUMBER P0408CRNSLDG6 P0408CRNSLDG6 P0408CRNSLDG6 P0408CRNSLDG6 8.500 7919.0 LSND 9.30 45.0 9.0 750 7.2 3.200 1.970 3.200 4.500 70.0 128.0 7O.0 70.0 SANDSTONE 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 4. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-78 : MILNE POINT : NORTH SLOPE : ALASKA 8.500 .0 0 * FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMS4 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 335 Tape File Start Depth = 11350.000000 Tape File End Depth = 7840.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 511819 datums Tape Subfile: 6 404 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11257.0 EWR4 11230.0 SLD 11247.0 CNP 11238.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMI/M ANGLE: MAXIMUM ANGLE: STOP DEPTH 16002.0 15975.0 15991.0 15982.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD STAB. LITHO DENSITY DGR DUAL GAMMA RAY $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: 02-OCT-95 ISC 2.11 CIM 3.94 MEMORY 16070.0 11324.0 16070.0 0 25.9 73.2 TOOL NUMBER P0408CRNSLDG6 P0408CRNSLDG6 P0408CRNSLDG6 P0408CRNSLDG6 8.500 7919.0 LSND 10.10 40.0 9.5 3O0 4.2 1.500 0.680 1.450 2.500 74.0 173.0 74.0 74.0 SANDSTONE 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 5. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPF-78 : MILNE POINT : NORTH SLOPE : ALASKA 8.500 .0 0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 11 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FET MWD 68 1 HR 4 11 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 180 01 1 4 90 810 01 1 44 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 465 Tape File Start Depth = 16100.000000 Tape File End Depth = 11225.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 200231 datums Tape Subfile: 7 534 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 8 is type: LIS 96/ 3/06 O1 **** REEL TRAILER **** 96/ 3/ 6 O1 Tape Subfile: 8 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 6 MAR 96 11:25a Elapsed execution time = 11.21 seconds. SYSTEM RETURN CODE = 0
