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196-081
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. /~ '-0g) File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: 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: Beve~Vincent TO RE-SCAN Nathan Lowell Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 St, ,AWNED FEB 1 7 2012 do Mr. Tom Maunder �J j `) Alaska Oil and Gas Conservation Commission \i(A 333 West 7 Avenue c \i\ Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of MPK -Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from MPK -Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator 0 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) MPK 10/29/2011 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal .---+>' MPK -02 1960810 50029226750000 0.2 NA 0.2 NA 5.1 9/5/2011 MPK -05 1960680 50029226700000 1.9 NA 1.9 NA 17.9 8/24/2011 MPK-06 1961910 50029227250000 1.5 NA 1.5 NA 8.5 8/27/2011 MPK-09 2050140 50029232470000 1.9 NA 1.9 NA 12.8 8/24/2011 MPK -13 1960400 50029226550000 1.7 NA 1.7 NA 14.5 8/24/2011 MPK -17 1960280 50029226470000 1 NA 1 NA 2.6 8/24/2011 MPK -18A 1970270 50029227330100 4.6 NA 4.6 NA 23.8 8/27/2011 MPK -21A 2031620 50029227180100 0.4 NA 0.4 NA 6.9 10/29/2011 MPK -22 2050220 50029232490000 2 NA 2 NA 5.1 8/27/2011 MPK -25 1960320 50029226500000 4.2 NA 4.2 NA 30.6 8/24/2011 MPK -30 1961680 50029227110000 1.5 NA 1.5 NA 17.0 8/25/2011 MPK-33 1962020 50029227290000 1.7 NA 1.7 NA 15.3 8/24/2011 MPK-34 1961690 50029227120000 2.5 NA 2.5 NA 25.5 8/25/2011 MPK-37 1960760 50029226740000 2 NA 2 NA 17.0 8/24/2011 MPK -38 1960300 50029226490000 3.2 NA 3.2 NA 15.3 8/25/2011 MPK -43A 1970410 50029227380100 _ 1.7 NA 1.7 NA 13.6 9/16/2011 ' STATE OF ALASKA ALASK/.. AND GAS CONSERVATION COMMIS.' REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑ Abandon ® Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Re -Enter Suspended Well ❑ Alter Casing ® Pull Tubing ❑ Perforate New Pool ❑ Waiver ® Other ❑ Change Approved Program ❑ Operation Shutdown ❑ Perforate ❑ Time Extension Change -Out ESP 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. ® Development ❑ Exploratory • 196 - 081 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: - P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 - 22675 - - 7. Property Designation: 8. Well Name and Number: ADL 375133 & 028231 r MPK - 9. Field / Pool(s): . Milne Point Unit / Kuparuk River Sands 10. Present well condition summary Total depth: measured 10212 feet Plugs (measured) 9919 feet true vertical 7231 feet Junk (measured) None feet Effective depth: measured 10192 feet Packer: (measured) 9829 / 9932 feet true vertical 7219 feet Packer: (true vertical) 7004 / 7065 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 4260' 9 -5/8" 4296' 3481' 5750 3090 Intermediate Production 10158' 7" 10192' 7219' 7240 5410 Liner 0, :Aiwa) € 7 2.(1 Perforation Depth: Measured Depth: 9848' - 9868' (above plug) True Vertical Depth: 7016' - 7027' (above plug) Tubing (size, grade, measured and true vertical depth): 2 -7/8 ", 6.5# L -80 9730' MD 6945' TVD Packers and SSSV (type, measured and true vertical depth): 7" HES Versatrieve Packer 9829' MD 7004' TVD 7" HES BWD Sump Packer 9932' MD 7065' TVD 11. Stimulation or cement squeeze summary: RECEIVED Intervals treated (measured): Treatment description including volumes used and final pressure: SEP 01 Alik a 011 & Gas Cam. Gommission Azt;:r,1: 2 12. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 0 1720 0 Subsequent to operation: 124 72 1589 500 187 13. Attachments: 14. Well Class after work: ❑ Copies of Logs and Surveys run ❑ Exploratory ' ® Development ❑ Service ❑ Stratigraphic IN Daily Report of Well Operations ® Well Schematic Diagram 15. Well Status after work: ❑ GINJ • ® Oil ❑ SUSP ❑ WDSPL ❑ Gas ❑ GSTOR ❑ SPLUG ❑ WAG ❑ WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Sean McLaughlin, 564 -4387 N/A Printed Name Elizabeth Barker Title Drilling Technologist ]' /�/� Prepared By Name/Number: Signature ® ��t""� 1 xa, Phone 564 -5674 Date f/ Elizabeth Barker, 564-5674 Form 10-404 Revised 111Y1010 RBDMS SEP 0 7 ZQ ?- 7fi Submit Original Only g /Yl� • • MPK -02 Well History (Pre Rig RWO) Date Summary 07/12/11 DRIFTED TBG W/ 2.09" BAR -BELL & 1.70" LIB, TAGGED ESP @ 9661' SLM/ 9665' MD ( -3' CORRECTION) RAN SBHPS MADE 15 MIN STOP @ 8780' MD, 3 HR STOP @ 9600' MD. CURRENTLY IN HOLE W/ CALIPER 07/13/11 RAN PDS CALIPER PER PROCEDURE. PULLED BK -DGLV FROM LOWER GLM @ 9512' SLM/ 9515' MD, POCKET LEFT OPEN PULLED DPSOV FROM UPPER GLM @ 122' SLM/ 137' MD, SET BK -DGLV 07/14/11 Counted turns on IA & bled off. PT lubricator to 300 psi low & 3500 psi high (charted). Set 2- 1/16" VR plug & removed front side IA. Installed tapped blind flange & torqued to API specs. PT flange x spool connection to 400 psi low and 3500 psi high (charted & recorded). 07/31/11 Verified barriers. C/O tree cap flange from WKM to a FMC Otis TQ all bolt to API spec, PT flange 300 low to 5000 psi charted , R/U lubricator & PT to low & high (charted) (For all subsequent lubricator breaks as well). « «« Set 2 9/16 H style BPV » » » ». Tested tree cap to 500 psi. Page 1 of 1 • North. America - ALASKA - BP Page 1 of 6 Operation Summary Report Common Well Name: MPK -02 AFE No Event Type: WORKOVER (WO) Start Date: 8/7/2011 End Date: X4- 00T5J -E (600,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/2/1996 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292267500 Active Datum: 2 : 02 10/29/1997 12:00 @50.45ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/6/2011 00:00 - 04:00 4.00 MOB P PRE MOB RIG OFF WELL MPK -30. - BACK ONTO REAR OF PAD. - STAGE RIG MATS OVER TO MPK -02. - MOB RIG OVER WELL. - 17:30 HRS ON 08/05/2011 24 HR NOTICE FOR UPCOMING BOPE TEST. LEFT MESSAGE. -17:40 HRS ON 08/05/2011 JOHN CRISP (AOGCC) WAIVED STATES RIGHT TO WITNESS. 04:00 - 11:00 7.00 MOB P PRE SHIM RIG OVER WELL. -SPOT FLOW BACK TANK AND ALL EQUIPMENT, PBU HARDLINE CREW TO RIG UP HARDLINE - TAKING ON FLUIDS , 120 DEG,8.45 PPG 1% KCL - RU CIRCULATION LINES - TEST LINES TO 3500 PSI FOR 5 CHARTED MIN - PU & MU DSM LUBRICATOR. - ACCEPT RIG AT 0600 HRS. 11:00 - 11:30 0.50 KILLW P -_ DECOMP RIG EVAC DRILL - HOLD AAR WITH CREW, SCS, WSL. 11:30 - 14:30 3.00 KILLW P DECOMP NU DSM LUBRICATOR - PRESSURE TEST LUBRICATOR - 250 PSI LOW AND 3500 PSI HIGH - HAD SOME TROUBLE GETTING A TEST ON THE LUBRICATOR, HAD TO INSTALL A BLOCK VALVE ON THE WING - PULLED THE BPV - TBG= 1500 PSI - I.A. = 1550 PSI 14:30 - 18:30 4.00 KILLW P DECOMP PJSM FOR GAS VENTING OPERATIONS - MADE NOTIFICATIONS TO DRILLSITE OPERATOR AND MPU SECURITY. - STARTED WITH THE I.A. , BLED FROM 1550 PSI TO 200 PSI , OPENED THE TUBING & BLED BOTH FROM 430 PSI TO 110 PSI. - SHUT IN AND LINED UP TO PUMP DOWN THE TUBING. 18:30 - 21:00 2.50 KILLW P DECOMP PUMPED 100 BBLS SEAWATER DOWN THE TUBING @ 6 BPM AND 920 PSI. - NO RETURNS WHILE PUMPING DOWN TUBING. -LINE UP AND BULL HEAD 500 BBLS OF SEAWATER AT 7 BPM AND 690 PSI. - MONITOR THE WELL FOR 30 MIN. WELL ON A VAC. - FEED THE WELL AT 30 BPH. 21:00 - 23:30 2.50 WHSUR P DECOMP PJSM FOR SETTING TWC. -R/U DSM LUBRICATOR AND TEST TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. -SET TWC AND ATTEMPT TO TEST FROM BELOW AT 7 BPM AND 12 PSI. FOR 50 BBLS. -TEST TWC FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH. GOOD TEST. 23:30 - 00:00 0.50 WHSUR P -_ DECOMP PJSM ON N/D TREE. -R/U • p : . • . m Printed 9/1/2011 9:25:13AM O rth America - ALASKA --SP Page 2 of 6 Operation Summary Report Common Well Name: MPK -02 AFE No Event Type: WORKOVER (WO) Start Date: 8/7/2011 End Date: X4- 00T5J -E (600,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/2/1996 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292267500 Active Datum: 2 : 0 10/29/1997 12:00 @50.45ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/7/2011 00:00 - 01:00 1.00 WHSUR P -_ DECOMP PJSM - FINISH N/D TREE. 01:00 - 04:00 3.00 BOPSUR P DECOMP PJSM FOR WU BOPE. -N /U 13 -5/8" BOPE WITH 2 - 7/8" X 5" VRRS MUD CROSS, BLIND SHEARS, ANNULAR PREVENTER. 04:00 - 09:30 5.50 BOPSUR P DECOMP PJSM FOR INSPECTING AND CHANGING OUT ANNULAR PREVENTER. - INSTALLED A JNT OF 2 -7/8" TUBING, CLOSED THE ANNULAR AND FILLED WITH WATER ON TOP. - ANNULAR WOULD NOT SEAL ENOUGH TO /� HOLD WATER. 8 - REMOVED THE TOP OF THE ANNULAR FOR INSPECTION, THE RUBBER ELEMENT LOOKED TO BE IN GOOD SHAPE - ELEMENT WAS REMOVED AND THE INNER SEALS OF THE ANNULAR WERE TESTED, NO LEAKS DETECTED. - THE RUBBER ELEMENT WAS CLEANED UP AND INSPECTED THEN CHANGED OUT WITH A NEW ONE. 09:30 10:30 1.00 BOPSUR P ■- DECOMP ANNULAR RD ANNULAR MAINTENANCE TOOL. TOOL. - BU BELL NIPPLE & RISER 10:30 - 11:30 1.00 BOPSUR P -_ DECOMP NILRFJ L NIPPLF -NU RISER. 11:30 - 12:00 0.50 BOPSUR P ._ DECOMP FUNCTION TEST ELEMENT. - BLEED AIR FROM ANNULAR PREVENTER 12:00 - 13:00 1.00 BOPSUR P -_ DECOMP PJSM - R/U TO TEST BOPE 13:00 - 19:00 6.00 BOPSUR P DECOMP PJSM FOR TESTING BOPE. PRESSURE TESTING 3- PREVENTER 13 -5/8" BOPE - ANNULAR, BLIND SHEARS, MUD CROSS, AND 2 -7/8" X 5" VBR'S. - TEST TO 250 -PSI LOW AND 3500 -PSI HIGH D FOR 5 -MIN EACH CHARTED ti - TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. - RAMS TESTED TO 250 PSI LOW AND 3500 PSI HIGH. - TESTED USING A 2 -7/8" TEST JOINT. - TESTS WITNESSED BY BP WSL, DDI TP, DDI DRILLER - WITNESS OF TEST WAIVED BY JOHN CRISP (AOGCC) @ 1740 5/5/11. - KOOMEY TEST 2850, 1500, 900 PSI, DRAW DOWN TO 1900, 1500, 900 PSI. 15 SECS FOR A 200 PSI INCREASE AND 73 SEC FOR FULL PRESSURE. 5 NITROGEN BOTTLES AT 1800 PSI AVERAGE. -F /P ON #1 CHOKE VALVE, GREASED VALVE AND RETESTED GOOD. ALL OTHER TEST WHERE PASS. 19:00 - 19:30 0.50 BOPSUR P -_ DECOMP BLOW DOWN LINES. -R/D TEST EQUIPMENT Printed 9/1/2011 9:25:13AM rth America - ALASKA - BP Page 3 of 6 Operation Summary Report Common Well Name: MPK -02 AFE No Event Type: WORKOVER (WO) Start Date: 8/7/2011 End Date: X4- 00T5J -E (600,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud DaterTime: 5/2/1996 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292267500 Active Datum: 2 : 02 10/29/1997 12:00 @50.45ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 21:30 2.00 BOPSUR P DECOMP PJSM -R/U DSM LUB AND OPSO LOPSO - PRESSURE TEST 250 PSI LOW 5 MIN CHARTED - GOOD TEST - PRESSURE TEST 3500 PSI HIGH 5 MIN CHARTED - GOOD TEST -PULL TWC. -R/D DSM. 21:30 - 22:30 1.00 PULL P DECOMP PJSM -M /U LANDING JOINT TO TUBING HANGER. -FMC BOLDS. 22:30 - 23:30 1.00 PULL P DECOMP PJSM FOR PULLING HANGER. - P/U ON HANGER WITH 120K, THEN BREAK , OVFR TO 115K UP WEIGHT/ - BULL HEAD 70 BBLS OF SEAWATER AT 7 BPM AND 1990 PSI. - ATTEMPT TO FILL WELL AND ESTABLISH LOSS RATE. FILL THROUGH KILL LINE AND FILL LINE PUMPING 60 BBLS IN 10 MINS. NO SIGN OF RETURNS. CONTINUE TO FILL HOLE AT 30 BPH. 23:30 - 00:00 0.50 PULL P DECOMP CENTRILIFT / FMC TERMINATE ESP CABLE FROM HANGER. -R/U SHEAVE. 8/8/2011 00:00 - 03:00 3.00 PULL P DECOMP FINISH R/U SHEAVE ANF RUNNING ESP LINE TO SPOOLING UNIT. -POOH RACKING BACK 2 -7/8" 6.5# L -80 8 RD, EUE TUBING FROM 9.742', - FILLING HOLE AT 40 BPH. 03:00 - 03:30 0.50 PULL P DECOMP UNANNOUNCED KICK WHILE TRIPPING DRILL. - COMPLEXITY OF FIRE DRILL IN THE MOTOR ROOM. -HANDS JUST RACKED STAND BACK, BROUGHT BLOCKS DOWN AND P/U SECOND STAND PULLED UP 30' AND SIMULATED CUTTING ESP. BROUGHT STAND DOWN AND STABBED VALVES. CLOSED IN BAG. THEN FIRE WAS ANNOUNCED IN MOTOR ROOM WHERE A WELDER WAS WORKING. ALL HANDS RESPONDED. APPROPRIATELY. -AAR: DISCUSSED STABBING FLOOR VALVE FIRST THEN P/U AND CUTTING ESP CABLE AFTER TIE OFF SO NOT TO SPOOL OVER SHEAVE ONCE CUT. DISCUSSED ANNOUNCING TO LOADER OF DRILL OVER THE DOYON 16 NET INSTEAD OF A PERSONAL RADIO LINE AS TO ALLOW THE SPOC TO ALSO BE NOTIFIED. - CONTINUE TO FILL THE HOLE AT 40 BPH. 03:30 - 09:30 6.00 PULL P DECOMP POOH RACKING BACK 2 -7/8" 6.5# L -80 8 RD EUE TUBING. - MAINTAIN HOLE FILL AT 40 BPH. - VISUALLY INSPECTING - CHANGE OUT JNT # 191 - 159 LASALLE CLAMPS RECOVERED, 6 PROTECTOLIZERS RECOVERED , 3 FLAT GUARDS RECOVERED Printed 9/1/2011 9:25:13AM • rth America - ALASKA - BP Page 4 of 6 Operation Summary Report Common Well Name: MPK -02 AFE No Event Type: WORKOVER (WO) Start Date: 8/7/2011 End Date: X4- 00T5J -E (600,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/2/1996 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292267500 Active Datum: 2 : 02 10/29/1997 12:00 @50.45ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 11:30 2.00 PULL P DECOMP MONITOR WELL BEFORE PULLING NON SHEARABLE THRU THE STACK - TERMINATE ESP CABLE - BREAK AND LD MOTOR AND PUMP ASSEMBLY - CENTRILIFT REP MAKING INSPECTIONS OF PUMP 11:30 - 12:30 1.00 RUNCOM P RUNCMP CLEAN AND CLEAR RIG FLOOR - REMOVE OLD ESP FROM PIPE SHED - INSTALL NEW ESP COMPLETION - MAINTAIN CONSTANT HOLE FILL AT 40 BPH. - INSTALL NEW ESP SPOOL IN THE SPOOLING UNIT. 12:30 - 17:00 4.50 RUNCOM P RUNCMP PJSM FOR PU & MU NEW ESP ASSEMBLY & NON SHEARABLES ACROSS THE STACK - VERIFIED SIZE AND SERIAL # & HORSE POWER OF THE ESP - CENTRILIFT REP MAKING THE MOTOR LEAD CONNECTION - MAKE UP MOTOR AND PUMP ASSEMBLY - HELD TABLE TOP WELL CONTROL DRILL, WITH NON SHEARABLES ACROSS THE STACK WE DISCUSSED THE STEPS THAT WOULD BE TAKEN IF THE WELL STARTED COMING ON. AAR: WAS DISCOVERED THAT WE NEVER REALLY TOLD THE THIRD PART CENTRILIFT HANDS WHAT THEY WERE SUPPOSED TO DO DURING A WELL CONTROL EVENT. 17:00 - 21:00 4.00 RUNCOM P RUNCMP RIH WITH NEW ESP ASSEMBI Y ON 2 -7/8" fi 5# L -80 8 RD EUE TUBING FROM THE DERRICK FROM 105 TO 3,425' -CHECK CONDUCTIVITY EVERY 2000', PUMP 1.5 BPM AT 20 PSI. - MAINTAIN CONTINUOUS HOLE FILL AT 40 BPH. 21:00 - 21:30 0.50 RUNCOM P RUNCMP UNANNOUNCED KICK WHILE TRIPPING IN THE HOLE DRILL. -THE POWER TONGS FAILED WHILE MAKING UP A STAND WHEN THE FLOW METER SHOWEDA 30% INCREASE IN FLOW. -THE HANDS WHERE ATTEMPTING TO GET THE POWER TONGS OFF OF THE STAND TO FREE THE UNTORQUED STAND AND STAB THE FLOOR VALVE WITH OUT SUCCESS. THE HANDS THEN TOLD THE DRILLER THAT THE BLIND /SHEARS NEED TO BE CLOSED. THIS WOULD HAVE BEEN THE ONLY OPTION AT THE TIME BUT IT TOOK THE CREW ABOUT 8 MIN. TO DETERMINE THIS. -AAR WE DISCUSSED THAT WHEN THERE IS AN EQUIPMENT FAILURE ON THE RIG THE FIRST THOUGHT NEEDS TO BE WELL CONTROL, THEN HOW DO WE FIX THE PROBLEM, BUT HAVE IT THOUGHT OUT ON HOW TO CONTROL THE WELL IN THE SCENERIO AT THAT EXACT MOMENT. THE CREW THOUGHT IT WAS A GREAT LEARNING EXPERIENCE DUE TO THE FACT THE OF THE FAILURE AND THAT IT CAUSED A BIT OF CONFUSION FOR 8 MIN. 21:30 - 22:00 0.50 RUNCOM P RUNCMP RIG SERVICE. REPAIR THE POWER TONGS. Printed 9/1/2011 9:25:13AM • rth.America - ALASKA - BP page.5 of 6 Operation Summary Report Common Well Name: MPK -02 AFE No Event Type: WORKOVER (WO) Start Date: 8/7/2011 End Date: X4- 00T5J -E (600,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/2/1996 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292267500 Active Datum. 2 : 02 10/29/1997 12:00 @50.45ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 00:00 2.00 RUNCOM P RUNCMP RIH WITH NEW ESP ASSEMBLY ON 2 -7/8" 6.5# L -80 8 RD EUE TUBING FROM THE DERRICK FROM 3,425' TO 5,330'. -CHECK CONDUCTIVITY EVERY 2000', PUMP 1.5 BPM AT 20 PSI. - MAINTAIN CONTINUOUS HOLE FILL AT 40 BPH. 8/9/2011 00:00 - 02:30 2.50 RUNCOM P RUNCMP RIH WITH NEW ESP ASSEMBLY ON 2 -7/8" 6.5# L -80 8 RD EUE TUBING FROM THE DERRICK FROM 5,330' TO 7,687'. -CHECK CONDUCTIVITY EVERY 2000', PUMP 1.5 BPM AT 20 PSI. - MAINTAIN CONTINUOUS HOLE FILL AT 40 BPH. 02:30 05:30 3.00 RUNCOM P ■- RUNCMP REEL REEL ESP CAE - MAINTAIN CONTINUOUS US HOLE FILL AT 40 BPH. 05:30 - 08:00 2.50 RUNCOM P RUNCMP RIH WITH NEW ESP ASSEMBLY ON 2 -7/8" 6.5# L -80 8 RD EUE TUBING FROM THE DERRICK FROM 7,687' 9,710' -CHECK CONDUCTIVITY EVERY 2000', PUMP 1.5 BPM AT 20 PSI. - USING BEST -O -LIFE 2000 GREASE - OPTIMUM TORQUE 2300 FT /LB USED - MAINTAIN CONTINUOUS HOLE FILL AT 40 BPH. 08:00 - 10:00 2.00 RUNCOM P RUNCMP a -7/8" • NDING HAN ER TWC INSTALLED - CENTRILIFT MAKING PENETRATOR SPLICE CONNECTION & CHECKING CONNECTIVITY, EVERYTHING TESTED GOOD - INSTALL BRASS SHIPPING CAP - LAND HANGER , FMC REP TO RILDS - PUW 115K , SOW 77K - RIGGING DOWN ESP SHEIVE, POWER TONGS CLEAN & CLEAR RIG FLOOR. 10:00 - 11:30 1.50 RUNCOM P RUNCMP RIG UP TO TEST TWC - ATTEMPTED TO TEST FROM BELOW, PUMPED 40 BBLS WITH 30 PSI @ 4BPM - TESTED FROM ABOVE WITH 250 PSI LOW AND 3500 PSI HIGH, BOTH CHARTED, BOTH TESTS GOOD. 11:30 12:00 0.50 RUNCOM P ■- RUNCMP LD LANDING JOINT - -SUCC O K OUT THE STACK - PREP FOR ND BOPE AND NU OF TREE. 12:00 14:00 2.00 RUNCOM P RUNCMP PJSM - N/D13 -5/8 5M BOPE 14:00 - 14:30 0.50 WHSUR P -_ RUNCMP FMC PREP WELL HEAD - CENTRILIFT PERFORM ESP INTEGRITY TEST 14:30 - 15:30 1.00 WHSUR P -_ RUNCMP PJSM -N /U PRODUCTION TREE 15:30 - 16:30 1.00 WHSUR P -_ RUNCMP FMC REP. TESTED TUBING HANGER VOID. - TESTED TO 5000 PSI FOR 30 MIN 16:30 - 18:30 2.00 WHSUR P RUNCMP PJSM - PRESSURE TEST TUBING HEAD ADAPTER AND TREE -250 PSI LOW 5 MINUTES, 5000 PSI HIGH 5 MINUTES - EACH CHARTED Printed 9/1/2011 9:25:13AM O rth America- ALASKA - BP Page 6 of 6 Operation Summary Report Common Well Name: MPK -02 AFE No Event Type: WORKOVER (WO) Start Date: 8/7/2011 End Date: X4- 00T5J -E (600,000.00 ) Project: Milne Point Site: M Pt K Pad Rig Name /No.: DOYON 16 Spud Date/Time: 5/2/1996 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292267500 Active Datum: 2 : 0 2 10/29/1997 12:00 @50.45ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 00:00 5.50 WHSUR P POST PJSM -RU DSM LUBRICATOR AND TEST 250 LOW 3500 HIGH -PULL TWC AND RD -R/U LRS, PRESSURE TEST LINES - FREEZE PROTECT 16 BBLS DOWN TUBING - 2 BBLS MINUTE @ 400 PSI. -SET BPV, TEST FROM BELOW WITH ROLLING TEST BY LRS -LRS PUMP 68 BBLS DOWN VA 2 BBLS A MINUTE @ 650 PSI, WELLHEAD PRESSURE =0 R/D LRS. RIG RELEASED FROM MPK -02 AT MIDNIGHT SEE DOYON 16 SUMMER MAINTENANCE FOR FURTHER. Printed 9/1/2011 9:25:13AM • • Tree: 2 9/16" - 5M CIW MP -O2 ORIG. KB. ELEV = 61' (N 27. Wellhead: 11" 5M FMC Gen 5A 1 ORIG. GL. ELEV = 33' (N 27 -E) w/ 2 7/8" FMC Tubing Hanger , EUE lift threads, 2.5" CIW H BPV profile 20 ", 91.1#, NT -80, 112' T „z WELD Camco 2 7/8” x 1" sidepocket KBMM GLM 136' KOP @ 1100' MAX HOLE :Angle 53.82° @ 9644' 9 5/8 ", 40 # /ft, I ' L -80 Btrc. 4296 Screens perforated. Watch for sand production! Tungsten coated pump stages to handle flower sand production. 2 7/8" 6.5 ppf, L -80, 8 rd EUE tbg.. ( drift ID = 2.347 ", cap. = 0.00592 bpf " Camco 2 7/8" x 1" sidepocket 9515' KBMM GLM x,, ; i 2 -7/8" HES XN nipple 9651 2.250" minium ID . ' i toor., Tandem Pump, 137 P -17 SXD al Tungsten stages 9668' j Pump TVD 6906' LIM %A Gas Separator CSE27610GA 9688' It `i Tandem Seal Section 9700` —r GSB3DBLT SB /SB P FSA m Stimulation Summary — , KMH Motor 228 HP / 2305 volt 8707' Me 60 amp (Re -rated to 195/2145/52, IIAA 6 PumpMate XTO w/6 fin Centralizes 9726' 4E1 V PumpMate TVD 6951' Perforation Summary Ref Ioa: 07/08/96 CCL / GR 1 i 7" HES versatrieve packer 9829' SIZE SPF INTERVAL (TVD) 1 1 Note: Perf holes through screens w ii C -Sands k4 il 4.5" N -80, 20/40 Ga. il 4.5" 5 9,848' - 9,908' 7,016' - 7,051' to Pii Pall well screens 2 -7/8" 5 9,848' - 9,868' 1 i 4.5" HES XN nipple Plug in XN nipple 9919 B -Sands 3.813" ID w/ 3.75" no go 4.5" 5 9,946' - 9,964' 7,074'- 7,085' I 7" HES `BWD' sump packer 1 9932' PBTD 10110' Collet shoulder 9936' 7" 26 #, L -80, Mod. BTRS 10192' DATE REV. BY COMMENTS MILNE POINT UNIT 5/14/96 M.Linder Drilled and cased well Nabors 27 -E 8/09/96 M.Linder Completion Nabors 4 -ES WELL MPU K -02 ESP Change out 5 S 11/08/97 / 05/20/98 ESP Change add screen API NO 50-029 -22675 05/12/01 B. Hasebe Nabors 4ES ESP RWO /Pert Screens 06/03/02 MDO ESP Completion 4 -es 11/08/02 M.Linder New ESP (Old gas separator cut out by sand. No gas separator installed during completion. 11/03/5 Lee Hulme ESP change out N -4ES BP EXPLORATION (AK) 08/10/11 B. Bixby ESP change out Doyon 16 _ STATE OF ALASKA RECEIVED ALASKA~ AND GAS CONSERVATION CcAlSSION . REPORT OF SUNDRY WELL OPERATIONS DEC 052005 1. Operations Performed: Chan e D Abandon D Suspend D Operation Shutdown D Perforate a Other D Alter Casing a Repair Well D Plug Perforations D Stimulate D Re-Enter Suspended Well D Change Approved Program a Pull Tubing D Perforate New Pool D Waiver D Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit 10 unll Number: BP Exploration (Alaska) Inc. a Development D Exploratory 196-081 .';¡' ! 3. Address: D Stratigraphic D Service 6. API Numbér: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22675-00-00 7. KB Elevation (ft): 61.33 9. Well Name and Number: MPK-02 8. Property Designation: 10. Field / Pool(s): ADL 028231 Milne Point Unit / Kuparuk River Sands 11. Present well condition summary Total depth: measured 10212 feet true vertical 7231 feet Plugs (measured) 9919 Effective depth: measured 9919 feet Junk (measured) None true vertical 7058 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 112' 112' Surface 4260' 9-5/8" 4296' 3481' 5750 3090 Intermediate Production 10158' 7" 10192' 7219' 7240 5410 Liner ~AWNE' . Dr: f' <j. f· ,fiD'" Perforation Depth MD (ft): 9848' - 9964' \,..>d'ib ."" ....1.,) ,,~.,..'>.! Perforation Depth TVD (ft): 7016' - 7085' 2-7/8", 6.5# L-80 9744' Tubing Size (size, grade, and measured depth): . Packers and SSSV (type and measured depth): 7" HES Versatrieve Packer 9829' 7" HES BWD Sump Packer --~.. - 9932' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final pressure: RBDMS 8Fl DEL î~ ],nl}) 13. Representative Dailv Averaae Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubina Pressure Prior to well operation: Subsequent to operation: 14. Attachments: D Copies of Logs and Surveys run 15. Well Class after proposed work: a Daily Report of Well Operations D Exploratory a Development D Service a Well Schematic Diagram 16. Well Status after proposed work: a Oil DGas DWAG DGINJ DWINJ D WDSPL 17. I hereby certify that the foregoing IS true ana correct to tne Dest or my knowledge. I Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 Printed Name Sondra Stewman , Title Technical Assistant ~atur~ .....- IJ . 58 Prepared By NameINumber: /0,., -J ["', ¡ I'''. ¡ I. I It ¡hOne 564-4750 Date -()2-() Sondra Stewman, 564-4750 Form 10-404 Revised 04/2004 - . t'·¡ t ¡ \! r\ L Submit Original Only Alaskl Oil & Ga$ Cons. Commission Tree: 2 9/16" - SM CIW Wellhead: 11" SM FMC Gen SA wI 27/S" FMC Tubing Hanger, EUE lift threads, 2.S" CIW H BPV profile 20",91.1#, NT-SO, WELD 112' KOP @ 1100' MAX HOLE :Angle 53.82° @ 9644' 9 S/S" , 40#/ft, L-SO Btrc. 4296' I 2718" 6.S ppf, L-SO, S rd EUE tbg.. ( drift 10 = 2.347", cap. = 0.00S92 bpf Stimulation Summary Perforation Summary Ref loa: 07/08/96 CCL I GR SIZE SPF INTERVAL (TVO) C -Sands 4.5" 5 9,848' - 9,908' 7,016'·7,051' 2-7í8" 5 9,848' . 9,86B' Plug in XN nip Ie B -Sands 4.S" S 9,946' - 9,964' 7,074'-7,OSS' PBTO 10110' 7" 26#, L-SO, Mod. BTRS 10192' DATE REV. BY COMMENTS Drilled and cased well Nabors 27-E Completion Nabors 4-ES OS/20/98 ESP Change add screen 5/14/96 M.Linder 8/09/96 M.Linder ESP Change out 5 11/08/97 / MPU K-02 / ~~~~~~~~%~....~~....~ / ~~~~~~~~~~~~~~~ 11/08/02 11/03/5 M.Linder Lee Hulme 05/t 2101 B. Hasøbe 06f03/02 MDO ORIG.'" ELEV = 61' (N 27-E) ORIG. GL. ELEV = 33' (N 27-E) Camco 2 7í8" x 1" side pocket KBMM GLM 137' Screens perforated. Watch for sand productionl Carbine coated pump stages to handle flower sand production. Cameo 2 7/8" x 1" sidepocket KBMM GLM 9515' 2-7/S" HES XN nipple 2.2S0" minium 10 Tandem Pump, 74GC3500 & 82GC3500 GPMTAR 513 Series 1:1 CTD Carbide I coated pump stages I Pump TVD . Gas Separator GRSFTX AR H6 I Tandem Seal Section I GSB3DB UT/L T AB/HSN PFSA/FSA CL5 9651' 9665' 6906' 9695' 9700' 304 HP, 2290 Volt, 81 Amp KMHG Motor PumpMate wi 6 fin Centralizer 9740' 9714' PumpMate TVD 6951' 7" HES versatrieve packer 9S29' Note: Perf holes through screens 4.S" N-SO, 20/40 Ga. Pall well screens 4.S" HES XN nipple I 9919' 3.S13" 10 wi 3.75" no go 7" HES 'BWO' sump packer 9932' Collet shoulder 9936' MILNE POINT UNIT WELL MPU K-02 API NO: 50-029-22675 BP EXPLORATION (AK) e Page 10f 2 BP EXPLORATION Operations Summary Report Legal Well Name: MPK-02 Common Well Name: MPK-02 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Date..! From - :0 : H~~rs Task Code NPT· Phase 00:00 - 00:00 24.00 MOB P 00:00 - 06:00 6.00 MOB P 06:00 - 07:30 1.50 RIGU P 07:30 - 09:00 1.50 RIGU P 09:00 - 11 :00 2.00 RIGU P 11 :00 - 14:00 3.00 RIGU P 14:00 - 15:00 1.00 RIGU P 15:00 - 18:00 3.00 KILL P 18:00 - 19:00 1.00 WHSUR P 19:00 - 20:00 1.00 WHSUR P 20:00 - 00:00 4.00 BOPSU P 00:00 - 01 :00 1.00 BOPSU P 01 :00 - 10:30 9.50 BOPSU P 10:30 - 11 :30 1.00 WHSUR P 11 :30 - 15:00 3.50 WHSUR P 15:00 - 18:00 3.00 WHSUR N 18:00 - 19:00 1.00 WHSUR N 10/31/2005 11/1/2005 11/2/2005 19:00 - 19:30 0.50 PULL P 19:30 - 21 :00 1.50 PULL P 21 :00 - 21 :30 0.50 PULL P 21 :30 - 23:00 1.50 PULL P 23:00 - 23:30 0.50 PULL P 23:30 - 00:00 0.50 PULL P 11/3/2005 00:00 - 03:00 3.00 PULL P 03:00 - 04:00 1.00 PULL P 04:00 - 06:00 2.00 PULL P 06:00 - 06:30 0.50 PULL P 06:30 - 07:30 1.00 PULL P 07:30 - 09:30 2.00 RUNCO 09:30 - 15:00 5.50 RUNCO 15:00 - 18:30 3.50 18:30 - 19:30 1.00 19:30 - 20:00 0.50 20:00 - 21 :30 1.50 PRE PRE PRE PRE PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP SFAL DECOMP SFAL DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP RUNCMP Start: 10/31/2005 Rig Release: 11/4/2005 Rig Number: 4ES I Spud Date: 5/2/1996 End: 11/4/2005 Description of Operations Move Rig and Equipment from Nabors Yard towards Milne Point Unit. Continue to Move Rig to MPK-02 Set BOPE into sub. Spot in rig over MPK-02. Raise & scope up derrick. Spot in & R/U pits. Accepted rig @ 1100 hrs. P/U lubricator & pull BPV. LId lubricator. R/U tiger tank. R/U lines to tiger tank & tree. Wait on communications. Cut in fiber optic cable down by Fairbanks. Safety Stand-Down at MPU request. Open well. tbg = 900 psi. Csg = 1,100 psi. Bleed gas. Bullhead Kill Well. Pumped 5.3 BPM @ 100 psi. Set TWC. Blow down lines. NíD HCR valve & tree. N/U DSA & test spool. N/U BOPE. Finish N/U BOPE & scffolding. N/U IA valve.. Pressure test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. BOP test witnessing waived by Jeff Jones WI AOGCC. Pull plug. RID test equip. Drain stack. Wait on Lasso-Apso. P/U lubricator & attempt to pull TWC. No Joy. LID lubricator. P/U 7' Pulling rod extension for lubricator & 7" Otis X-Over. Attempt to pull TWC. No-Joy. Piin in rod extension came out. top of Extention Rod in inside Flow-Nipple. Remove flow nipple. Insure plug is fully engauged. Pull Rod & retreiving tool. Inspect same. Re-pin rod & P/U lubricator. RIH & pull TWC. LID lubricator. Pump 50 bbls down tubing & 50 bbls down annulus. Monitor well. BOLDS. M/U landing jt into hanger. Pull hanger to tloor. P/U wt = 80 K. LID hanger, landing jt & 10' pup. Test ESP cable. Pull cable over sheave & attach to spooler. POOH wI ESP completion & stand back 2 7/8" tubing. Change out reels in spooling unit. Con't to POOH wI ESP completion & stand back 2 7/8" tubing. Con't to POOH wI ESP completion & stand back 2 7í8" tubing. Had 2 bad jts of tubing. Remove clamps & guards from ESP. Test cable. Cable tested No Good. Wrap & remove spool from spooling unit. RId elephant trunk. Inspect & LID ESP. Service & lube rig. Clear & clean rig floor. P/U, M/U & service ESP. RIH wI new ESP on 2 7í8" tubing. Test cable & pump thru ESP every 2000'. Make reel to reel splice. Cut & slip 84' of drilling line. Change out line on tugger. Con't to RIH wI ESP on 2 7/8" tubing. Test cable & pump thru ESP every 2000'. M/U landing jt into hanger. Install penetrator & check ESP cable. Make upper connector splice. Plug in & test cable & Printed: 11/7/2005 9:58:09 AM . . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date .-.. 11/3/2005 e BP EXPLORATION Operations Summary Report i Phase ! i -----..-.. RUNCMP RUNCMP 22:00 - 22:30 0.50 RUNCOrfP RUNCMP 22:30 - 00:00 1.50 BOPSUF P RUNCMP 11/4/2005 00:00 - 01 :00 1.00 WHSUR P RUNCMP 01 :00 - 01 :30 0.50 WHSUR P RUNCMP 01 :30 - 02:00 0.50 WHSUR P RUNCMP 02:00 - 03:00 1.00 WHSUR P RUNCMP 03:00 - 06:00 3.00 RIGD P POST MPK-02 MPK-02 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES From - To I Hours! Task I Code I NPT ___n_ .._.._~_... ___~_.. ..__---L--_.. 20:00 - 21 :30 1.50 RUNCOI~ 21 :30 - 22:00 0.50 RUNCOI~ Page 2 of 2 Sta rt: 1 0/31/2005 Rig Release: 11/4/2005 Rig Number: 4ES Spud Date: 5/2/1996 End: 11/4/2005 Description of Operations ...-. _.___....____. n_"·___.__..._m.. "..-----.. connector. Blow down lines. Land hanger. P/U Wt = 77K, SIO Wt = 50K. RILDS. UD landing jt. Ran 159 LaSalle Clamps, 3 Flat Guards, 6 Protectolizers. Set & test TWC. Drain BOP stack. N/D BOPE, test spool & DSA. N/U Adapter Flange & X-mas Tree. Test tree to 5000 psi, Tested good. P/U lubricator. Pull TWC. Install BPV. UD lubricator. Secure well. Clear & clean cellar. ... RELEASE RIG @ 0300 hrs... RDMO. Printed: 11/7/2005 9:58:09 AM 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 Change Out ESP 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. [] Development KBE = 61.33' [] 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 3800' NSL, 2042' WEL, SEC. 3, T12N, R11E, UM MPK-02 At top of productive interval 9. Permit Number / Approval No. 196-081 3381' NSL, 1131' WEL, SEC. 32, T13N, R11E, UM 10. APl Number At effective depth 50-029-22675-00 3439' NSL, 1168' WEL, SEC. 32, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3638' NSL, 1294' WEL, SEC. 32, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 10212 feet Plugs (measured) Plug inside of HES XN Nipple in the screen assembly at true vertical 7231 feet 9919' Effective depth: measured 9919 feet Junk (measured) true vertical 7058 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arictic set I (approx.) 112' 112' Surface 4260' 9-5/8" 779 sx PF 'E', 914 sx Class 'G' 4296' 3481' Intermediate Production 10158' 7" 400 sx Class 'G', 60 sx PF 'E' 10192' 7219' Liner RECEIVED Perforation depth: measured Open: 9848'- 9908' Below Plug: 9946'-9964' NOV 1 ~I 2002 true vertical Open: 7015' - 7051' Below Plug: 7074' -7084' /~as~a 011 & (3a~ ~on~. C.~rnmi~i0[, Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 Eue 8rd to 9748' Ane, h0raoe Packers and SSSV (type and measured depth) 7" HES Versatrieve Packer at 9829' and a 7" HES 'BWD' Sump Packer at 9932'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-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 117. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed So~ Title Technical Assistant Date [ [- ['~ -~'~ · ~'~ F~ ! ~'%!['"' i -.;~ ! Prepared ByNarne/Number: Sondra Stewrnan, 564-4750 Submit In Duplicate Form 10-404 Rev. 06/15/88 Legal Well Name: MPK-02 Common Well Name: MPK-02 Spud Date: 5/2/1996 Event Name: WORKOVER Start: 11/7/2002 End: 11/8/2002 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 11/8/2002 Rig Name: NABORS 4ES Rig Number: 4ES ~!-:; ~ ii~:.:.~i._...i_-!_~'.i::.il~ ~i ::i: _iDeSCdption of Operations 11/6/2002 06:00 - 12:00 6.00 RIGU P PRE MI/RU NABORS 4ES& SAFE OUT EQUIPMENT. 12:00 - 14:00 2.00 KILL P DECOMP RIG LUBRICATOR & PULL BPV & SPOT TANK & RU TO KILL WELL. 14:00 - 16:00 2.00 KILL P DECOMP CIRC. WELL BORE INFLUX OUT WITH 8.5 PPG. SEAWATER & MONITOR SAME. INITIAL TBG. PS1.=1260 & ANNULUS= 1550 PSI. 16:00-16:30 0.50 WHSUR P DECOMP SETTWC. 16:30 - 18:00 1.50 WHSUR P DECOMP NIPPLE DN TREE. 18:00 - 19:30 1.50 BOPSUF P DECOMP NIPPLE UP BOP 19:30 - 22:30 3.00 BOPSUF P DECOMP TEST BOP TO 250 LOW & 3500 HIGH 22:30 - 23:30 1.00 WHSUR P DECOMP RIG LUB & PULL TWC 23:30 - 00:00 0.50i PULL P DECOMP MU LANDING JT. BOLDS & PULL HANGER TO FLOOR. & TEST BELOW PENETRATOR BAD TEST. 11/7/2002 00:00 - 07:30 7.50 PULL P DECOMP PULL & LAY DN ESP COMPLETION & EVALUATE & FIND THAT GAS SEPARATOR WASHED BADLY WITH SAND TO THE EXTENT THAT ESP CABLE WAS DAMAGED TO THE EXTENT TO OCCUR A SHORT. 07:30 - 12:00 4.50 EVAL N WAIT COMP EVALUATE WHAT TYPE OF ESP COMPLETION THAT WELL NEEDS TO BE RE-PLUMBED WITH & MAKE ASSEMBLY SAME AT SHOP. 12:00 - 15:00 3.00 RUNCOI~ COMP MU ESP ASSY. & SERVICE SAME. 15:00 - 00:00 9.00 RUNCOI~ COMP RIH WITH ESP COMPLETION/ClRC THROUGH PUMP EVERY 2000' TO SE'I-rING DEPTH @ 9745' 11/8/2002 00:00 - 02:30 2.50 RUNCOI~ COMP MU HANGER & MAKE EFT CONNECTOR SPLICE & LAND HANGER & RILDS. & TEST HANGER. 02:30 - 03:30 1.00 BOPSUF 3 COMP SET TVVC & TEST & NIPPLE DN BOP'S 03:30 - 04:30 1.00 WHSUR = COMP NIPPLE UP TREE & TEST TO 5000 PSI. 04:30 - 06:00 1.50 WHSUR ~ COMP PULL TWC & SET BPV & SECURE TREE AREA Pdnted: 11112/2002 10:41:37 AM 1. Operations performed: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS I-i Operation Shutdown i"! Stimulate r-! Plugging !-! Perforate I~! Pull Tubing r'l Alter Casing I~ Repair Well !~! Other 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3800' NSL, 2042' WEL, SEC. 3, T12N, R11E, UM At top of productive interval 3381' NSL, 1131' WEL, SEC. 32, T13N, R11E, UM At effective depth 3439' NSL, 1168' WEL, SEC. 32, T13N, R11E, UM At total depth 3638' NSL, 1294' WEL, SEC. 32, T13N, R11E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Size 10212 feet 7231 feet 9919 feet 7058 feet Length Casing Structural Conductor Surface Intermediate Production Liner Change Out ESP 5. Type of well: !~ Development r"l Exploratory I'"1 Stratigraphic I'-I Service 6. Datum Elevation (DF or KB) KBE = 61.33' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-02 9. Permit Number / Approval No. 196-081 10. APl Number 50- 029-22675-00 11 Field and Pool Milne Point Unit/Kuparuk River Sands Plugs (measured) Junk (measured) Plug inside of HES XN Nipple in the screen assembly at 9919' Cemented MD TVD 80' 20" 250 sx Arictic set I (approx.) 112' 112' 4260' 9-5/8" 779 sx PF 'E', 914 sx Class 'G' 4296' 3481' 10158' 7" 400 sx Class 'G', 60 sx PF 'E' 10192' 7219' RECEIVED Perforation depth: measured 9848'- 9908', 9946'- 9964' true vertical 7015' - 7051', 7074'-7084' Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 Eue 8rd to 9742' Gas Cor~s, uor~-~r~ss~or, Aochorage Packers and SSSV (type and measured depth) 7" HES Versatrieve Packer at 9829' and a 7" HES 'BWD' Sump Packer at 9932'. 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation: Subsequent to operation: 15. Attachments r"l copies of Logs and Surveys run Btl Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure I 16. Status of well classifications as: ~ Oil r"! Gas r-! Suspended Service 17. ! hereby certify that the fg.~,going is truce and correct to the best of my knowledge Si§ned So~~~~:.L_...~~itle TechnicalAssistant Date ..... ~;¢-~.:'.~ ~~~~~/~, ~ PreparedByName/Number: SondraStewman, 564-4750 ~ ~] ~' '/ ~ ,~ Submit In Duplicate"' Form 10-404 Rev. 06/15/88 ~ ),: ::~ ~ %~ , ? ~¢:-.~-~ .~; Legal Well Name: MPK-02 Common Well Name: MPK-02 Spud Date: 5/211996 Event Name: WORKOVER Start: 5/24/2002 End: 6/312002 Contractor Name: NABORS Rig Release: 6/3t2002 Rig Name: NABORS 4ES Rig Number: 6/1/2002 18:00 - 00:00 6.00 RIGU P PRE MI/RU 6/2/2002 00:00 - 02:00 2.00 RIGU P PRE RIG UP & SAFE OUT EQUIPMENT. AND ACCEPT RIG @ 0200 HRS. 6/2/2002 02:00- 03:30 1.50 KILL P DECOMP RIG HCR VALVE & OFFLOAD SEAWATER 03:30- 04:00 0.50 KILL P DECOMP RIG LUB & PULL BPV 04:00 - 04:30 0.50 KILL P DECOMP FINISH RIGGING LINES & TEST TO 3000 PSI. TBG. PS1=1560# ANN=2030 # 04:30 - 09:30 5.00 KILL P DECOMP KILL WELL TO 8.9 PPG. FLUID 09:30- 10:00 0.50 KILL P DECOMP SET TWC & TEST. 10:00 - 11:00 1.00 WHSUR P DECOMP NIPPLE DN TREE 11'00 - 12:30 1.50 BOPSUF; P DECOMP NIPPLE UP BOP 12:30 - 13:30 1.00 BOPSUF; P DECOMP TEST BOP TO 250 LOW & 3500 HIGH TEST WAIVED BY LEW GRIMALDI WITH AOGC. 13'30 - 14:00 0.50 BOPSUR P DECOMP PULL TWC 14'00 - 14:30 0.50 PULL P DECOMP MU LANDING JT. & BOLDS & PULL HANGER TO FLOOR & LAYDN. 14:30 - 16:00 1.50 PULL P DECOMP POOH WITH ESP COMP TO 2500' (CABLE SPLICE) 16:00 - 17:00 1.00 PULL P DECOMP CUT ESP SPLICE OUT & TEST DN HOLE AND TEST WERE GOOD) BAD SPLICE) 17:00 - 2t:30 4.50 PULL P DECOMP POOH WITH ESP COMP TO ESP ASSY. 21:30- 00:00 2.50 PULL P DECOMP LAY DN ESP & CIO SPOOLS 6/3/2002 00:00- 02:00 2.00 RUNCOI~ !:) COMP MU ESP ASSY. (GAS SEPARATOR WOULD NOT FLG. UP) 02:00- 04:00 2.00 RUNCOI~F' COMP CHANGE OUT GAS SEPARATOR. 04:00- 04:30 0.50 RUNCOr~tP COMP PLUG IN & TEST & INSTALL GUARDS ON ESP ASSY. 04:30- 10:00 5.50 RUNCOI~ COMP RIH WITH ESP COMPLETION TO 7520' 10:00- 12:30 2.50 RUNCOI~ COMP MAKE SPLICE IN ESP CABLE 12:30- 13:30 1.00 RUNCOI~ COMP RIH WITH ESP COMPLETION TO SETTING DEPTH @9742' 13:30- 15:00 1.50 RUNCOr~ COMP MAKE UP HANGER & MAKE EFT CONNECTOR SPLICE & ATTACH TO PENETRATOR & TEST SAME. 15:00- 15:30 0.50 RUNCOI~ COMP LAND TBG. HANGER & RILDS & TEST 15:30- 16:30 1.00 BOPSUR = COMP SET TWC & NIPPLE DN BOP 16:30 - 17:30 1.00 WHSUR = COMP NIPPLE UP TREE & TEST TO 5000 PSI. 17:30- 18:00 0.50 WHSUR P COMP RIG LUB & PULL TWC & SET BPV & SECURE WELL (RIG RELEASED @ 1800 HRS. 6/3/2002 Printed: 6/10/2002 9:26:36 AM STATE OF ALASKA ALASKA ,.,.L AND GAS CONSERVATION COMrv.,,.,$1ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] RepairWell [] Other 2. Name of Operator 5. Type of well: 6. Datum Elevation (DF or KB) BP Exploration (Alaska) Inc. ]~ Development KBE = 61.33' E]'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 3800' NSL, 2042' WEL, SEC. 3, T12N, R11E, UM MPK-02 9. Permit Number/ Approval No. At top of productive interval ~ 196-081 3381' NSL, 1131' WEL, SEC. 32, T13N, R11 E, UM 10. APl Number At effective depth 50-029-22675-00 3569' NSL, 1249' WEL, SEC. 32, T13N, R11E, UM 11. Field and Pool At total depth Milne Point Unit / Kuparuk River 3638' NSL, 1294' WEL, SEC. 32, T13N, R11E, UM Sands 12. Present well condition summary Total depth: measured 10212 feet Plugs (measured) true vertical 7231 feet Effective depth: measured 10110 feet Junk (measured) true vertical 7171 feet Casing Length Size Cemented MD TVD Structural Conductor 80' 20" 250 sx Arictic set 1 (approx.) 112' 112' Surface 4260' 9-5/8" 779 sx PF 'E', 914 sx Class 'G' 4296' 3481' Intermediate Production 10158' 7" 400 sx Class 'G', 60 sx PF 'E' 10192' 7219' Liner Perforation depth: measured 9848' - 9908', 9946' - 9964' R E C E IV true vertical 7015' - 7051', 7074' -7084' JUN 1 Tubing (size, grade, and measured depth) 2-7/8", 6.5#, L-80 Eue 8rd to 9736' Alaska Oil & Gas Cons. Commission Packers and SSSV (type and measured depth) None Anchorage 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe prOduction or Injection 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 [] Daily Report of Well Operations [] Oil [] Gas [] Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed s ., . Title Technical Assistant Date (,_'-)LO- · . Prepared By Name/Number: Sondra Stewman, 564-4750 Form 10-404 Rev. 06/15/88 NR t 1 Submit In Duplicate~.~ operations SUmmary Report Legal Well Name: MPK-02 Common Well Name: MPK-02 Spud Date: 5/2/1996 Event Name: WORKOVER Start: 5/7/2001 End: 5/11/2001 Contractor Name: NABORS Rig Release: 5/11/2001 Rig Name: NABORS 4ES Rig Number: ~:~:~t;~::iDate~:: ~: ~::;' :Fro~iTO~,:;: ;:::~: ;::: H~U;s~;~: ACtiVity COde ~NpTi, Phase [ Description of Operations 5/9/2001 00:00 - 01:00 1.00 MOB P PRE MORU. RAISE & SCOPE DERRICK. 01:00 - 02:30 1.50 MOB P PRE SPOT & BERM TIGER TANK. RIG UP LINES TO TIGER ITANK. ACCEPTED RIG @ 0100 HRS, 5-9-01. 02:30 - 03:30 1.00 WHSUR P DECOMP R/U LUBRICATOR & PULL BPV. TEST HARD LINES TO TREE. 03:30 - 06:00 2.50 KILL P DECOMP SITP 900 PSI, SICP 900 PSI. OPEN WELL & KILL WELL WI 8.4 PPG SEAWATER. 4 BPM 1100 PSI. PUMPED 375 BBLS. 06:00 - 07:00 1.00 KILL P DECOMP MONITOR WELL, WELL DEAD. INSTALL TWC VALVE & TEST TO 3500 PSI, OK. 07:00 - 08:30 1.50 WHSUR P DECOMP N/D X-MAS TREE. VERIFY HANGER THREADS. 08:30 - 12:30 4.00 BOPSUF P DECOMP N/U BOPE. CHANGE RAMS. M/U TEST EQUIP. 12:30 - 15:30 3.00 BOPSUF P DECOMP PRESSURE TEST BOPE. LP 250 PSI, HP 3500 PSI, TEST OK. TEST WITNESSING WAIVED BY CHUCK SHEVE WI AOGCC. 15:30 - 16:00 0.50 BOPSUF.P DECOMP R/D TEST EQUIP & CLEAR FLOOR. 16:00 - 18:30 2.50 WHSUR 3 DECOMP W/O LUBRICATOR. R/U & PULL TWC. WELL DEAD. 18:30 - 19:30 1.00 PULL 3 DECOMP M/U LANDING JT. BOLDS. PULL HANGER. P/U WT 95K MAX. 19:30 - 20:30 1.00 PULL ~ DECOMP L/D HANGER. MONITOR WELL. FILLED WI 25 BBLS. LOSSES 7 BPH. 20:30 - 22:30 2.00 PULL ~ DECOMP PULL OUT OF HOLE W/2 7/8" COMPLETION STRING. 22:30 - 23:00 0.50 PULL ~ DECOMP CUT SPLICE ON CABLE & CHANGE OUT CABLE SPOOL. 23:00 - 00:00 1.00 PULL ~ DECOMP CON-T PULL OUT OF HOLE W/2 7/8" COMPLETION STRING. (6500') 5/10/2001 00:00 - 06:00 6.00 PULL :) DECOMP POOH W/2 7/8" COMPLETION STRING. 06:00 - 08:00 2.00 PULL P DECOMP INSPECT & L/D ESP. CLEAR FLOOR. 08:00 - 13:00 5.00 PERF P COMP R/U E-LINE EQUIP. RIH TO PBTD @ 9889'. 13:00 - 16:00 3.00 PERF P COMP RIH W/2 7/8" PERF GUN W/3.5" ROLLERS. PERF 9848-9868' 6 SPF, 60 DEGREE PHASING (20'). 16:00 - 17:00 1.00 PERF P COMP R/D E-LINE EQUIP. 17:00 - 19:00 2.00~ RUNCO~ P COMP R/U TO RUN COMPLETION. M/U & SERVICE ESP. 19:00 - 19:30 0.50 RUNCO~ COMP PULL MLE OVER SHEAVE. PLUG IN CABLE & TEST CONNECTION. 19:30 - 00:00 4.50 RUNCO~ COMP RIH W/2 7/8" COMPLETION STRING. 5/11/2001 00:00 - 00:30 0.50 RUNCOI~~ COMP RIH W/2 7/8" COMPLETION STRING TO 7400' 00:30 - 03:30 3.00 RUNCOI~= COMP CHANGE OUT CABLE SPOOLS. MAKE REEL TO REEL SPLICE. 03:30 - 04:30 1.00 RUNCOI~I° COMP CON'T RIH W/2 7/8" COMPLETION STRING. BOTTOM OF STRING @ 9736'. 04:30 - 05:00 0.50 RUNCOI~ COMP M/U LANDING JOINT & INSTALL PENETRATOR. 05:00 - 06:30 1.50 RUNCOr~ COMP ATTACH FIELD CONNNECTION & TEST SAME. 06:30 - 07:00 0.50 RUNCOI~ COMP LAND TBG STRING.. RILDS. P/U WT 82K, S/O WT 43K. LAY RI DOWN LANDING JT. 07:00 - 07:30 0.50 WHSU P COMP NSTALL TWC & TEST TO 3500 PSI. 07:30 - 09:00 1.50 BOPSUR P COMP N/D BOPE. 09:00 - 10:30 1.50 WHSUR P COMP N/U X-MAS TREE. TEST HANGER VOID & TREE TO 5000 PSI, OK. 10:30 - 12:00 1.50 WHSUR P COMP PULL TWC & INSTALL BPV. SECURE WELL & CLEAN CELLAR. RIG RELEASED @ 1200 HRS, 11-5-01. Printed: 5/24/2001 2:44:05 PM oN OR BEFORE W C:LORlk,'~I;LM.DO C PERMIT AOGCC Individual Well Geological Materials Inventory DATA T DATA PLUS 96-081 GR/CCL ~L~35-10100 96-081 GR/CCL-PERF ~-9750-10050 96- 081 CR/CCL-SET 45~9700-9825 96-081 STAT PRES SURV ~9700-10050 96-081 7375 R/CCL 96-081 CDR-MD ~4300-10150 96-081 CDR-TVD ~3490-7190 96-081 CDN-.~ ~ ~/4300-10090 96-081 CDN-TVD ~L~3500-7160 96-081 7446 ~/4233-10212 CDR/CND 96-081 7497 ~T/GR/CCL Page: 1 Date: 07/21/98 RUN RECVD 1 07/26/96 1 08/12/96 1 08/12/96 1 08/12/96 1 08/12/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 FINAL 09/05/96 1 09/05/96 1 10/16/96 10-407 DAILY WELL OPS COMPLETION DATE _/~/ ?/ / / ~/ TO --~/~/c~// Are dry ditch samples required? yes ~ And received? ye~ no~ ...... Was the well cored? yes ~_~Analysis & description received? ye~___~_o Are well tests required? yes ~ Received? ~ no -~ Initial COMMENTS STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION CdMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: E~Operation Shutdown F-IStimulate []Plugging []-]Perforate [~;~Pull Tubing F--IAIter Casing [~ Repair Well [~Other 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 4. Location of well at surface 3800' NSL, 2042' WEL, Sec. 3, T12N, R11E, UM At top of productive interval 3381' NSL, 649' WEL, Sec. 32, T13N, R11 E, UM At effective depth 3570' NSL, 727' WEL, Sec. 32, T13N, R11 E, UM At total depth 3625' NSL, 763' WEL, Sec. 32, T13N, R11 E, UM ESP Exchange 6. Datum Elevation (DF or KBE) KBE = 65' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-02 9. Permit Number / Approval No. 96-81 10. APl Number 50- 029-22675 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 10192' feet true vertical 7219' feet Effective depth: measured 10110' feet true vertical 7171' feet Casing Length Size Structural Conductor 80' 20" Surface 4260' 9 5/8" Intermediate Production 10158' 7" Liner Plugs (measured) Junk (measured) Plug in XN nipple at 9919' Cemented 250 sx Arcticset I (approx) 779 sx PF 'E', 914 sx Class 'G' 400 sx Class 'G', 60 sx PF 'E' MD TVD 110' 110' 4296' 3482' 10192' 7219' Perforation depth: measured 9848'-9908', 9946'-9964' true vertical 7015'-7051 ', 7074'-7084' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9656' ORIGINAL Packers and SSV (type and measured depth) 7" HES versatrieve packer at 9829' and 7" HES 'BWD' sump packer at 9932' 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 Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attach ments [] 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 isc~r~t, and correct to the best of my knowledge ... Signed ~ Prepared By Name/Number: Submit In Duplicate~l:~ Form 10-404 Rev. 06/15/88 Progress Report Facility M Pt K Pad Well MPK-02 Page 1 Rig Nabors5S Date 21 May 98 Date/Time 08 May 98 06:00-10:30 10:30-12:30 12:30-13:30 13:30-14:30 14:30-18:00 18:00-22:00 22:00-22:30 22:30-23:30 23:30-00:30 09 May 98 00:30-03:00 03:00-04:00 04:00-04:30 04:30-06:00 06:00-08:30 08:30-10:00 10:00-18:00 18:00-19:30 19:30-20:30 20:30-21:30 21:30-01:00 10 May 98 01:00-04:30 04:30-05:00 05:00-06:00 06:00-10:00 10:00-14:30 14:30-18:00 18:00-20:30 20:30-23:15 23:15-02:30 11 May 98 02:30-04:00 04:00-05:00 05:00-06:00 06:00-11:30 11:30-13:30 13:30-15:30 15:30-18:00 18:00-20:00 20:00-22:30 22:30-01:30 12 May 98 01:30-06:00 06:00-09:00 09:00-17:00 17:00-18:00 18:00-20:30 20:30-01:30 13 May 98 01:30-03:30 03:30-05:00 05:00-06:00 06:00-06:15 06:15-07:30 07:30-09:30 09:30-12:00 12:00-14:30 Duration 4-1/2 hr 2hr lhr lhr 3-1/2 hr 4hr 1/2 hr lhr lhr 2-1/2 hr lhr 1/2hr 1-1/2 hr 2-1/2 hr 1-1/2 hr 8hr 1-1/2 hr lhr lhr 3-1/2 hr 3-1/2 hr 1/2 hr lhr 4hr 4-1/2 hr 3-1/2 hr 2-1/2 hr 2-3/4 hr 3-1/4 hr 1-1/2 hr lhr lhr 5-1/2 hr 2hr 2hr 2-1/2 hr 2hr 2-1/2 hr 3hr 4-1/2 hr 3hr 8hr lhr 2-1/2 hr 5hr 2hr 1-1/2 hr lhr 1/4 hr 1-1/4 hr 2hr 2-1/2 hr 2-1/2 hr Activity Rig moved 100.00 % Rig moved 100.00 % Held safety meeting Removed Hanger plug Circulated at 9653.0 ft Circulated at 9653.0 ft Installed Hanger plug Rigged down Xmas tree Rigged up All rams Tested All rams Removed Hanger plug Removed Tubing hanger Pulled Tubing in stands to 150.0 ft Circulated at 9538.8 ft Circulated at 9538.8 ft Pulled Tubing in stands to 7928.8 ft Pulled Tubing in stands to 9695.8 ft Laid down 0.0 ft of Tubing Conducted slickline operations on Slickline equipment - Tool run Conducted slickline operations on Slickline equipment - Tool run Ran Tubing in stands to 9528.8 ft Ran Tubing to 9873.8 ft (2-7/8in OD) Reverse circulated at 9873.8 ft Reverse circulated at 10090.8 ft Pulled Tubing in stands to 10090.8 ft Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Serviced Block line Ran Tubing to -21.2 ft (2-7/8in OD) Ran Tubing in stands to 978.8 ft Ran Tubing to 9909.8 ft (2-7/8in OD) Ran Tubing to 9909.8 ft (2-7/8in OD) Circulated at 9778.8 ft Pulled Tubing in stands to 9807.8 ft Pulled Tubing in stands to -21.2 ft Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Conducted slickline operations on Slickline equipment - Setting run Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 0.0 ft Ran Tubing in stands to 7940.0 ft Ran Tubing in stands to 7940.0 ft Ran Tubing in stands to 9685.0 ft Ran Tubing in stands to 9685.0 ft Held safety meeting Installed ESP Rigged down All rams Installed Xmas tree Displace treatment STATE OF ALASKA ALASK/-~ 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 Exchange 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 3800' NSL, 2042' WEL, Sec. 3, T12N, R11 E, UM At top of productive interval 3381' NSL, 649' WEL, Sec. 32, T13N, R11 E, UM At effective depth 3570' NSL, 727' WEL, Sec. 32, T13N, R11 E, UM At total depth 3625' NSL, 763' WEL, Sec. 32, T13N, R11 E, UM 5. Type of well: [] Development [] Exploratory [] Stratigraphic [] Service 6. Datum Elevation (DF or KBE) KBE: 65' 7. Unit or Property Name Milne Point Unit 8. Well Number MPK-02 9. Permit Number / Approval No. 96-81 10. APl Number 50- 029-22675 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 10192' feet true vertical 7219' feet Effective depth: measured 10110' feet true vertical 7171' feet Casing Length Size Structural Conductor 80' 20" Surface 4260' 9 5/8" Intermediate Production 10158' 7" Liner Plugs (measured) Junk (measured) Cemented 250 sx Arcticset I (approx) 779 sx PF 'E', 914 sx Class 'G' 400 sx Class 'G', 60 sx PF 'E' MD TVD 110' 110' 4296' 3482' 10192' 7219' Perforation depth: measured 9848'-9908', 9946'-9964' true vertical 7015'-7051',7074'-7084' Tubing (size, grade, and measured depth) 2 7/8" 6.5# L-80 to 9717' Packers and SSV (type and measured depth) None ORIGINAl_ 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 1998 Alaska Oil & Gas Cons. Oommis~km 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or In!ection Data Oil-Bbl Gas-Mcr 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 ,/~4,¢,,¢.- ~ ~ Title Engineering Supervisor Date / Prepared By Name/Number: Mary Youngers 564-5242 Form 10-404 Rev. 06/15/88 Submit In Dupliq~ Facility M Pt K Pad Progress Report Well MPK-02 Page 1 Rig Nabors 5S Date 13 February 98 Date/Time 30 Oct 97 31 Oct 97 01 Nov 97 02 Nov 97 03 Nov 97 04 Nov 97 11:00 14:30 15:30 16:30 18:00 19:00 20:30 21:00 00:00 01:30 02:30 03:30 04:30 05:30 06:00 08:30 11:00 13:00 13:30 14:00 14:30 18:00 20:00 00:00 02:30 03:00 06:00 08:00 09:00 12:00 13:00 14:00 14:30 02:30 03:00 03:30 06:00 07:00 15:00 17:30 18:00 22:00 22:30 23:00 23:30 06:00 07:00 08:00 08:30 14:30 15:30 16:30 20:00 05:00 Duration Activity At well location - Slot Completed operations Equipment work completed Completed operations Equipment work completed Resumed operations String displaced with Seawater - 100.00 % displaced Observed well static String displaced with Seawater - 200.00 % displaced Completed operations Hole displaced with Seawater - 110.00 % displaced 10.000 bbl LCM pill spotted downhole, LCM content 10.0 lb/bbl Completed operations Completed operations Equipment work completed Obtained clean returns - 120.00 % hole volume 20.000 bbl LCM pill spotted downhole, LCM content 15.0 lb/bbl Hole displaced with Seawater- 100.00 % displaced Equipment work completed Pressure test completed successfully - 5000.000 psi Equipment work completed Equipment work completed Aborted equipment work Equipment work completed Equipment work completed Obtained req. fluid properties - 1.00 %, hole vol. Function test completed satisfactorily Equipment work completed Equipment work completed Completed operations Broke circulation Completed operations Completed operations Stopped: To change handling equipment Equipment work completed Completed operations Retrieved 60.0 ft from Other sub-surface equipment Operation stopped due to Incident Resumed operations Equipment work completed Completed run with Slickline / braided cable from 0.0 ft to 9901.0 ft Completed run with Bailer from 9901.0 ft to 9904.0 ft Equipment work completed Work completed - Tubing handling equipment in position Completed operations Stopped: To hold safety meeting At Top of perforations: 9900.0 ft Stopped: To circulate Stopped: To circulate Stopped: To service drilling equipment Equipment work completed Completed operations Hole displaced with Seawater - 110.00 % displaced Completed operations Facility M Pt K Pad Progress Report Well MPK-02 Rig Nabors 5S Page Date 2 13 February 98 Date/Time 05 Nov 97 06 Nov 97 06:00 11:00 12:30 21:30 00:00 02:00 02:30 05:30 06:00 07:00 09:30 12:00 17:00 20:00 06:00 Duration Activity Stopped: To hold safety meeting Equipment work completed Equipment work completed Stopped: To splice cable Equipment work completed Com,leted Eqmpment Eqmpment Eqmpment Eqmpment Eqmpment Eqm >ment Completed run with ESP to 9657.0 ft work completed work completed work completed work completed work completed work completed operations Equipment work completed Rig off station STATE OF ALASKA ~ ' ALASK~ OIL AND GAS CONSERVATION CU~ViMISSION 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. 96-81 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22675 4. Location of well at surface 9. Unit or Lease Name __ 3800' NSL, 2042' WEL, SEC. 3, T12N, R11E ":' :..:.¥ :: "~.. _.:~"~ :~ :-~ ~.f#~. Milne Point Unit Attop of productive interval ~ ¢"/~'/¢~' ~, 10. Well Number 3381' NSL, 1131' WEL, SEC. 32, T13N, R11E ....... ~ MPK-02 At total depth ~' '"";':'~: "~: ' I 11 Field and Pool 3638' NSL, 1294' WEL, SEC. 32, T13N, Rll Ei _. _'".~L~;_ _ .- . ' Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. I-ea~e'Designation and Serial No. Sands KBE = 65.3'I ADL 028231 12. Date Spudded05/02/96 I 13' Date T'D' Reached I 14' Date C°mp" Susp" °r Abandl15' Water depth' if OffshOre I 16' NO' Of COmpletiOns05/10/96 08/07/96 N/A MSLI, One 17. Total Depth (MD+TVD)118. Plug Back Depth (MD+TVD)I19. Directional Survey 20. Depth where SSSV set~l. Thickness of Permafrost 10212 7231 F~ 10110 7171 F~ []Yes []No N/A MD! 1800' (Approx.) 2'2. Type Electric or Other Logs Run MWD, LWD, Gyro, GR/CCL, GR/RES, CDN ~'~. CASING, LINER AND CEMENTING RECORD ., CASING SE'FI'lNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP Bo'FrOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1 # NT80LHE 38' 1 10' 30" 250 SX Arcticset I (Approx.) 9-5/8" 40# L-80 36' 4296' 12-1/4" 779 sx PF 'E', 914 sx Class 'G' ........ 7" 26# L-80 34' 10192' 8-1/2" 400 sx Class 'G', 60 sx PF 'E' 2;4. 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) 4-1/2" Gun Diameter, 5 spf 2-7/8", 6.5#, L-80 9758' N/A MD TVD MD TVD 9848'-9908' 7015'-7051' 9946'-9964' 7074'-7084' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED ORIGINAL 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) August 10, 1996 ] Electric Submersible Pump ...... Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD · I ¢'i'0w Tubing!Casing Pressure CALCULATED· OIL-BBL GAS-MCF WATER-DeL 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. Submit core chips. JAN 0 ~ 1997 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. 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. (Subsea) Top KC1 9833' 6945' Top Kuparuk 'B' 9911' 6992' Top Kuparuk B7 9945' 7012' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I hereby certify that the foregoing is t~'ue and~cclrrect to the best of my knowledge Signed 7~,f'q ~')J~~ Title Senior Drilling Engineer Date I 1, Tim Schofield ~_ / Prepared By Name/Number: Kathy Campoamor, 564-5122 iNSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 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 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: M PK-02 Rig Name: N-27E AFE: 337030 Accept Date: 05/01/96 Spud Date: 05/02/96 Release Date: 05/1 3/96 May I 1996 (1) Rig moved 35 %. May 2 1996 (2) Rig moved 100 %. Nabors rig #27E accepted 05/01/96 @ 1400 hrs. RU divertor. RU kelly. MU BHA #1. Tested divertor. Held safety meeting. Circulated at 110 ft. Drilled to 540 ft. May 3 1996 (3) Drilled to 2201 ft. Circulated at 2201 ft. POOH to 831 ft. RIH to 2201 ft. Drilled to 2545 ft. May 4 1996(4 ) Drilled to 3239 ft. Circulated at 3239 ft. POOH to 1739 ft. RIH to 3239 ft. Drilled to 4315 ft. Circulated at 4315 ft. POOH to 3250 ft. May 5 1996 (5) POOH to 830 ft. RIH to 4315 ft. Circulated at 4315 ft. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 2278 ft (9.625 in OD). Washed to 2303 ft. Ran casing to 4296 ft (9.625 in OD). Circulated at 4296 ft. Mixed and pumped slurry - 488 bbl. Displaced slurry - 318 bbl. Cleared flowline. RD cement unit. RD divertor. May 6 1996 (6) RD divertor. Installed wellhead integral components. Tested casing spool. RU BOP stack. Tested BOP stack. Installed bore protector. Serviced block line. Ran electric logs. MU BHA #2. RIH to 4211 ft. Circulated at 4211 ft. Tested casing. Drilled installed equipment - float collar. Circulated at 4325 ft. Performed formation integrity test, 12.5 ppg EMW. Drilled to 4560 ft. May 7 1996 (7) Drilled to 5300 ft. Circulated at 5300 ft. POOH to 4280 ft. RIH to 5300 ft. Drilled to 6153 ft. Circulated at 6153 ft. Drilled to 6309 ft. Circulated at 6309 ft. POOH t/5300 ft. RIH to 6309 ft. Drilled to 6600 ft. Page May 8 1996 (8) Drilled to 7064 ft. Repaired mud pumps. Drilled to 7820 ft. Circulated at 7820 ft. POOH to 6300 ft. RIH to 7820 ft. Drilled to 8203 ft. Repaired flowline. May 9 1996 (9) Drilled to 8961 ft. Repaired mud pumps. Drilled to 9330 ft. Circulated at 9330 ft. POOH to 7820 ft. RIH to 9290 ft. Reamed to 9330 ft. Drilled to 9500 ft. May 10 1996 (10) Drilled to 9581 ft. Repaired flowline. Drilled to 10155 ft. May 11 1996 (11) Drilled to 10212 ft. Circulated at 10212 ft. POOH to 4280 ft. RIH to 10169 ft. Washed to 10212 ft. Circulated at 10212 ft. LD 903 ft of 5 in OD drill pipe. Pulled BHA. RU casing handling equipment. Held safety meeting. Ran casing to 1000 ft (7 in OD). Repaired drillstring handling equipment. Ran casing to 2310 ft (7 in OD). May 12 1996 (12) Ran casing to 4294 ft (7 in OD). Circulated at 4984 ft. Ran casing to 10192 ft (7 in OD). Circulated at 10 ft. Circulated at 10192 ft. May 13 1996 (13) Circulated at 10192 ft. Circulated at 10192 ft. Mixed and pumped slurry- 146 bbl. Displaced slurry - 376 bbl. Tested casing. RD cement unit. Installed seal assembly. RD BOP stack. Installed adapter spool. Installed Xmas tree. May 14 1996 (14) Installed Xmas tree. Tested all tree valves. Installed hanger plug. Freeze protect well - 100 bbl of diesel. Nabors rig #27E released 05/13/96 @ 1500 hrs. Page 2 MILNE POINT, ALASKA TO: Hendrix/Stevens FROM: Mark O'Malley Well Name:[ MPK-02 Main Category: IDrl~l / Completion Sub Category: ~E-Line. Perf & IStatic & WLRBP Operation Date: ~ 7~28-29 /96 Date: J 7/29/96 OBJECTIVE: Perforate the Kuparuk B & C Sands, Static pressure survey, Setting WLRBP above perfs and pressure test. IlWHSIP=600 psig I IAP=0psig I OAP= 0 psig I II TIME OPERATION 7 / 28 /96 18:00 Held pre job safety meeting. RU ATLAS tested surface equip to 1500 psi. tested good. All shots will be run with guardian system 4.5" / 5-SPF / ALPHA JET / 135/45° Phasing 18:30 #1 Gun run 18' Kuparuk B-Sands RIH With gun and made a tie in pass from 10,050' to 8,600' Corrected back to Marked line GR /CCL Log run 7/08/96. Dropped back down and logged into position @ 9,942' 4' from CCL to top shot. Bleed tubing down from 1500 psi to O-psi. Fired gun good indication on surface gun fired. Tubing pressure went from 0 to 600 psi. Logged off RIH and flagged the line at 10,050'. POH gun at surface all shots fired. B-Sands shot 9946' - 9,964' 20'30 #2 Gun run 20' Kuparuk C-Sands RIH With 20' gun to flag @ 10.050' corrected depth. Logged into position @ 9,996' 2' from CCL to top shot. Fired gun good indication on surface gun fired. Logged off. POH gun at surface all shots fired. C-Sands shot 9,888' - 9,908' 7 /29 00'30 #3 Gun run 20' Kuparuk C-Sands RIH With 20' gun to flag @ 10.050' corrected depth. Logged into position @ 9,866' 2' from CCL to top shot. Fired gun good indication on surface gun fired. Logged off. POH gun at surface all shots fired. C-Sands shot 9,868' - 9,888' 02'30 #4 Gun run 20' Kuparuk C-Sands RIH With 20' gun to flag @ 10.050' corrected depth. Logged into position, gun was hanging up pulling through perforated area. Spotted gun CCL @ 9,846' 2' from CCL to top shot. Fired gun good indication on surface gun fired. Logged off. POH gun at surface all shots fired. C-Sands shot 9,848' - 9,868' 05:00 RU RIH W/ Static Pressure Survey. Logged up from 10.050' to 9,700' Tied into log GR/CCL 7/08/96 Corrected back, Spotted Pressure gauge @ 9,926' MD / 7,000' TVD. .. Started survey @ 06:37 starting pressure 3571.8 and Temp 174° Ran survey for 30 min. The limited stop time was because of K-pad access restraints due to pad construction. Pressure had stabilized @ 3570.6 psi and Temp @ 174° POH. 08:00 RU RIH W/ Baker #20 setting tool and 7" WLRBP 8.5' from CCL to middle of plug. RIH and Tied into GR from 9,100' - 8,925' Corrected back. RIH Logged from 9,825' to 9,770'. A collar was located @ 9,800' md spotted WLRBP @ 9,790' md set plug POH Released radio silence. RU HB&R Pressured up above plug @ 1600 psi for 30 min. tested good. Bleed down casing ( tubing ) to O-psi Held for 15 min. RD ATLAS and HB&R Left well with O-psi. with a WLRBP @ 9,790' MD. 12'00 RESULTS: Perforated the B&C sands. 600 psi on surface. Static run. Set a WLRBP above the perfs and tested good. Bled down tubing down to O-psi. IIDiesel use: 0 Bbls MeOH use: 0 Bbls SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPK-02 Rig Name: N-4ES AFE: 337030 Accept Date: 08/05/96 Spud Date: Release Date: 08/07/96 Aug 6 1996 MIRU. Berm & trim herculite. Raise & scope derrick. Nabors rig #4ES accepted 08/05/96 @ 2000 hrs. ND tree. NU adapter flange & BOP's. Pull BPV & set test plug. Test all rams & valves. Test annular. Right to witness test waived by AOGCC inspector Chuck Sheve. RU floor to run tubing. MU RBP retrieving tool & PU 2-7/8" tubing from pipe shed. Aug 7 1996 Cont PU tubing from shed. Slip 42' of drill line. Cont PU singles. Displaced diesel & seawater f/9745' with brine. TIH with tubing. Tag & latch RBP. Released packer. CBU. Circ out gas & oil out through choke with bottoms up. Shut down & monitor well while taking on more brine. Circ 2nd bottoms up. Monitor well. LD 5 jts tubing. POOH in stands. RU to run ESP. MU & service pump. TIH with 2-7/8" ESP completion string. Aug 8 1996 Cont RIH w/ESP completion. Make splice to ESP cable #1. Cont RIH w/ESP completion. Make ESP cable splice to spool #3. Cont RIH w/ESP completion & MU hanger & landing jt. Make splice at hanger. Land tubing. RILDS. LD landing jt. Set TWC. ND BOP's. NU tree & test same. Pull TVVC & set BPV & secure tree & cellar. Nabors rig #4ES released 08/07/96 @ 2400 hrs. Note: No freeze protect because the weather was such that there was no freezing concerns and because the well was quickly placed on production. Page ANNULAR INJECTION DATA ENTRY SCREEN Asset .MiJ9¢- ........................................ Legal Desc .3~i.~Jt:b~,~L21.0D'.~EL....~ec,02,~.;l.2i~l~.l.;~£ ......................... Rig Name ~27.E. ....................................... ' .................................................................................................................... Inj Well Name .M.P.t~_-.I.7. ................................ Permit Start ............................... Permit End ............................... Sur Csg Dep ,3.5.0.8 ............. .......4.r..1.J~.=.9.~ ........... .4.r..l.,8.:.9.Z. ..... Cumulative Data : ~: i : i :Rig ;:~ ;:~'Co~pl~tibn i:::!!Fotmation :: intermittant;~ . Final Well Total : i Mud/C~,cr ~ !::: :~Wa~hI :- : · Free~e:: Freeze Daily Data Source I Date Of contaminated/ PJg Wash' COmpletion ::F6rmatiOn: Freeze Freeze Dally Annulus Well i Injection Drlg Mud | Fluids ! : Fluids I: :Fluids ;l P[otection! Protection Total Rale i Slatus Comments Complications MPK-25 03/15/96 140 140 MPK-25 03/20/96 175 225 400 MPK-25 ,03/21/96 1,273 1,273 MPK-25 I 03/22/96 300 300 MPK-25 03/23/96i 80 80 MPK-25 i 03/24/96 70 70 MPK-38 103/25/96 150 150 MPK-38 i 03/26/96 243 243 ~ .i 03/27/96 163 ~ 20 [ 183 ~~ 03/28/96 1,496 ! 1,496 ' 1 ~MPK-38 J 03/31/96 250 I 10 260 iM~-3~ ~0./0~/~ 320 ~ ~20 , ~ 04/06/96 0 I i , 0 ................. i o.~o~.. ,,o ~ ,, '' !, " o ~ I o"~o~ ~o i I i' ~o ...... IMPK-38 '04/09/96 1,373 ' i [ 1,373 ~ !04/10/06 280 [ 18 298 !MPK-38 ¢04/11/96 260 ! 20 i 280 ~ '~ 04/12/96, '490 IMPK-38 ~ 04/14/96 135 I 10 145 M.K-~. i0~/~ ~/~ ~0 I zo ~0 M.K-3~ i04/~3/9~ S0 e0I ~0 ~00 MPK-SZ i04/~4/9~ ~,~40 ~0 ~ i 04/~/~e ~00 ~0 S~0 IMPK-37 104126196 200 i 10 210 1.5 BPM ~ 700 PSI IMPK-37 i04/27/9e 7OO J 10 710 1.SBPM ~ 700PSI MPK-S~ ~04/~/~6 so ~ ~0 ~0 ~.s ePU ~ zoo ~s~ ~MPK-37 i 04/29/96 350 J 350 1.5 bpm ~ 700 PSI ~ 04130196 1,000 i 60t 1,060 3 BPM ¢ 800 PSI MPK-02 ~05104/96 350 ~ ~ 350 3 BPM ~ 800 PSI [MPK-02 i 05/05/96 950 ~ 10~ 960 70 bbls of the 950 was returned cement ~i o~o~/,. ~o I ~o i 4~o IM~K-0~ ~ 05108196, 520 j~ 10 ~ 530 .1.5 BPM ~ 700 PSI 05/09196 522 ~ 20 I 542 ~ 05/10/96 221 ~ 10 ! 231 IMPK-02 i 05/12/96 925 ~ ~ 925 lu.~-o~ O~/l~/~e ~ i ! ~oo 3BPM~ 750 PSI I i i ' PAGE NO, COMPS'fY BP WELL NA~E i~'~-02 LOCATION ! MtLNE ~AT!ON 2 ~'t~E~qSKA MAGNETIC DECLiNATiON Z7~77 GRID CONVERGENCE ANGLE 0~00 DATE: O1-MA¥-% WELL NU~ER API 50-029-22675 JOB ~ 37894 WELL ~AD LO[~TION: LA?(ti/-S) 0,00 DEP(E/-W) 0,00 AZI~J~ FRG~~ -^.v , ~. ~OmR, TABLE TO VAE~T tS TIE IN POINT(TIP) : MEASURED DEf%H 0,00 TEYE VEF~ DEF~fH 0,00 I~LINATION AZIMUTH 0~00 LATITLIDE(N/-S) 0~00 DEPARTURE(E/-W) 0~00 321,51 OA,N 0 ,~ 1997 Gas Cons. Commission ~orage ************* CiRCULaR AG~C ~F?(-02 MEAg]F~D INTERVAL VERTICAL DEP%M DP'TN ft ft ft O.t~, 0.0 0.00 i00,® 100,0 i00,00 2(E~,60 100,0 !99.99 300.00 100.0 400.00 I00.0 TARGET STATION AZ!ML~H LATITUDE SECTION O.n~ 0.00 0.00 0.00 -o.57 -i.66 0,63 ~55,06 -1.63 -2,97 0,87 145.78 -2.75 -4.46 0.84 i49,13 -4.01 DEPARTURE MSPLAC~M~NT at 0.00 0.00 O.E1 0.60 0.6.5 1,75 1.31 3.05 2,!2 4.53 AZIMU%H d~q 0.00 1..,Y,41 1%,05 154,4~. 152,i6 de-.:/ lOOft 0.00 0 0.08 (:: 27 ,. ..-)~ 500.00 tOO.O 499.96 6¢~.00 i00.0 700.00 I00.0 %0.00 lOO.O 899,9! %,99 0,93 146,43 -5,31 2,94 6,07 151,03 -9.34 i.00 '~'.~d~o -;-~?.- ......4.~.A "~.~ .... ~ 9~ -10,74 0,~3 N3,57 -?,36 5,6i ii.01 i4~.16 0.i7 -!i.92 0.31 i24.88 -t0,07 6.46 11.96 147.37 1!50 r,...', iiY/,W' 100,0 .%'9.91 50.0 1049.90 50,0 107~,87 50.0 !!49 ~n 47,0 1196,.~4 -11,37 0,9i ojo~_,, 24 -9.As._ -10,30 i.60 3!6,54 -8,64 -8,5~ 2,37 313.51 -7,62 -6,04 3,49 ~, o ~ ' -2,74 4,58 3i7,73 -3,38 6.i7 11.45 147.42 1.21 5.43 10.37 148.46 1.38 4.20 8.70 151.!7 i.55 2,40 ^,?g 157,59 ': n.~y 3.~9 177,~ 1250.00 1300.¢0 1350.00 !400.00 !450.00 53,0 1249,43 5~,0 1298,99 50,0 1348,38 50,0 1377,60 50.0 !446.56 2,40 6.57 318.0! 0,44 8.97 8.54 320,02 5,4! i6,75 9,30 320.i5 ii ~ 25.55 !0.39 320,22 i8,!4 ..... - ....... n :6,00 -3,31 3,34 ~77,50 3,76 -t=,oi ,...,,o 312,0~. t,70 -!8,24 25,73 ¢.~.~..~_ ~.o0_ . -Z4,66 35,84 316,5i 3,30 1500,00 !550,00 1600KX:, 50.0 1495.24 50.0 !543.76 so,<: !592.!8 50~0 16a}~41 50,0 1687,96 47,08 !3.79 32!.75 34.9i ~ .... 3~,4S 44,39 ~ ~:' i4~5~ 322,07 ~4 '~ M.64 ........:o.v~ :.:~,n~ 64.5! 100 ~= i9.~? ~...,. 76,44 -:*,TS 47 i9 ~1~ "i 2 · _ ~ ! ,./- -39,27 =" ...... ~¥.~/ 318,51 -46,97 71.70 319,07 ~= !8 84,89 3!9,46 2,95 -64,95 100,3i 317,64 7.7~ 1725,00 1.-"~. ~' is ...', k~: 18.25 ,;. ~.,.! .' ,r ~."".' 25,0 !711,29 50,0 !757,04 50.0 180!,86 50,0 !845,98 50,0 ,a~ =~ ~9.~: 25 -- ~20 96,85 1~ ~ ~7,30 320-~~ ,*~ .'.v i75.06 ~,~°~ n~ 320,?^. 134,!9 -70,69 109,28 319.69 '-y.~i"' -83,55 129,43 319,79 6.33 -97.~4 151.60 319.90 2..?0 -~12,51 'v= . . . !.o,12 320,02 3.0A -!27.94 199,70 320,i6 2,54 I775,B3 2025,¢~ 2075,~ 2i25,00 2i75,£0 50,0 195~,75 50,0 1975,72 50,0 20!8,09 50,0 2059,3i 50,0 2079,5! 224,76 ~),Z3 32!,83 !73,00 o~n ~o 31,26 2~1,88 !93,10 276,86 32,~8 322,09 214,02 3~,15 36,04 322,02 236,32 334,69 36,95 322,42 259,83 -143.56 ~4.81 320.31 0.63 -t59.35 250.36 320~47 2.06 -i75,70 276.90 320.62 3.25 -193,09 305,!8 320,75 6,32 -2!1.3i 334,91 320,88 !,88 2225.00 2325.04 2375.00 2425,00 50,0 2138,89 50,0 2177.73 50,0 ~116,il 5~ 2253,71 50,0 2290,80 ~55,67 39,I2 ~2,29 397,i6 :~,92 322,47 309,15 429,2! 40.8! 322,53 334.58 462.16 4i.67 327,48 360.73 4'~,68 42,54 3~2,41 387,31 -230,!2 365,70 321,00 4.34 -249,34 3'77,i7 321,11 0,46 -268,85 429,21 321,22 3,78 -288,9i 462,16 321,31 1.72 -309,35 495,68 321,39 !.74 ~URV~¥ CAlCULATiONS ************* CtRO]~AR ARC MBTHOD******** :~.00 >v.v 2327,43 ~=~v 50.0 2575.00 50,0 ~397,56 ~ :'~ 50,0 TARGET STAT![~ AZIMUTH ~TtTUDE 529,72 43,27 :3~2,48 414,29 564+69 45,5i 322.2g 441+99 600,94 47,~7 322,34 i~n ~,. 676,92 ~,09~.._ ~c~,A~.~ ._ 53i+04 DEPART~:E DISPLACEMEHT at E/-~ - ft ft -330,09 ~' 7~ = .44 564,69 -3A -373,61 600,94 -3%.44 636.43 -4t?,77 676,92 AZIMUTH 321,45 32i,51 321,56 321,67 DL$ deq/ lOOft 4,49 3,92 4,42 2,76 2725~00 2775 2525 ~00 2o~ ~.0 2493,95 50,0 ?_=.25,2! 50,0 2556~28 ~jo,,14 50.0 26i7+83 7~5,83 5i~17 ~.;~.., ~ 562,05 ._ 754~83 91.43 323.01 =o. ~ 8.33,32 52,06 ~r23+25 656,03 872,77 52~19 323,3~ ~== 0 -44a.~, 715,83 321,74 O,Sl -466,79 754,84 S21.JO 0.52 -490,~ 794,01 32!,86 0,64 -513.89 833,34 321.93 0,68 -537,47 872,80 32!,99 0.3~ 2775,00 3025,(x3 3075.00 50,0 2648,,82 =,":~ ,. o 2680:!3 50.0 50.0 2742.25 50 .,0 2774 .,34 91!,99 51,~z ~,79 719,~5 '"~"'"' ~,2~ 322,55 ~n ~, 990.15 5i,98 3~2,82 78!+22 -~.1,04 912,03 322,04 2,15 -584,67 951,01 322,06 0,38 -606,43 990,20 322,09 t,54 %32.i0 1029,37 322,!2 -655,44 D67,7! 322,13 4,56 :~979.AA 3325,CO 3425,00 50~0 2807~70 50,0 284!,7! ~ n 9A79,?0 ~V.~ ...... 50~0 ~ F' 2739+62 !i04.8-? 47,37 322,09 572,25 114!,53 46,89 :r£2,~? 90!,17 ~7A.A~ ~"' ~^ 322.05 930.45 ~/~ 90.~ ;r;'~.~7 960,48 i255~:~ 50,13 -678,31 ii04,96 322,13 -700,82 i!4!,60 322~!3 -7Z<,64 1!78,72 322,13 -747,06 1216,81 322~12 -770+6i i255.:: o~=,:o 3,16 0,96 4,22 2,44 . S~25+00 3575,00 3625,00 3675,00 50+0 297i,82 50,0 ~n~ ~= 50,0 3036,29 50,0 30&5+i0 50,0 3099.60 ,~o~ % 49;A9 ......... 102i ^"' !369+82 50,27 322,37 1081,62 !447 ot ~.~1 ?;~9,A~ 1i43+07 -793,99 1293,4A 322,.~ °'v,28 133i.60 32~,i4 -840,67 i367,90 322,i4 -864,i7 i408,48 322,15 -867,75 1447+31 322,!7 ~' .90 i:06 1,04 3725 0,-' :' .y +:7',2 3925 +O0 5~,0 31~3,M 50.0 3i6i,95 50.0 3i93,02 50,0 3224,07 50,0 ~= '~ !466,24 5~.aA ~" 80 it7~,1~ _.,. 0~£. . ~.: : '<~ ~:' ~i,~4> 323,22 122d:,,73 i603,70 5!,6i 323,5! !268,!7 io~,89 5i,65 o~n ~, - -91i+38 i486+35 322,18 -934,77 1525+48 322,20 -955,46 !564.65 322,22 -961,84 i603,~3 322,25 -i005+89 !643,03 322,25 0,51 0.2i 0,45 4,23 3975+00 50,0 3286,09 4025+00 50.0 33!6.97 EflD GYRO SURVE% 4035,24 =~+~ ~ ~3323,~8~" 4i29,~ 94,7 338t,28 <~ o, 96,? 343~+85 ~. _ 51 '~ 3!9,5! 1325,26 i72! 43 5!,94 3t9,70 1729,39 =o ~ . J~+w 319,54. 1365,35 l~j4,.,~? ..?~=~o~+44 319,95 1422,50 16&!,45 53,t6 3~0,16 148-1,65 -i031,03 !682,25 322,20 -1056+51 172t,53 322,!4 -1061,74 i729,59 322,13 -ii10,12 i804,40 322,03 -1159,65 1881,51 321,95 2,06 0.44 i,52 0.55 0,77 4256,15 29,3 4%~ 4~ -' - 4449.05 96.4 4543,20 94.2 4637,67 94,5 3457,37 1904+97 53+~ 320,67 1499,78 2~15.9& 196!,63 5!,78 ~¢24,50 1~50,&5 3575,70 2057,18 5i,~6 5~4,54 1622,26 3634,98 2130,23 50,29 2~4,07 1&~1,66 ~^95,~5 220z,36 4~,~= 322,05 17~?,34 -i174,64 1905,02 32!,93 -1221,24. 1981,69 ..... J~l,~o -1265,16 2057,27 322,05 -1.¥)7,83 2130,36 322,13 -1351,19 2202,50 322,16 1,72 3,60 0,13 1,50 1,93 ***** :**** ANADRiLL ****~*******~* SURVEY CALCL~ATiONS **~********** CIRCULAR A~£ M~ooR=u INTERVAL VERTICAL DEPTH DEPTH 473i,69 ?4,0 3757,8i 4A2A,'7 _ .. i, 94,5 3820,29 5012,98 ?3J 3942,t5 5i08,57 95,6 4CE~4,43 TARGET S~ATION AZ!ML~H LATITUDE SECTION ft ~e~ deq ft 2273,i4 48,39 323,22 1795.60 2344,00 48,82 3~,29 1852,02 24i4,47 4%56 320,84 I907,2! 2485.5? 49,20 321,74 !762.7! 2555~11 47,47 320.78 2019,27 DEPAB~URE DISPLACEMENT at E/-W ft ft ~7.,2~ -1394,i6 ~ ~' " -1437,0~ 2344,!7 -1480,87 24t4.63 -1525,35 2485,74 -1570,73 ~ ~ AZIMUTH 322,17 322,19 322,17 39~.i5 DLS O.e~/ tOOft ! ,37 1,42 0,62 5203,0? 5297,5i 5485,!8 5580,85 94,4 41~.59 92.8 4244.54 95.7 4305,01 ~,~7 Sa,~i 319,24 2074,65 977A,2q 50.79 320.~ 2i86.74 2848,16 5~,74 32i,45 2242,63 2922,28 50,86 :~3.91 2301.~,~° -!617.20 2630,50 322,06 -... ~! 0~.4~ -~AA4,0~ ~v ~. i£ 32~,00 -!7t0.$7 2776.37 321,96 -!755,87 2848.24 32i.94 -!800,81 2922,37 321~96 1.5! 0.95 0.50 0,68 5676,35 5772~0! 5959.76 6055.42 95,5 4365,0! 95.7 44..24,97 94,! 4484.1I 93,7 4542,96 95,7 4602,83 .~,~I 322.82 2361,21 Z~96,54 ~ ~ 307t.06 51.05 S~I,09 24~9,90 ~I44,~ 5i,05 32i,05 2476.81 32!7,10 5i,!! [~2,36 2534,02 -1845.15 2996.65 321.'?? -1891,07 3071.17 221.'99 -1937.04 o~aa oo 321,97 · ~A~.~ .. ~9~2,21 3217.~1 S21,97 -2027,68 329i.6! o5~ o~ 1,00 1,44 0,04 0.33 6245.32 6527.61 95,? 4662,78 94,0 472I.~.7 94.2 478!,44 94~! 484!,28 94,1 4901,07 3366,50 51,20 ~n ,, o~,~o 2651,7i 3439,63 50,95 3i9,23 2707,63 3512,40 50,56 31&67 2761,77 ~=~' ~: 5n,44 317~~ 36~!i 50.6! S16~34 2867,66 -2074.24 3366,61 321.97 -2!21,42 3439.72 321.92 o~^ c~ 3512,46 321.84 -2219 a': RSA4,7A -2269.58 3657.il 321.64 !,7! i:05 1.!4 0.4';_' 0.70 6822.47 67i6.76 6903+67 6997.53 94,9 4960.~I 94.3 50t9,65 94.i 5078.05. o.:.~,~,. 5!37,20 93.9 5t96,70 ~,% o., 5i,3~ 3i4.79 2920,27 3803,59 5i,46 315,14 2?72,34 3948~37 5i,01 316.79 3078.02 4020,79 50,32 3!6.36 3!3!,60 -232i.i6 37A0.2'~ 321,52 -2373,29 ..~.~Pnq,59 ~,';~*,3'? -2423,94 3876J4 .... ~,:~, ~n,_. -2473.03 3946.42 '.~21.~2 -2522,0! 4020.~, ~? 321,15 i~47 0,32 1,96 i.46 709P,40 7! R;.~ 7281 7376,~A 7470,81 94,9 5258.07 94.0 5319..77.' 95.4 5382.40 o4,4 ~ 28 94.7 55.,06,23 4093.07 49.06 319..58 3!86.i8 4163.'~ 48,66 320,51 3240,54 4235,82 49.0~ 4307.!4 49.09 4378,7i 49,!4 320,47 3407,45 -2569,48 4093.16 321.12 -2614.98 4!64.03 32i.10 -2660.42 a.~o: .... .'93 51'21.n`~, ... -2705,06 4307,26 32i,J. 0 -2750,15 4378,82 32!.09 0,73 0.48 0,30 0,77 7564.43 7659,26 7754.52 7849.83 7945.02 93,6 55~.7,70 94,6 .. ~O~U,41 95,3 5693,89 95,3 5758,23 95,2 5823,!6 4449,30 48,78 3t9,50 3461,54 4520,4! ~,43 32~,70 3516,1! 459!,43 47.99 320,93 3571,16 4~.1,74 47,08 320,92 3.525,75 473i,33 ~,90 3i9.75 ~.79,33 -2795,55 4449.42 321.05 -2841,19 4520.55 321.06 -28~.,06 459!.58 32i,06 -2930,38 4661,oo~ 321.05 -~974,8i 4731,48 32i,04 0,87 1,03 0,49 0.95 8i34.~ 8227 o~ ~ 5887,7A 94,0 555!,06 93,4 6013,08 94,7 6073,77 94,7 6133,13 4801,40 47,76 ~!,71 3733,59 4870,88 47,59 322,30 3788,34 4940,65 49,15 320,70 3842,94 5013,35 51,15 321,80 3899,64 D387,15 51,24 ,~!,.~ 3?57,49 -3019,17 4g0!,57 32!.04 -306t,94 4871,04 321.05 -3105,38 4940.80 321.06 -3150,88 5013.50 321.06 -3196,70 5087,30 321.07 1,75 0:50 2,11 2 0,32 MFq-i-02 ~£ASURED iNTERVAL V~RT!CAL &513,10 ?6,0 6173,45 8607,03 ?3,9 6252,86 8,702,27 ?5,2 63!3,60 8795+t7 92.9 i~v~ ~o 7890,47 95,3 6433,41 ~.R~E~ ~i~i!uN AZIMUTH LATITUDE SECTION iNCLN, ~/-~ 5307+90 50,14 37E0,98 4i27,55 5~79.4? %.AA 322+62 ,,~ ~o DSF'ARTURE. DISPLACEM~,NT at ft ft -3243.92 5161,79 ..... ~ ...... 08 AZIMUTH 6eg 321,07 321,05 321,04 321,05 321,07 DLS deq/ !OOf~ 1,12 0,44 1,47 0,35 9074,91 9264,54 ~JT,JO 91,4 649i+88 93,0 6551,11 94.9 66i.0,46 94.7 6668+19 95,0 6725.39 ~,.'.,~ +. ~ 5743,76 ~7 / jC . . -3469,40 US" ._20,40 -3519,4! 5595,!0 321,11 -~s~ ~? ~c. 08 321,'iA -3597,68 5743.53 321,22 -3639.61 5819,50 321,29 0,34 i,45 !,44 0.77- 9549,48 9644,06 9738 9832,!2 94,1 658i,30 ~1~ , 94,6 6893,94 94,9 6950,!4 93,1 7005.74 5894,72 53,73 2~7,43 4&.Z4 :,i ~Y, i ,~c, 53+67 UZ6,V/ 466Y,3Y AOi7 +53 ?' ~" - . ,. oJ+,.~ 2426+70 4733,Z5 6123,64 == =r, 299,gi 47?7,60 6i'97~92 53~ii :.~= =n 4~zr~ 7~ -3680,60 5894,73 321,36 _OwS'., ~ =,',7 ~ ,', 5~* -3764,!7 6047,53 321,51 -3805,52 6!23,64 321.58 -3245.46 6177,94 321,65 0.66 0,39 0,27 1.02 0,59 9926+27 94,2 100i9,15 92~9 lOllS TM 9A,4 _,~ .. 10212+00 96+5 7061.97 7!i7,00 7i73+97 723i.04 A27~.04 =~ =; 327,42 4924,42 ..... JO+J,., . 6347,38 53~77 328,45 4987.82 6424.64 ~ ~ ........... oo+,4 J~o,~ 5053,52 -3886,09 6273,08 321,72 -~°5,~n 6347,46 _q~A7.3n ~ w 321,87 6502,26 321,93 0,4E 0,92 i 0,00 gyro/data B.P. EXPLORATION ~ ~ ---~/ WELL NO:MPK-02 MILNE POINT, ALASKA Gyro Multishot Survey Inside 9.625 CASING Survey date' 5 MAY 1996 Job number' AK0596G340 Date_~ ~ ~ & G~ Cz, ms. CommL~ SR340.DOC gyro~/data Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920. June 21, 1996 B.P. Exploration Petrotechnical Data Center, MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Re~ K-PAD, WELL #MPK-02, MILNE POINT, AK Enclosed please find one (1) original, six (6) copies and one (1) disk of the completed survey of Well #MPK-02 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. Shoup Operations Manager RS/fee Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data. CONTENTS JOB NUMBER :AK0596G340 1. DISCUSSION , SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR340.DOC gyro/data 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR340.DOC gyro/data DISCUSSION JOB NUMBER · AK0596G340 Tool 746 was run in welI#MPK-02 on ATLAS 7/32" Wireline inside drillpipe, survey was run without problems. SR340.DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0596G340 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 SR340.DOC gyro/data 2. SURVEY DETAILS SR340.DOC gyro/data SURVEY' DETAILS JOB NUMBER: AK0596G340 CLIENT: B.P. EXPLORATION RIG: K PAD LOCATION: MILNE POINT, ALASKA WELL: MPK-02 LATITUDE: 70.4000 N LONGITUDE: 149.5 W SURVEY DATE: 5 MAY 1996 SURVEY TYPE : MULTISHOT IN 9.625 CASING DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 61.33FT. 4025 FT. SURVEY TIED ONTO: NA SURVEYINTERVAL: 100' FROM 0 -1000" 50' FROM 1000' - 4025' UTM CO-ORDINATES: TARGET DIRECTION: 321.51 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD SR340.DOC gyro/data 3. OUTRUN SURVEY LISTING SR340.DOC A Gyrodat a D i re c t iona i Survey for B.P. EXPLORATION WELL: MPK-02, 9.625 Location: K PAD, MILNE POINT, ALASKA ~ob~Number: AK0596G340 .un Date: 5-May-96 15:00:00 urveyor: TOM STODDARD !alculation Method: MINIMUM CURVATURE .urvey Latitude: 70.400000 deg. N lub-sea Correction from Vertical Reference: 61.33 ft. ~zimuth Correction: Bearings are Relative to True North 'roposed Well Direction: 321.510 deg ~ertical Section Calculated from Well Head Location ~losure Calculated from Well Head Location [orizontal Coordinates Calculated from Local Horizontal Reference A Gyrodat a Di re c t i ona i Survey ~.P. EXPLORATION ~ELL:~MPK-02, 9.625 Jocation: K PAD, MILNE Iob Number: AK0596G340 POINT, ALASKA 4EASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.00 0.0 0.0 0.0 0.00 0.00 0.0 0.0 -61.3 ] - 4025 FT. GYRO SURVEY RUN IN CASING. 4EASURED DEPTHS ARE REFERENCED TO AN RKB HEIGHT OF 61.33 FT. Page HORIZONTAL COORD I NATES feet 0.00 N 0.00 E 100.0 .69 159.41 100.0 -.6 38.7 200.0 .63 155.06 200.0 -1.7 138.7 300.0 .87 145.78 300.0 -3.0 238.7 400.0 .84 149.13 400.0 -4.5 338.6 500.0 .93 146.43 500.0 -6.0 438.6 600.0 .96 145.20 599.9 -7.6 538.6 700..0 1.00 143.73 699.9 -9.4 638.6 800.0 .83 143.57 799.9 -11.0 738.6 900.0 .31 124.88 899.9 -11.9 838.6 1000.0 .91 319.24 999.9 -11.4 938.6 1050.0 1.60 316.54 1049.9 -10.3 988.6 1100.0 2.37 313.51 1099.9 -8.6 1038.5 1150.0 3.49 316.34 1149.8 -6.0 1088.5 1197.0 4.58 317.73 1196.7 -2.8 1135.4 1250.0 6.57 318.01 1249.4 2.4 1188.1 1300.0 8.54 320.02 1299.0 8.9 1237.7 1350.0 9.39 320.15 1348.4 16.7 1287.1 1400.0 10.89 320.22 1397.6 25.5 1336.3 1450.0 12.53 321.20 1446.6 35.7 1385.2 1500.0 13.79 321.75 1495.2 47.1 1433.9 . 1. 2. 2. 3. . 1. 3. 3. 2. .69 .08 .27 .06 .09 04 05 16 55 21 39 56 26 31 75 97 70 01 30 52 .6 159.4 1.8 158.1 3.1 154.5 4.5 152.2 6.1 151.0 7.7 149.9 9.4 148.9 11.0 148.2 12.0 147.4 1.1.5 147.4 10.4 148.5 8.7 151.2 6.3 157.6 3.4 177.5 3.3 277.2 9.3' 305.3 17.0 312.1 25.7 314.8 35.8 316.5 47.2 317.7 .57 S .21 E 1.6'3 S .66 E 2.75 S 1.32 E 4.02 S 2.12 E 5.32 S 2.95 E 6.69 S 3.87 E 8.08 S 4.87 E 9.37 S 5.82 E 10.11 S 6.47 E 9.66 S 6.17 E 8.85 S 5.43 ! 7.63 S 4.20 E 5.82 S 2.40 E 3.40 S .15 E .42 N 3.30 W 5.39 N 7.60 W 11.36 N 12.59 W 18.12 N 18.23 W 25.98 N 24.65 W 34.89 N 31.74 W A Gyroda t a D i r e c t i ona i Survey I.P. EXPLORATION TELL: MPK-02, 9.625 Jocation: K PAD, MILNE POINT, rob Number: AK0596G340 ALASKA Page [EASURED 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 ,C 00 R D I N A T E S feet 1550.0 14.23 321.45 1543.8 1600.0 14.59 322.07 1592.2 1650.0 16.04 321.07 1640.4 1700.0 19.89 320.371 1688.0 1725.0 22.19 320.14 1711.3 59.2 71.6 84.8 100.2 109.2 1482.4 1530.9 1579.1 1626.6 1650.0 .89 59.3 318.5 .79 71.7 319.1 .95 84.9 319.5 .71 100.3 319.6 .19 109.3 319.7 44.38 N 39.26 W 54.15 N 46.96 W 64.49 N 55.18 W 76.43 N 64.95 W 83.33 N 70.69 W 1775.0 25.35 320.50 1757.0 1825.0 27.30 320.59 1801.9 1875.0 28.82 320.96 1846.0 1925.0 30.08 321.28 1889.5 1975.0 30.23 321.83 1932.8 129.4 151.5 175.0 199.6 224.7 1695.7 1740.5 1784.6 1828.2 1871.4 .32 129.4 319.8 .90 151.6 319.9 .07 175.1 320.0 .52 199.7 320.2 · 63 224.8 320.3 98.84 N 83.55 W 115.95 N 97.64 W 134.18 N 112.51 W 153.31 N 127.94 W 172.98 N 143.55 W 2025.0 31.26 321.88 1975.7 2075.0 32.88 322.09 2018.1 2125.0 36.04 322.02 2059.3 2175.0 36.95 322.42 2099.5 2225.0 39.12 322.29 2138.9 250.3 276.8 305.1 334.9 365.7 1914.4 1956.8 1998.0 2038.2 2077.6 .07 250.3 320.5 .24 276.9 320.6 .32 305.2 320.7 .88 334.9 320.9 .35 365.7 321.0 193.09 N 159.34 W 214.00 N 175.69 W 236.31 N 193.08 W 259.81 N 211.30 W 284.20 N 230.11 W 2275.0 38.92 322.47 2177.7 2325.0 40.81 322.53 2216.1 2375.0 41.67 322.48 2253.7 2425.0 42.54 322.41 2290.8 2475.0 43.27 322.48 2327.4 397.1 429.2 462.1 495.7 529.7 2116.4 2154.8 2192.4 2229.5 2266.1 .45 397.2 321.1 .78 429.2 321.2 .72 462.1 321.3 .74 495.7 321.4 .46 529.7 321.5 309.13 N 249.33 ~ 334.56 N 268.84 W 360.71 N 288.90 W 387.29 N 309.34 W 414.27 N 330.08 W 2525.0 45.51 322.28 2363.2 2575.0 47.47 322.34 2397.6 2625.0 49.67 322.64 2430.7 2675.0 51.05 322.68 2462.6 2725.0 51.17 322.97 2494.0 564.7 600.9 638.4 676.9 715.8 2301.8 2336.3 2369.3 2401.2 2432.6 .49 564.7' 321.5 .94 600.9 321.6 .41 638.4 321.6 .77 676.9 321.7 .51 715.8 321.7 441.97 N 351.43 W 470.66 N 373.60 W 500.40 N 396.42 W 531.01 N 419.78 W 562.02 N 443.29 W A Gyrodat a D i r e c t iona i Survey .P. EXPLORATION tELL: MPK-02, 9.625 ,ocation: K PAD, MILNE POINT, 'ob Number: AK0596G340 ALASKA Page [EASURED 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 .C O 0 R D I N A T E S feet 2775.0 51.43 323.01 2525.2 2825.0 51.73 323.16 2556.3 2875.0 52.06 323.25 2587.1 2925.0 52.19 323.38 2617.8 2975.0 51.22 322.79 2648.8 754 794 833 872 912 .8 .0 .3 .7 .0 2463.9 2495.0 2525.8 2556.5 2587.5 .53 754.8 321.8 .64 794.0 321.9 .69 833.3 321.9 .32 872.8 322.0 2.15 912.0 322.0 593.18 N 466.78 W 624.50 N 490.31 W 656.00 N 513.88 W 687.65 N 537.46 W 719.03 N 561.03 W 3025.0 51.24 322.55' 2680.1 3075.0 51.98 322.82 2711.2 3125.0 51.18 322.84 2742.3 3175.0 48.95 322.15 2774.3 3225.0 47.37 322.09 2807.7 950 990 1029 1067 1104 .9 .1 .3 .6 .9 2618.8 2649.9 2680.9 2713.0 2746.4 .37 951.0 322.1 1.56 990.2 322.1 1.60 1029..3 322.1 4.59 1067.7 322.1 3.17 1104.9 322.1 750.02 N 584.67 W 781.19 N 608.43 W 812.41 N 632.10 W 842.82 N 655.43 W 872.22 N 678.31 W 3275.0 46.89 322.09 2841.7 3325.0 49.00 322.05 2875.2 3375.0 50.22 322.07 2907.6 3425.0 50.13 322.27 2939.6 3475.0 49.69 322.38 2971.8 1141 1178 1216 1255 1293 .5 .6 .7 .1 .4 2780.4 2813.9 2846.3 2878.3 2910.5 .95 1141.6 322.1 4.23 1178.7 322.1 2.42 1216.8 322.1 .36 1255.2 322.1 .90 1293.4 322.1 901.13 N 700.82 W 930.41 N 723.65 W 960.45 N 747.06 W 990.78 N 770.61 W 1021.05 N 793.99 W 3525.0 49.74 322.35 3004.2 3575.0 50.27 322.37 3036.3 3625.0 50.70 322.56 3068.1 3675.0 51.21 322.68 3099.6 3725.0 51.46 322.80 3130.8 1331' 1369 1408 1447 1486 .5 .8 .4 .2 .2 2942.8 2975.0 3006.8 3038.3 3069.5 .10 1331.6 322.1 1.07 1369.9 322.1 .90 1408.5 322.2 1.04 1447.3 322.2 · 54 1486.3 322.2 1051.26 N 1081.59 N 1112.18 N 1143.03 N 1174.11 N 817.28 ~ 840.67 W 864.17 W 887.75 W 911.38 W 3775.0 51.57 323.09 3162.0 3825.0 51.60 323.22 3193.0 3875.0 51.61 323.51 3224.1 3925.0 51.65 320.81 3255.1 3975.0 51.78 319.51 3286.1 1525.3 1564.5 1603.7 1642.9 1682.1 3100.6 3131.7 3162.8 3193.8 3224.8 .50 1525.5 322.2 .22 1564.6 322.2 .45 1603.8 322.3 4.23 1643.0 322.2 2.05 1682.2 322.2 1205.34 N 1236.69 N 1268.14 N 1299.09 N 1329.23 N 934.97 W 958.46 W 981.84 W 1005.89 W 1031.03 W A Gyro da t a D i re c t i ona I Survey ~.P. EXPLORATION IELL.: MPK-02, 9.625 Jocation: K PAD, MILNE POINT, ALASKA rob Number: AK0596G340 Page IEASURED 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. H 0 R I Z O N T A L COORDINATES feet 4025.0 51.94 319.70 3317.0 1721.4 3255.7 .43 1721.5 322.1 1359.18 N 1056.51 Final Station Closure: Distance: 1721.51 ft Az: 322.14 deg. A Gyro da t a D i r e c t i ona I Survey for B.P. EXPLORATION WELL: MPK-02, 9.625 Location: K PAD, MILNE POINT, ALASKA Iob Number: AK0596G340SS {un Date: 5-May-96 15:00:00 ~urveyor: TOM STODDARD ~alculation Method: MINIMUM CURVATURE ~urvey Latitude: 70.400000 deg. N 3ub-sea Correction from Vertical Reference: 61.33 ft. %zimuth Correction: ~yro: Bearings are Relative to True North Proposed Well Direction: 321.510 deg Yertical Section Calculated from Well Head Location 2losure Calculated from Well Head Location Korizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i r e c t i ona i Survey I.P. EXPLORATION [ELL: MPK-02, 9.625 Jocation: K PAD, MILNE POINT, ~ob Number: AK0596G340SS ALASKA Page SUBSEA DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL SECTION feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. H O R I Z O N T A L C O O R D I N A T E.S feet -61.3 0.00 0.00 0.0 100.0 .65 156.74 161.3 200.0 .78 149.37 261.3 300.0 .86 147.84 361.3 400.0 .90 147.47 461.3 0.0 -1.3 -2.5 -3.9 -5.4 0.00 0.0 0.0 .32 1.8 158.6 .20 3.1 155.9 .14 4.5 153.1 .08 6.1 151.5 0.00 N 0.00 E 1.22 S .49 E 2.32 S 1.06 E 3.53 S 1.81 E 4.82 S 2.63 E 00 00 00 00 00 .0 .95 145.68 561.3 .0 .98 144.30 661.3 .0 .90 143.63 761.3 .0 .51 132.09 861.3 .0 .68 244.25 961.3 -7.0 -8.7 -10.3 -11.6 -11.6 .06 .04 .12 .40 .95 7.7 150.3 9.4 149.3 11.0 148.5 12.0 147.7 11.5 147.4 6.16 S 3.52 E 7.54 S 4.48 E 8.87 S 5.45 E 9.82 S 6.22 E 9.83 S 6.28 E 1000.0 1.78 315.85 1061.3 1100.0 3.76 316.68 1161.3 1200.0 7.04 318.49 1261.3 1300.0 9.78 320.17 1361.3 1400.0 12.91 321.37 1461.3 -9.9 -5.2 4.0 19.0 39.1 . 2. 3. 2. 3. 43 27 81 O5 O7 8.7 149.1 3.4 162.5 9.3 284.0 25.7 312.8 47.2 316.9 8.57 S 5.15 E 5.22 S 1.84 E 1.61 N 4.33 W 13.14 N 14.08 W 28.69 N 26.81 W 1500.0 14.36 321.68 1561.3 1600.0 17.74 320.76 1661.3 1700.0 25.53 320.51 1761.3 1800.0 29.27 321.07 1861.3 1900.0 30.92 321.86 1961.3 63.7 91.6 131.5 183.7 241.7 5. 6. 2. 1. 85 05 09 88 59 71.7 318.7 100.3 319.5 151.6 319.8 199.7 320.1 250.3 320.4 47.92 N 42.06 W 69.74 N 59.48 W 100.47 N 84.90 W 140.92 N 117.95 W 186.35 N 154.05 W 2000.0 36.08 322.04 2061.3 2100.0 39.01 322.39 2161.3 2200.0 41.85 322.46 2261.3 2300.0 45.39 322.29 2361.3 2400.0 51.00 322.68 2461.3 306.6 383.8 469.0 562.9 675.4 . 2. 1. 4. 2. O9 10 72 34 84 334.9 320.8 397.2 321.1 495.7 321.3 564.7 321.5 676.9 321.7 237.49 N 194.00 W 298.60 N 241.21 W 366.17 N 293.10 W 440.55 N 350.34 W 529.83 N 418.87 W A Gyrodat a Di re c t iona i Survey ~.P. EXPLORATION ~ELL: MPK-02, 9.625 ~ocation: K PAD, MILNE Iob Number: AK0596G340SS POINT, ALASKA Page SUBSEA .DEPTH feet I N C L AZIMUTH VERTICAL DEPTH deg. deg. feet VERTICAL DOGLEG CLOSURE SECTION SEVERITY DIST. AZIMUTH feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2500.0 51.78 323.17 2561.3 2600.0 51.23 322.69 2661.3 2700.0 49.86 322.43 2761.3 2800.0 48.13 322.06 2861.3 2900.0 49.84 322.35 2961.3 800.4 .65 833.3 321.9 927.5 1.44 951.0 322.0 1052.1 3.38 1067.7 322.1 1163.2 2.87 1178.7 322.1 1280.9 .72 1293.4 322.1 629.64 N 494.16 W 731.41 N 570.47 W 830.49 N 645.97 W 918.28 N 714.19 W 1011.18 N 786.37 W 3000.0 50.61 322.52 3061.3 3100.0 51.57 323.08 3161.3 3200.0 51.68 320.55 3261.3 3255.7 51.94 319.70 3317.0 1400.1 .93 1408.5 322.2 1524.6 .50 1525.5 322.2 1650.7 3.80 1682.2 322.2 1721.4 .43 1721.5 322.1 1105.66 N 1204.71 N 1305.13 N 1359.18 N 859.17 W 934.49 W 1010.93 W 1056.51 W Final Station Closure: Distance: 1721.51 ft Az: 322.14 deg. A Gyrodat a Di re c t ional Survey for B.P. EXPLORATION WELL: MPK-02, 9.625 Location: K PAD, MILNE POINT, ALASKA lob Number: AK0596G340SS Jun Date: 5-May-96 15:00:00 ~urveyor: TOM STODDARD ~alculation Method: MINIMUM CURVATURE ~urvey Latitude: 70.400000 deg. N ~ub-sea Correction from Vertical Reference: 61.33 ft. ~zimuth Correction: ]yro: Bearings are Relative to True North ?roposed Well Direction: 321.510 deg zertical section Calculated from Well Head Location ~losure Calculated from Well Head Location ~orizontal Coordinates Calculated from Local Horizontal Reference A Gyro da t a D i re c t i ona i Survey ~.P. EXPLORATION ~ELL: MPK-02, 9.625 ~ocation: K PAD, MILNE POINT, ~ob Number: AK0596G340SS ALASKA SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. -61.3 0.00 0.00 0.0 0.0 0.00 ) - 4025 PT. GYRO SURVEY RUN IN CASING.' 4EASURED DEPTHS ARE REFERENCED TO AN RKB HEIGHT OF 61.33 CLOSURE DIST. AZIMUTH feet deg. 0.0 0.0 FT. Page HORIZONTAL COORDINATES feet O.Od N 0.00 E 100 . 0 . 65 156 . 74 161 . 3 -1 · 3 200 · 0 .78 149.37 261.3 -2 · 5 300 . 0 · 86 147.84 361.3 -3 · 9 400.0 .90 147.47 461.3 -5.4 500.0 · 95 145.68 561.3 -7 · 0 600.0 .98 144.30 661.3 -8.7 700.0 .90 143.63 761.3 -10.3 800.0 .51 132.09 861.3 -11.6 900.0 .68 244.25 961.3 -11.6 1000.0 1.78 315.85 1061.3 -9.9 1100.0 3.76 316.68 1161.3 -5.2 1200.0 7.04 318.49 1261.3 4.0 1300.0 9.78 320.17 1361.3 19.0 1400.0 12.91 321.37 1461.3 39.1 1500.0 14.36 321.68 1561.3 63.7 1600.0 17.74 320.76 1661.3 91.6 1700.0 25.53 320.51 1761.3 131.5 1800.0 29.27 321.07 1861.3 183.7 1900.0 30.92 321.86 1961.3 241.7 2000.0 36.08 322.04 2061.3 306.6 .32 .20 .14 .08 .06 .04 .12 .40 .95 1.43 2.27 3.81 2.05 3.07 .85 5.05 6.09 2.88 1.59 6.09 10 15 19 25 33 1.8 158.6 3 .1 155.9 4.5 153.1 6.1 151.5 7.7 150.3 9.4 149.3 1.0 148.5 2.0 147.7 1.5 147.4 8.7 149.1 3.4 162.5 9.3 284.0 5.7 312.8 7.2 316.9 1.7 318.7 0.3 319.5 1.6 319.8 9.7 320.1 0.3 320.4 4.9 320.8 1.22 S .49 E 2.32 S 1.06 E 3.53 S 1.81 E 4.82 S 2.63 E 6.16 S 3.52 E 7.54 S 4.48 E 8.87 S 5.45 E 9.82 S 6.22 E 9.83 S' 6.28 E 8.57 S 5.15 E 5.22 S 1.84 E 1.61 N 4.33 W 13.14 N 14.08 W 28.69 N 26.81 W 47.92 N 42.06 W 69.74 N 59.48 W 100.47 N 84.90 W 140.92 N 117.95 W 186.35 N 154.05 W 237.49 N 194.00 W A Gyroda t a. D i r e c t iona i Survey .P. EXPLORATION ELL: MPK-02, 9.625 ocation: K PAD, MILNE POINT, ob Number: AK0596G340SS ALASKA Page SUBSEA I N C L AZIMUTH DEPTH feet deg. deg. VERTICAL VERTICAL DOGLEG CLOSURE DEPTH SECTION SEVERITY DIST. AZIMUTH feet feet deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 2100.0 39.01 322.39 2200.0 41.85 322.46 2300.0 45.39 322.29 2400.0 51.00 322.68 2500.0 51.78 323.17 2161.3 383.8 2.10 397.2 321.1 2261.3 469.0 1.72 495.7 321.3 2361.3 562.9 4.34 564.7 321.5 2461.3 675.4 2.84 676.9 321.7 2561.3 800.4 .65 833.3 321.9 298.60 N 241.21 W 366.17 N 293.10 W 440.55 N 350.34 W 529.83 N 418.87 W 629.64 N 494.16 W 2600.0 51.23 322.69 2700.0 49.86 322.43 2800.0 48.13 322.06 2900.0 49.84 322.35 3000.0 50.61 322.52 2661.3 927.5 1.44 951.0 322.0 2761.3 1052.1 3.38 1067.7 322.1 2861.3 1163.2 2.87 1178.7 322.1 2961.3 1280.9 .72 1293.4 322.1 3061.3 1400.1 .93 1408.5 322.2 731.41 N 570.47 W 830.49 N 645.97 W 918.28 N 714.19 W 1011.18 N 786.37 W 1105.66 N 859.17 W 3100.0 51.57 323.08 3200.0 51.68 320.55 3255.7 51.94 319.70 3161.3 1524.6 .50 1525.5 322.2 3261.3 1650.7 3.80 1682.2 322.2 3317.0 1721.4 .43 1721.5 322.1 1204.71 N 1305.13 N 1359.18 N 934.49 W 1010.93 W 1056.51 W ~inal Station Closure: Distance: 1721.51 ft Az: 322.14 deg. gyro/data- QUALITY CONTROL REPORT JOB NUMBER: AK0596G340 TOOL NUMBER: 746 MAXIMUM GYRO TEMPERATURE: 72.45 C MAXIMUM AMBIENT TEMPERATURE: 54.23 C MAXIMUM INCLINATION: 52.19 AVERAGE AZIMUTH: 322.14 WIRELINE REZERO VALUE: 4.3 REZERO ERROR/K: 1.0034 CALIBRATION USED FOR FIELD SURVEY: 1291 CALIBRATION USED FOR FINAL SURVEY: 1291 PRE JOB MASS BALANCE OFFSET CHECK: -.4 POST JOB MASS BALANCE OFFSET CHECK~: CONDITION OF SHOCK WATCHES -.451 USED -.39 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 4025 51.94 319.70 3317.0 1359.2 -1056.5 FINAL SURVEY 4025 51.94 319.70 3317.0 1359.18 -1056.51 SR340.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0596G340 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 4025 51.94 51.94 51.94 51.94 51.94 AZIMUTH M.D. ft 1' 2 3 4 5 4025 319.70 319.70 319.70 319.70 319.70 SR340.DOC gyro/data EQUIPMENT AND CHRONOLOGICAL REPORT SR340.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0596G340 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 746 GYRO SECTION A0119 DATA SECTION C0073 POWER SECTION C0065 BACKUP TOOL No. 739 GYRO SECTION A0004 DATA SECTION C0035 POWER SECTION C0033 COMPUTER POWER SUPPLY PRINTER INTERFACE COMPUTER POWER SUPPLY PRINTER INTERFACE A0222 A0085 A0079 A0035 A0246 A0107 A0029 A0071 WIRELINE COMPANY: CABLE SIZE: ATLAS WIRELINE 7/32" RUNNING GEAR 2.5" SYSTEM TOTAL LENGTH OF TOOL: MAXIMUM O.D.: 15 FEET 2.5 INCHES TOTAL WEIGHT OF TOOL: 100 POUNDS SR340.DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK0596G340 05/05/96 05:00 05:45 06:30- 10:15 10:45 11:15 12:00 13:15 13:50 14:45 17:30 18:50 TRANs TO LOCATION ARRIVE AT LOCATION MU TOOL TOOL WORKING, STANDBY PU TOOL, MU PUMPIN SUB RIH. 1000' START CONTINUOUS RUN 4025' CK. DATA OK. CONTINUOUS OUT 1000' GYRO COMPASS OUT. LD. TOOL BD. TOOL RD. ATLAS ARRIVE AT ATLAS. PROCESS SURVEY RTN. TO RIG W / SURVEY.(K PAD) 05/06/96 14:00 RETURN TO ANCHORAGE SR340.DOC HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 20 September 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL # DESCRIPTION ~¢-ce~ ~-0~ ~ 7~q~ ~ ~,~ ~.+~.~s ECC No. Run # 1 6653.01 Run # 1 6774.00 Please sign and return to: Attn. Ro~ey D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 ~chorage, AK 99518 ~ ~r F~ to (907) 563-7803 Received by(~~¢ Date: ! I Schlumberger - GeoQuest A Division of Schlumberger Technologies Corporation 500 W. International Airport Road Anchorage, Alaska 99518 - 1199 (907) 562-7669 (Bus.) (907) 563-3309 (Fax) August 30, 1996 TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 The following data of the CDR/CDN. CDR/CDN TVDfor well MPK-02 Job # 96163 was sent to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 1 OH LIS Tape 3 Bluelines each 1 Film each Stat~-0f Alaska Alaska Oil & Gas Conservation Comm. Attn. Larry Grant 3'001..Porcupine Ddve Anchorage, Alaska 99501 1 OH LIS Tape I Biueline each':. 1 RF Sepia each .../~ ..- OXY USA, Inc Attn: Darlene Fairly P.O. Box 50250 Midland, Texas 79710 1 OH LIS Tape 1 Blueline each 1 RF Sepia each Sent Certified Mail Z 777 937 467 .NOTE: NO DEPTH SHIFT PER MATT LINDER PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP EXPLORATION (ALASKA)INC. PETROTECHNICAL DATA CENTER, MB3-3 900 EAST BENSON BLVD. ANCHORAGE, ALASKA 99519-6612 Schlumberger Courier: SCHLUMBERGER GEOQUEST 500 WEST INTERNATIONAL AIRPORT ROAD ANCHORAGE, ALASKA 99518-1199 RECEIVED DateDelivere~:[P05 '~99~O Received B,: ~ ~)~ ~ Oil 8, Gas Co~s. Commi~n ~¢~e HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 2 August 1996 Transmittal of Data ECC #: 6728.00 Sent by: HAND CARRY Data: ML-LDWG Dear Sir/Madam, Reference: BP MILNE POINT / KUPARUK NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Received by: Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 nor F~ to /9071 563-7803 Date: /~UG 12 Abst¢., Oil & Gss Co~s. Comrr, i~o~ ~cbor~e HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE Ai~CHORAGE AK, 99501. Date: RE: 2 August 1996 Transmittal of Data ECC #: 6728.01 Sent by: HAND CARRY Data: PLS Dear Sir/Madam, Reference: Enclosed, please find the data as described below: Prints/Films: 1 PLS FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Received b~~ Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A~[, 99501. Date: 1 August 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, please find the data as described below: WELL DESCRIPTION 1 GR/CCL FINAL BL+RF 1 PFC/PERF FINAL BL+RF 1 PFC/PERF FINAL BL+RF Run # 1 Run # 1 Run # 1 ECC No. 6728.01 6755.00 Please sign and return to: Attn. Rodney D. Paulson Received by~ Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: REGEIVED AUG ] 2 Oil & Gas Oo~s. Commissi~ .,~chorage HOWARD OKLAND Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE A_K, 99501. Date: 19 July 1996 RE: Transmittal of Data Sent by: HAND CARRY WELL ~(~-0'~(~ MPK-37 ~ ~{0~ MPF-74 Dear Sir/Madam, Enclosed, please find the data as described below: $ DESCRIPTION 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 GR/CCL FINAL BL+RF 1 SBT/GR FINAL BL+RF ECC No. Run # 1 6638.02 Run # 1 6639.01 Run # 1 6728.00 Run # 1 6729.00 Run # 1 6730.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Anchorage, AK 99518 Or FAX to (907) 563-7803 Date: JUL 26 ~ 0~1 & G~ Co~s. Commi~i~ ,~c~om~e ME, iOP, ANDU TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission David Johns .t~ Chairman Blair Wondzell, P. I. Supervisor-~'?~/~'~ F_~_O~!: Bobby Foster,'~'~' SUBJECT: Petroleum Inspector DATE: May 5, 1996 FILE NO: AWQIEEDD.doc BOPE Test - Nabors 27E BPX - MPU - MPK-02 PTD # 96-0081 Kuparuk River Field Sunday, May 5, 1996: I traveled this date to BPX's MPU well MPK-02 being drilled by Nabors rig 27 E and witnessed the initial BOPE test. As the attached AOGCC BOPE Test Report shows there was 1 failure - a valve in the choke manifold leaked - the valve was cycled and tested OK. While standingby for the test to begin ! spoke with Brian Busby, Nabors toolpusher, concerning the surface cement job. Brian said that they circulated out 15 +- bbls. of good cement. ! later talked with Tom Anglen, SDS rep., and he told me that they did indeed get about 15 bbls. of cement back and that they had changed up the cementing program up. They had lightened up the spacer from 12 ppg. to 11ppg. and had added 1/4 ppsk. of FLOCELE, a lost circulation material to the lead cement which was 200% over calculated volume of the annulus volume. The lead cement consisted of 780+- sks. of TYPE E Permafrost. The tail cement consisted of 914+- sks. ( 30% over annular volume ) of Premium Class G. Tom said that the next surface cement would probably be performed in the same manner to see if this program will continue to work. The rig was clean and all equipment seemed to be in good working order. The location was clean and ali extra equipment was stored properly. There was good access to all areas of the rig. Summary: I witnessed the initial BOPE test on BPX's MPU well MPK-02 being drilled by Nabors rig 27E - test time 3 - 1 failure. ,Attachment: AWQIEEDD.XLS X_ Unclassified Confidential (Unclassified if doc. removed ) STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report OPERATION: Drlg: X Drig Contractor: Operator: Well Name: Casing Size: g. 625" Test: Initial X Workover: NABORS Rig No. 27E PTD # BPX Rep.: MPK-02 Rig Rep.: Set @ 4,296' Location: Sec. Weekly Other DATE: 5/5/96 g6-008'1 Rig Ph.# 659-4384 TOM ANGLEN BRIAN BUSBY 3 T. 12N R. 11E Meridian Um. MISC. INSPECTIONS: Location Gen.: OK Housekeeping: OK (Gen) PTD On Location YES Standing Order Posted YES Well Sign OK Drl. Rig OK Hazard Sec. YES Test FLOOR SAFETY VALVES: Quan. Pressure P/F Upper Kelly / IBOP I I 500/5,000 ~ P Lower Kelly / IBOP I! 500/5,000 r P Ball Type I 500~ 000 P Inside BOP ' I '500~,000 ' . P BOP STACK: Quan. Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves 2 Kill Line Valves ' 1 Check Valve N lA Test Press. P/F 300/3,000 P 500/5,000 P P I 500/5,000 500/'3,000 ,, . 500/5,000 P P CHOKE MANIFOLD: No. Valves 17 No. Flanges 42 Manual Chokes 2 Hydraulio Chokes I Test Pressure P/F 500/5,000 F/P Functioned Functioned P P ACCUMULATOR SYSTEM: System Pressure 3,000 I P Pressure After Closure '1, 700 t P MUD SYSTEM: Visual Alarm 200 psi Attained After Closure 0 minutes 22 Trip Tank . YES YES System Pressure Attained I minutes 41 Pit Level Indicators YES YES Blind Switch Covers: Master: YES Remote: Flow Indicator YES YES Nitgn. Btl's: 8 {~, 2350 av~l. . . Meth Gas Detector YES YES Psig. H2S Gas Detector YES YES . , sec. sec. YES Number of Failures: '/ ,Test Time: 3.0 Hours. Number of valves tested 23 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with' Written 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 I I . . I I I I I III I I REMARKS: Distribution: orig-Well File c - Oper./Rig c - Database c - Tdp Rpt File c - Inspector STATE w~¥hEss REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO I Waived By: W~tnessed By: BOBBY D. FOSTER FI-021L (Rev. 12/94) AWQIEEDD.XLS MEMORANDUM THRU: State of Alaska Aias~(a Oil and Gas Conservation Commission Dc. vid Johr~ei ..... Chairman ...& Blair Wondz~ll,5",~) P. I. Supe~is~~~' FROM: Bobby Foster~.~-' SUBJECT: Petroleum Inspector ~ 'T' · uA, E. May 1, 1996 FILE NO: EWQIEADD.doc Diverter Inspection BPX - MPU - K- 02 Kuparuk River Field Wednesday, May 1, 1996: I traveled this date to BPX's MPU well K- 02 and inspected the diverter system. The system was installed propedy and caution/warning signs were installed at the ends of the vent lines. The lines were secured and the divert valves were operational, i did not witness the system test due to having to travel to another job but I spoke with Tom Anglen, BPX rig rep., and he said the system operated properly. Summary: i inspected the diverter system on Nabors rig 27E drilling BPX's MPU well K-02 Attachment: EWQIEADD.XLS X Unclassified Confidential (Unclassified if doc. removed ) Confidential ._ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Diverter Systems Inspection Report Drlg Contractor: Nabors Alaska Drilling, l.nc. Operator: BPX MPU Well Name: MPK-02 Location: Sec. 3 T. 12N R. Operation: Development Rig No. 27E PTD # Oper. Rep.: Rig Rep.: 11E Merdian Umiat Date: 511196 X Exploratory: , , 96-0081 Rig Ph. # 659-4384 TOM ANGLEN BRIAN BUSBY MISC. INSPECTIONS: ACCUMULATOR SYSTEM: Location Gen.: OK Well Sign: OK Systems Pressure: Not Tested . psig Housekeeping: OK (Gen.) Drlg. Rig: OK Pressure After Closure: psig Reserve Pit:.. N ,/A Flare Pit: N / A 200 psi Attained After Closure: min. sec. Systems Pressure Attained: ~min. _..._.._sec. Nitrogen Bottles: DIVERTER SYSTEM INSPECTION: Diver[er Size: 20 Diver[ Valve(s) Full Opening: YES Valve(s) Auto & Simultaneous: YES Vent Line(s) Size: 10 Vent Line(s) Length: Line(s) Bifurcated: YES Line(s) Down Wind: YES Line(s) Anchored: YES Turns Targeted / Long Radius: YES in. psig 86 & 136 ff. MUD SYSTEM INSPECTION: Light Alarm Trip Tank: OK OK Mud Pits: OK OK Flow Monitor: OK OK GAS DETECTORS: Light Alarm Methane NT NT Hydrogen Sulfide: NT NT NORTH Prevailing Winds N.O. (2) 10" Mechanically{ Knife VaNes N.C. Mud System ~ Motor Module Drawing Not To Scale Pipe Shed 20" Annular Preventer With 10" FO Hydraulic Knife Valve NOn Compliance items 0 Repair Items Withil 0 Remarks: Inspected for proper installation only. Day (s) And contact the Inspector @ 659-3607 Distribution orig. - Well File c - Oper/Rep c- Database c - Trip Rpt File c - Inspector AOGCC REP.: FI-022 (Rev. 7/93 EWQIEADD,XLS ~$1~& O~L AND GAS CONSEI~¥A~0N C0~SSION TONY KNOWLE$, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 29, 1996 Tim Schofield, Senior Drilling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re; Well # Company Permit # Surf Loc Btmhole Loc Milne Point Unit MPK-02 BP Exploration (Alaska), Inc 96-081 3800qNSL, 2042~EL, Sec 03, T12N, R11E, UM 35732qSL, 1301~3/EL, Sec 32, T13N, RilE, UM Dear Mr Schofield: Enclosed is the approved application for permit to drill 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. Approval' for annular injection is contingent on the operator's submittal of an Application for Sundry Approvals (10-403) with pertinent facts and evaluation of surface hole conditions, casing placement, cementing, and any diagnostic logs that were nm. The documentation submitted should assure the Commission that an adequate seal has been attained and that the well has been cased and cemented according to regulation. The commission hereby denies your request for annular injection in all wells on K-pad except for MPK-17, until such time as a 10-403 is submitted and approved. 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 drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Tuckerman Babcock Commissioner BY ORDER OF THE COMMISSION STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 [] Drill [] Redrill Ilb. Type of well [] Exploratory [] Stratigraphic Test [] Development Oil la. Type of work [] Re-Entry [] Deepen I [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RTE = 61' Milne Point Unit / Kuparuk River 3. Address 6. Property Designation Sands P.O. Box 196612, Anchorage, Alaska 99519-6612 :"'ADL 028231 [4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 3800' NSL, 2042' WEL, SEC. 3, T12N, R11E Milne Point Unit At top of productive interval 8. Well Number 'dqumber 2S100302630-277 3382' NSL, 1150' WEL, SEC. 32, T13N, R11E MPK-02 At total depth 9. Approximate spud date Amount $200,000.00 3573' NSL, 1301' WEL, SEC. 32, T13N, R11E 05/01/96 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028232, 1150'I MPK-05, 106' @ 750' TVD 2555 10142' M D / 7211' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e) Kick Off Depth 1000 Maximum Hole Angle $0.57° Maximum surface 3005 psig, At total depth (TVD) 7529' / 3758 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.1# NT80LHE Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 5844' 31' 31' 4299' 3500' 650 sx PF'E', 914 sx Class 'G' 8-1/2" 7" 26# L-80 Mod B 10112' 30' 30' 10142' 7211' 393 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 Cas in g Le n gth Size Cemented M D TVD Structural Conductor Surface Intermediate Production E C E iV E D Liner APR 1 8 199G Perforation depth: measured Aia¢<a 0it & Gas Cons. Commission true vertical Ancl',orage 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Ddlling Program [] Drilling Fluid Program [] Time vs Depth PIct [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Engineer Name/Number:~64-5089 ~ Prepared By Name/Number Kathy Campoamor, Contact 564-5 122 21. I hereby certify that the foregoing is' e best of my knowledge Tim Schofield /Icl'T) ~ ~_~~/~¢~ Title Senior Drilling Engineer Date ~,- 8 / Commission Use Only Permit Number _ I APl Number I Approval Date I See cover letter I for other requirements Conditions of Approval: Samples Required [] Yes 12~ No Mud Log Required [] Yes j~ No Hydrogen Sulfide Measures F-lYes ~t~No Directional Survey Required RYes [] No Required Working Pressure for BOPE FI2M; 1--13M; lid 5M; [] 10M; [] 15M Other: ORIGINAL SIGNED BY by order of ,.,/ Approved By J. David Noll;ol], P.E. Commissioner the commission Date / IPlicate Form 10-401 Rev. 12-01-85 Submit I Well Name: I MPK-02 [ Well Plan Summary I Type of Well (producer or injector): ]Kuparuk Producer I Surface Location: 3800' FSL 2042' FEL Sec 3 T12N R11E UM., AK. Target Location: 3382' FSL 1150' FEL Sec 32 T13N R11E UM., AK. Bottom Hole 3573' FSL 1301' FEL Sec 32 T13N R11E UM., AK. Location: Note: Target & BHL footages are based on assumed true and square sections and are not surveyed legal locations. I AFE Number: 1337040 I I Rig: [Nabors 27E I Estimated Start Date: ]May 1, 1996 I Operating days to drill and case: IMD: I10142' I ITVD: 17211' BKB [ IKBE: 161' I Well Design (conventional, slimhole, I Ultra Slimhole, 7" Longstring etc.): Formation Markers: Formation Tops MD TVD Formation Pressure/EMW Base permafrost 1837 1811 n/a NA (Top Schrader) 5854 4488 1905 psi~ / 8.0 ppg OA 1955 psig / 8.0 ppg Base Schrader Bluff 6237 4731 1995 psig / 8.0 ppg Top HRZ 8858 6396 n/a Base HRZ n/a Kupark D Shale 9512 6811 n/a Kupamk C 9827 7011 3650 psig / 10 ppg TKB 3669 psig / 10 ppg Total Depth 10142 7211 n/a Casinl,,/Tubing Program: Hole Csg/ Wt/Ft Grade Conn Length Top Btm Size Tbg MD/TVD MD/TVD O.D. I 30" 20" 91.1# NT80LHE weld 80 32' 112/112 12 1/4" 9 5/8" 40g L-80 btrc 5844' 31' 4299/3500 8 1/2" 7" 26# L-80 Mod B 10112' 30' 10142/7211 N/A (tbg) 2-7/8" 6.5# L-80 EUE 9483' 29' 9512/6811 8rd Internal yield pressure of the 7" 26g casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at 7529' TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3758 psi is 3005 psi, well below the internal yield pressure rating of the 7" casing. The Modified Buttress 7" 26g will be run on bottom. Logging Pro [Open Hole Logs: ,ram. Surface MWD ONLY Schrader Bluff Final LWD GR/Resistivity/SFC CSG to TD CDN over Kupamk intervals [Mud Logs: Mud logs and samples are not required API# 50-029-22xxx MPK-02 (96F) April 18, 1996 Mud Program: Special design considerations Hydrates 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 the updated pad data sheet are encouraged. We will have hydrates on K Pad. We will have our mud weight to 11 PPG by 2000 feet. We will weight up in 0.5 ppg increments as necessary. We will use the coldest mix water available to minimize warming if the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to below 600 GPM when hydrates are ~resent to keep mud temperatures to a minimum. Surface Mud Properties: [Spud Mud 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 11.5 100 35 15 30 10 15 Production Mud Properties: ]LSND Density Marsh Yield 10 see 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 10.5 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: [KOP: ] 1000' Maximum Hole Angle: Maximum Dog Leg: Inclination in target: Close Approach Well: I 50.57 degrees _< 4 degrees 50.57 Degrees MPK 5 Well Plan is 106 feet @ 750 feet TVD This wellplan will allow MPK-02 wellpath to be drilled as per BP's close approach guidelines. The well path should be followed as close as possible to ensure we do not compromise the proximity tolerances. Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) 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. RECE.IVED APR 1 8 199G Alaska Oil & Gas Cons. Can]mission Anchorage AP1 # 50-029-22XXX MPK-02 (96F) April 18, 1996 Request for AOGCC Approval Disposal of Drilling Wastes (20AAC25.254) 1. Approval is requested for Annular Pumping for K Pad well MPK-02 to be drilled, and any well on the pad/drillsite previously permitted for disposal activities by AGOCC. 2. The Base of the Permafrost for all wells located in the Milne Point Unit is 1750 feet. Aquifers in the Milne Point Unit have been exempted from Class II injection activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. 3. The receiving zone to which the fluids will migrate is identified as the Prince Creek geological formation at 2500 - 3300' TVD. The confining layer is the Sagavanirktok Shale defined by logs between _ 2150 to _ 2500 'TVD. Additional data which demonstrates the confining layers, porosity, and permeability of the injection zone was submitted to the AOGCC on 7-24-95. 4. There are no wells on Milne Point K Pad. There may be additional unidentified wells within a quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The drilling wastes to be disposed of during this operations can be defined as drilling mud, cement contaminated drilling mud, and drill cuttings; rig wash fluid (inclusive of rig boiler blow down, and mud and cement rinse water of associated rig equipment, completion fluids (seawater and brine), formation fluids, reserve pit fluids, and drill rig domestic waste water. (Note: if you plan to dispose of fluids OTHER than those outlined above you must list them on the request) The maximum volume to be disposed of in the annulus is 35,000 bbls. Fluid densities will range from 8.3 to 13.0 ppg. Any deviation from this program must be detailed separately. 6. The 9.625" surface casing shoe will set at 3659'md 3523 ('tvd) and cemented with 703 "E" and 250 "G" sacks cement. This depth is below the base of the permafrost (1750' TVD) and into the top of the Prince Creek formation which has a long established history of annular pumping at Milne Point. The break down pressure of the Prince Creek formation is 13 to13.5 ppg equivalent mud weight. 7. The burst rating (80%) for the 9.625" 40# 'surface casing is 4600 psi. The collapse rating (80%) for the7" 26# 'intermediate/production casing is 4325 psi. 8. The Maximum Allowable Surface Pressure while annular pumping is the lesser of 2000 psi or the calculated pressure according to the following equation: MASP (psi) = (Max Breakdown ppg-8.3 ppg) X 0.052 X Surf Csg Shoe TVD MASP (psi) = 952 psi 9. The maximum pressure imposed at the surface casing shoe is calculated according to the following equation: Max Press @ Surf Csg Shoe (psi) = .052 x Max Breakdown ppg x Surf Csg Shoe TVD D E IV Max Prss at Surf Csg Shoe =2473 psi t"~ E IJ This pressure is less than the 80% burst and collapse casing pressures calculated in #7. 1 0. Additional data supplied as needed. DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. AREA WELL PREV VOL PERMITTED PERMITTED DATES INJECTED (BBL) VOL (BBL) Milne Point M PK-02 0 35000 Requested Milne Point MPK-17 10130 35,000 2/16/96 - 2/16/97 Milne Point MPK-25 0 35,000 2/15/96 - 2/15/97 Milne Point MPK-18 0 35,000 3/7/96 - 3/7/97 Milne Point MPK-37 0 35,000 4/12/96 - 4/12/97 Milne Point MPK-38 0 35,000 2/15/96 - 2/15/97 Milne Point MPK-10i 0 35,000 3/13/96 - 3/13/97 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. AP1 # 50-029-22XXX MPK-02 (96F) April 18, 1996 DRILLING HAZARDS AND RISKS: See both the NEW Milne Point K-Pad Data Sheet prepared by Pete Van Dusen for information on the Cascade wells , and review recent wells drilled on E Pad. Most of the trouble time on recent wells has been due to equipment mechanical problems with the surface equipment, rather than formation drilling problems. Hydrates We will have hydrates on K Pad. We will have our mud weight to 11 PPG by 2000 feet. We will weight up in 0.5 ppg increments as necessary. We will use the coldest mix water available to minimize warming if the interval. We will use only 8" directional motors to allow lower flow rates. We will control flow rates to below 600 GPM when hydrates are present to keep mud temperatures to a minimum. The MPU PE group will be perforating, 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: The Kuparuk sands and a number of shallower intervals typically are highly fractured. Be prepared to treat these losses while drilling initially with LCM treatments. This will become even more prevalent in the production hole when we shallow set surface casing. Weighting up before entering the reservoir will be the most likely time we would lose circulation. Stuck Pipe Potential: There has been several cases of stuck pipe occuring at the top of the Kuparuk, with both the intervals above and below the Schrader Bluff open. We have made improvements to the mud system and continue to monitor for stuck pipe conditions. The stuck pipe intervals and shod trip guidelines on the Pad Data Sheet should be followed to avoid stuck pipe incidents. Running casing should be as smooth and quickly as possible to avoid stopping casing and possibly getting stuck. Shallow Set Casing: The wells at K Pad will use shallow set casing which can provide cost savings if the wells are trouble free. There are increased risk for stuck pipe, lost circulation, especially while running casing. The casing program will include running centralizers over both the Kuparuk and Schrader Bluff, and cemented in a single stage. The rig team will need to be more careful on these wells to fully realize the cost benefits. Kick Tolerance: The surface casing setting depth for this well allows a kick tolerance of 38.8 bbl influx (Gas) based on a 12.5 ppg LOT at the 9-5/8" casing shoe and a estimated reservoir pressure of 3708 psig (9.9 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 9.9 ppg EMW (3708 psi @ 7131' ssTVD). There has been no injection in this region since then, therefore the reservoir pressure should not exceed this estimate. We will continue to take the conservative approach to circulate the well until stable before tripping or before running casing. 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. AP1 # 50-029-22XXX MPK-02 (96F) April 18, 1996 EXCEPTIONS AND ADDITIONS TO RECOMMENDED PRACTICES: A) Recommended Practices for Drilling Surface Hole: 6. Land the surface casing and DO NOT attempt to reciprocate surface casing. 8.h if surface casing sticks off bottom and does not permit landing the casing hanger, use the FMC emergency slips and slip setting procedure. Pull 200 klbs tension when setting slips. 14. Conduct a stripping drill after testing BOP stack, while RIH with 8-1/2" bit to drill out 9- 5/8" surface casing. See Stripping Drill instructions in Appendix: B ) Recommended Practices for Production Hole: . 10. 10.h The Rig Supervisor should be on the rig floor as the Kuparuk sands are penetrated. Perform a flow check after penetrating each sand (C, B and A). The maximum PU weight while reciprocating for this type of production casing (7", 26#. L-80, BTC) is 480,000#, this is 80% of the tube strength (joint strength is higher). The cement will be displaced with source water. Ensure lines from mud pumps to the cement head have been flushed clean with clean source water and that the source water has been filtered to 2 microns. Tail in the cement displacement with sufficient diesel to place the diesel/source water interface @ 2100' TVD when the displacement is shut down (plug bumped). This eliminate the need to PU and RIH with 3-1/2" DP tp 2100' TVD to freeze protect the well. It is very important that we drain all the mud out of the stack proir to backing out the 7" Landing joint. Recent wells have found mud in the production casing which had come from either the cement displacement or from the stack after the cement job. We are committed to leaving a clean wellbore for the completion operation. If production casing sticks off bottom and does not permit landing the casing hanger, proceed as follows: Utilize the 7" emergency hanger kit. Set the emergency slips with + 250,000 lbs of tension. Use the modified FMC pack-off to make up the tubing head adapter. RECEIVED AP1 # 50-029-22XXX MPK-02 (96F) April 18, 1996 MP K-02 Proposed Summary of Operations . Drill and Set 20" Conductor. Weld an FMC landing ring for the FMC Gen 5A 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 12-1/4" surface hole to 4299' md (3500' tvd). Use extreme care when drilling through the known hydrate interval down to _+ 3100 feet TVD. 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). Test 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. cumulative volume for LOT test for well f'fle. Follow Pad Data Sheet short trip guidelines. 10. Drill 8-1/2" hole to TD at 10142' MD (7211' TVD). (Note: This hole section will be logged with LWD Triple Combo (GR/Res/Neu/Dens). 12. Pull Wear Bushing, and Change Pipe Rams to 7". Run and Cement 7" casing with 1 stage cement program and displace with water and brine. Test casing to 3500 psi and freeze protect wellbore to 2000' TVD with diesel. Closely monitor casing running loads for drag. 13. ND BOPE and NU dry hole tree. Release rig to next well. Note: This well will be perforated, and cleaned out with a completion rig and prior to running the ESP completion. 14. MIRU workover completion unit. ND dry hole tree. NU BOPs and test. 15. PU and RIH with 3.5" DP and 6" bit, clean out to PBTD. TOOH. 16. PU and RIH with perforating string (procedure to be distributed later with perforation intervals). 17. PU and RIH with 2-7/8" EUE 8rd tubing with Electric Submersible Pump (ESP) completion. 18. Set 2 way check. ND BOPE and NU tree and test. Pull two way check, freeze protect, set BPV, close valves. Test tree. 17. RI)MO with workover/completion rig. RECEIVED POST , APR 1 8 1996 RIG WORK Alaska 0il & (~as Cons. A,,c mrog.~. 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. , 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 and clean out this well with a pulling unit. API# 50-029-22XXX MPK-02 (96F) April 18, 1996 MPK,02 WELL 9-5/8" SURFACE CASING CEMENT PROGRAM - HALLIBURTON CASING SIZE: 9-5/8" CIRC. TEMP 80 deg F at 4000' TVDSS. SPACER: 70 bbls NSCI Spacer weighted to 12 ppg LEAD CEMENT TYPE: Type E Permafrost (200% excess over annular hole volume) ADDITIVES: Retarder WEIGHT: 12.0 ppg YIELD: 2.17 ft3/sx MIX WATER: 11.63 gal/sk APPROX #SACKS: 650 THICKENING TIME: Greater than 4 hfs at 50° F. TAIL CEMENT TYPE: Premium G (30% excess over annular hole volume) ADDITIVES: 0.2% CFR-3, 0.2% Halad-344, 2.0% CaC12 WEIGHT: 15.8 ppg APPROX #SACKS: 914 FLUID LOSS: 100-150 cc YIELD: 1.15 fi3/sx MIX WATER: 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER: 0 CENTRALIZER PLACEMENT: 1. 1 TURBULATOR centralizer per joint of 9-5/8" casing on the bottom 10 joints above the FS. 2. 1 TURBULATOR centralizer per joint of 9-5/8" casing from 2000 to 2500 feet. OTHER CONSIDERATIONS: This well is being drilled after MPK-25 was suspended following problems with the surface casing job. We cannot stress the importance of getting a sucessful cement job on the well. There are changes to the spacer, cement volumes and centralizer program on this well. If the cement falls back, we will do a wellhead stability cement job. 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. 1Vlix slurry on the fly -- batch mixing is not necessary. Make sure to fill the casing every joint to avoid having to shut down to fill the casing. Casing has been stuck while the rig was shut down filling only 5 joints. THE RIG SHOULD BE PREPARED TO HANDLE CEMENT RETURNS AT THE SURFACE. CEMENT VOLUME: 1. The Tail Slurry volume is increased to 623 sacks is calculated to cover the 9-5/8" to 1800 feet with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints is 6 BBL. AP1 # 50-029-22XXX MPK-02 (96F) April 18, 1996 MPK-02 7" PRODUCTION CASING CEMENT PROGRAM- HALLIBURTON STAGE I CEMENT JOB ACROSS THE KUPARUK and SCHRADER BLUFF: CIRC. TEMP: 115° F BHST 120 deg F at 7040' TVDSS. SPACER: 50 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: 0.3% CFR-3, 30#/SK Silicalite, 1.7% Halad 344 WEIGHT: 12.25 ppg YIELD: 2.81 cu fffsk APPROX # SACKS: 3 93 FLUID LOSS: < 45cc/30 min @ 140° F MIX WATER: 16 gal/sk THICKENING TIME: 4 1/2 hrs @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: 1. 7"x 8-1/4" Straight Blade Rigid Centralizers-- two per joint across the Kuparuk Sands from 9512 - 10142(30 total). This will cover 200' above the C Sand. 2. 7"x 8-1/4"Straight Blade Rigid Centralizers-- two per joint from 5855' - 6237' to cover the Schrader Bluffs Sands (32 Total). 3. Run one 7" x 8-1/4"Straight Blade Rigid Centralizer inside the 9-5/8" casing shoe. 4. Total 7" x 8-1/4" Straight Blade Rigid Centralizers needed is 63. 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. Batch mixing is not necessary. CEMENT VOLUME: 1. Stage 1 cement volume is calculated to cover 500' md above the NA Top with 30% excess. RECEIVED APR '1 8 1996 Alaska Oil & Gas Con,'~. Commission Anchorage AP1 # 50-029-22XXX MPK-02 (96F) April 18, 1996 MPK-2 Cement Calculator Milne Point Cement and Centralizer Calculations Well MPK-2 Surface (1 Stage) Cement Job cement Type E G Hole Size 12.25 Yeild (cfs) 2.17 1.15 Casing Size 9.625 Weight (ppg) 1 2 15.8 BPF 0.0558 BPF + 30% 0.0725 BPF + 150% 0.1395 Depth BBLS Cu. Ft. Sacks ToD of Cemen' Shoe Depth ~ Calculated G Tail Volume 2499 187.2 1051 914 1800 E Lead Volum6 1800 251.0 1409 650 Surface Total E 6 5 0 Total G 91 4 9-5/8" Bows I 0 Production 1-Stage Cement Job Cement Yield Hole Size 8.5 Silicalite Slurry 2.05 Casing Size 7 BPF 0.0226 BPF + 30% 0.0294 Top of Cemenl Stage I IVD BBLS Cu. Ft. Sacks Calculated NA Top ~~ 1 44 806 393 5355 Seabee Top Kuparuk Top Centralizers 3 0 Across the Kuparuk Centralizers 32 Across the Schrader Bluff Total G ST1 393 Total ST Blade~ 6 3 RECEIVED APR '1 8 199G Alaska 0il & Gas Cons. Ccmmission Anchorage Page 1 !CDO 1811 8000-- 4731 5000-- 6396 6500-- ~11 7211 Set'vi( Dr',iLLing PLo, ne: ? ~>o,s VERTICAL VIEW SCALE ~ Ft, / DMS]]]q TVD REF: WELLHEAD VERTIC~ S~ECTION REF: VEl_LIE:AD , 0.03 ~ 0 ND TIE IN HURIZ~TAL VIEW (TRU~JRIt t) SCALE 500 r-t, / DI~I[]N SURVEY REF: WEL~D t tAI. I. I ttLJl,~ I[ N 4/16/g6 910 pm 45CD 4CDO 3500 3800 L:500 ~ 1500 IOCD 5(]0 0 500 CRITICAL P0]NT DATA MD Inc Azi, TV]] N/S ~ 0.~ ~ 1~ ~ ~ / ST~T ~ ~ ~ 3,~/1~ P~ T~ ~ 0 0.~ ~1.51 0 0 N 0 E 0 ~ / ST~T 1~ 0.~ ~I,51 1~ 0 N 0 E 6.~ 1~ ~~ ~ 12.~ ~ 1~ ~ ~ i~ ~.13 ~1,51 1Bll 141 N 112 W ' ~ ~ ~D ~ ~.~ ~1,51 24~ ~5 N ~ ~ 18~ ~ 1~ ~ 4 k ........... ~ ~ [ ~,~ ~1.51 ~ 2~1 N 1~ W ~ ~ m ~ ~ ~ ~12 ~.57 ~1.51 ~11 ~72 N 37t6 W ~'~ = ~ "~ - K~ / ~1 ~ ~,57 ~1,51 7011 ~ N ~Z ~ 697 ~ ' I 9 5/8 m ~, ~ ~ ~ ~ ~ ~ J ~ ~ bc ~ ~ ~S E~ 3t45 -500 0 500 1000 1500 2OC~ 2500 3500 4000 4500 5030 5500 6000 6500 VERTICAL SECTION Ft~N~iD 321,51 TVD 72t t ,CD ~ 10142,07 vs 6456,17 N/S 5(]53,15 N E/W 4018,43 W Halliburton Energy Services - Drilling Systems PSL Proposal Report Pagel Tune: 3:12 pm Weilimh 1D: MPK.02 WpI Lint R~ 4/16t96 Smvey Reference: WELLHEAD Reference World Coordinales: Lat. 70.25.34 N - Long. 149.18.41 W Refenmce GRID Sys~ran: Alaska Stole Plane Zone: Alaska 4 Refenmce GRID Coordinales: (ft): 6005935.75 N 584512.26 E North Aligned To: TRUE NORTH Vertical Sectioo Reference: WFJJ J-IF_,AD Closure R~: WFJ-I-HEAD Calculated using the Minimum Curvature Method Computed using WIN-CADD$ REV2.2.1 Vertical Section Plane: 321.51 deg. BPX - Shared Services Drilling Alaska State Plane: Zone4 Miine Pt: MPK MPK-02 Est MPK-02 Wpl Feas Measur~ Inci Drift Subsea TVD Course T O T A L (ft) (deg.)(deg.) (ft) (ft) (fl) (ft) (fi) GRID Coordinalm (ft) (f0 TIE~ 0.00 0.00 0.00 61.00 0.00 0.00 0.00N K~I~TOFBUR.DO3.00deg/100ft 1000.00 0.00 0.00 939.00 1000.00 1000.00 0.00N 1100.00 3.00 321.51 1038.95 1099.95 100.00 2.~N 0.00E 6005935,76 584512,26 0.00E 6005935.76 584512.26 !.63W 6005937.79 584510.61 Closure Vertical Build Walk DIS Cum. Expected Total Max Hot Mitt Hot~ ~. Vm Surv~ Tool Di~ Dh'. Section Rate Rate Dogleg Rectangular Coords l~ror F,n~!~..':l~ Errm' (ft) (deg.) (ft) (dg/100ft) (dg/100ft) (dg/t00ft) (deg) (ft) (ft) (ft) (ft)~' (d~.) (1~) 0.0C@ 0.00 0.00 0.00 0.00 0.00 0.0 0.00N 0.00 E 0.00 0.00 .0 00 0.00 ~-PBD , .'~ 0.0CO 0.00 0.00 0,00 0.00 0.00 0.0 0.00N 0.00E 3.17 ~.~,~77 '0.00 1.41 BPltM~D 2,620 321.51 2.62 3.00 0.00 3.00 3.0 2.04 N 1.64W 3.38 51__51 1.56 BPltM-PBD 1200.00 6.00 321.51 1138.63 1199.63 100.00 8.19N 6.51W 6005943,87 584505,66 10.4~O321.51 10.46 1300.00 9.00 32131 1237.77 1298.77 100.00 18.40N ,14.64W 6005953.99 584497.42 23.510321.51 23.51 1400.00 12.00 321.51 1336.08 1397.08 100.00 32.67N i25.98W 6005968.12 584485.92 41.74@321"51 41.74 3.00. 0.00 3.00 0.00 3.00 0.00 3.00 6.0 8.16 N 6.55W 3.63 3.58 5 !.51 1.74 BPHM-PBD 3.00 9,0 18.31N 14.75W 3.97 3.79 51"51 1.92 BPHM-PBD 3.00 12.0 32.47N 26.Z2W 4.44 4.01 51.51 2.13 BPHM,-i~D 1500.00 15.00 32131 1433.31 1494.31 100.00 50.93N 40.5CW 6005986,23 584471.18 65.04@321.51 65.08 1600.00 18.00 321.51 1529.18 1590.18 100.00 73.16N 58.1trw 6006008.25 584453.26 93.480321.51 93.48 1700.00 21.00 321.51 1623.43 1684.43 100.00 99.29N 78.95W 6006034.13 584432.19 126.850321.51 126.85 3.00 3.00 3.00 0.00 0.00 0.00 3.00 15.0 50.58 N 40.95W 5.09 4.23 51.51 236 BPliM-PBD 3.00 18.0 72.58N 58.91W 5.96 4.47 51.51 2.62 BPHM-PBD 3.00 21.0 98.40 N 80.0COW 7.07 4.7 i 51"51 2.90 BPHM-PBD 1800.00 24.00 321.51 1715.81 1776.81 100.00 129.23N 102.77W 6006063.81 584408.04 165.120321"51 165.12 1837.59 25.13 321.51 1750.00 1811.00 37.59 141.47N !!2.5CW 6006075.93 584398.18 180.74~321.51 180.74 1900.00 27.00 32131 1806.06 1867,06 62.41 162.93N 129.5t~V 6006097,19 51M380.g7 208.1~'1.51 208.16 3.00 3.00 0.00 0.00 3.00 24.0 127.96N 104.3'/W 8Al 4.9~ 51..51 3.21 BPHM-PBD 3.00 25.1 140.03N 114.3CW 8.96 5.~.~::i51.51 3.34 I~-I~D 3.00 27.0 161.19N 131.75'W 9.96 5.:~i~' 51"51 3.56 BPHM-I~D 2000.00 30.00 321.51 1893.93 1954.93 100.00 200.27N 159.2CCW 6006134.19 584350.76 255.870321"51 255.87 2100.00 33.00 321.51 1979.18 2040.18 100.00 241.16N 191.78W 6006174.71 584317.79 308.12@321.51 308.12 2200.00 36,00 321.51 2061.59 2122.59 100.00 285.49N 227.03W 6006218,63 584282.04 364.750321.51 364.75 3.00 3.00 3.00 0.00 0.00 0.00 3.00 30.0 197.94N 162.1~;W 11.79 5.56 51,51 3.94 BPHM~D 3,00 33.0 238.13N 195.5~V 13.87 5,87 51.51 4.36 BlqtM.,PBD 3.iX} 36.0 281.64 N 231.87W 16.18 6.21 51.51 4.82 BHtM-PBD 2300.00 39.00 321.51 2140.91 2201.91 100.00 333.13N 264.9IW 6006265.84 584243.62 425.62@321"51 425.62 2400.00 42.00 321.51 2216.95 2277.95 100.00 383.95N 305.33W 6006316.20 584202.64 490_~@321.51 49036 2500.00 45.00 321.51 2289.47 2350.47 100.00 437.82N 348.1'/W 6006369.58 584159.20 559.380321"51 55938 3.00 3.00 3.00 0.00 0.00 0.00 3.00 39.0 328.34N 270.93W 18.73 6"55 51.51 5.32 'BPHM-PBD 3.00 42.0 378.11N 312.6~Ar 21.51 6.90 51"51 5.87 BHIM-PBD 3.00 45.0 430.79 N 357.01W 24.53 7.26 51.51 6.46 BPHM-PBD 2600.00 48.00 321.51 2358.30 2419.30 100.00 494"59N 393.31W 6006425.83 584113,42 631.910321.51 631.91 END OF BUILD 2685.67 50.57 321.51 2414.18 2475.18 85.67 545.41N 433.7~v' 6006476.18 584072.44 696.84@321.51 696.84 CASING POINT OD = 9 5/8 in. ID = 8.84 in, Weight = 40.00 lb/ft. 4299.22 50.57 321.51 3439.00 3500.00 1613.55 1520.87N 1209.45W 6007442.80 583285.90 1943.15@321.51 1943.15 3.00 3.00 0.00 0.t30 0.00 0.00 3.00 48.0 486.25 N 403.8CW 27.77 7.62 51.51 7.10 BPHM-PBD 3.00 50.6 535.86N 445.73W 30.71 7.93 51.51 7.68 BPHM-PBD 0.00 50.6 1520.87N 1209.45W 0.00 0.00 0.00 0.00 BPHM-PBD Halliburton Energy Services - Drilling Systems PSL Proposal Report Page2 Da~e: 4/16/96 Welli~h ID: MPK-02Wpi Measm~ lncl Drift Subsca TVD Course T 0 T A L (fi) (4~g.) (deg.) (fi) (fl) (fl) (fl) (fl) GRID Coordinal~s Northing Fasting (fi) (f0 Closure Vertical Build Walk DLS Cum. F, xpecl~ Total Max Hot Min Hot Dir. Vm Dist. Dir. Section Rate Rate Dogleg RectangularCoord~ Eh-Or ~ I~xl~ ~ (f0 (deg.) (fl) (dg/10Oft) (dg/10Of0 (d~/100f0 (deS) (fl) (fi) (fl) (fi) (d~.) (~ NA S~ds 5854.79 50.57 321.51 4427.00 4488.00 1555.57 2461.29N 1957.3CW 6008374.76 582527.71 3144.67@321.51 3144.67 6237.39 50.57 321.51 4670,00 4731.00 382.60 269'2.59N 2141.2~V 6008603.99 582341.25 3440.1S@321.51 3440.19 8858.g'/ 50_57 321.51 6335.00 6396.00 2621.49 4277.40N 3401.53W 6010174.76 581063.79 5465.03~321.51 5465.03 9512.28 50.57 321.51 6750.00 6811.00 653.40 4672.42N 3715.6C~/ 6010566.30 580745.42 5969.72~321.51 5969.72 K-F/TKUC! 9827.17 50.57 321.51 6950.00 7011.00 314.89 4862.78N 3867.04W 6010755.00 580592.00 6212.95@321.51 6212.95 CASING POINT OD -- 7 in, ID = 6.28 in, Weight = 26.00 lb/fi. 10142.07 50.57 321.51 7150.00 7211.00 314.89 5053.15N 4018.43W 6010943.71 580438.58 6456.17~321.51 6456.17 Sun~'y Tool 0.00 0.00 0.00 0.00 0.00 0.00 0.00 50,6 2407.00N 2025.57W 142.05 25.01 51.51 27.53 BPHM-PBD 0.00 50.6 2632.90N 2216.2~ 155.55 27.11 51.51 30.04 BPHM-PBD 0.00 50.6 4180.70N 3523.136' 248.12 41.53 51.51 47.30 BPHM-~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 50.6 4566.49 N 3848.8C~/ 271.19 45.12 5 !.51 51.62 BPHM-PBD 0.00 50.6 4752.41 N 4005.84W 282.32 46.86 51.51 53.70 BPHM-PBD 0.00 50.6 4938.33 N 4162.81W 293.44 48.60 51.51 55.78 BPI-IM-PBD N240 t80 140 120 8O fl. \ / \ / 41~II(X~ 1:03 am B40 210 Rer TVD Sep.Fcm-tc~ 750.00 21,00 ' 04P.g9 23.60 0.00 ","~'=:~ '" '" · ,.~_ ~.., ,. STATUS t20 2t50 Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.1 Page I Date: 4/17/96 Time: 7:03 am Normal Plane Method All distances are between EXPECTED Positions Alaska State Plane: Zone4 Milne Pt: MPK MPK-02 Est MPK-02 Wp1 Feas Interval Step Depth S0.0Oft.(MD) From 0.00 To 10142.07 ft.(MD) All Directions using BP ~ide Method in Dec.Deg. All Depths and Distance ~ in FEET All distances are between EXPECTED Positions Offset Flowing Zone Flowing Shut-in Well Safe~y Min. Safety Safety Clear Spread MD TVD Dist Dist MPK-5 MWD 88.2 99.4 900 900 13.5 2.2 MPK- 17 MWD 133.0 146.1 1050 1050 15.8 2.6 MPK-18 Wp2 98.7 111.2 1000 1000 15.0 2.5 MPK-25 MWD 188.6 198.6 800 800 12.0 2.0 MPK-37 Wp3 270.7 283.2 1000 1000 15.0 2.5 MPK-38 MWD 254.7 267.2 1000 1000 15.0 2.5 CASCADE-IA 1458.9 1467.7 700 700 10.5 1.8 CASCADE-01 1458.9 1467.7 700 700 10.5 1.8 Close Approach Status Enter Enter Exit Exit Shut-in Danger Danger Shut-in Zone Zone Zone Zone MD MD MD MD Close Approach Status OK OK OK OK OK OK OK OK RECEIVED APR 1 8 199(; Alaska Oil & Gas Cons. Commission Anchorage Halliburton Travelling Cylinder Report Computed using WIN-CADDS REI/2.2.1 Page 1 Date: 4/17/96 Time: 7:03 am Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: Zone4 Milne Pt: MPK MPK-02 Est MPK-02 Wpl Feas N/S and F_./W are measured from the ~ TVD is measured from the WELLHEAD Iateaval St~ Depth 50.00 ft.(MD) From 0.00 To 10142.07 ft.(MD) All Directions using BP Highside Method in Dee. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Close Approach Status Offset Flowing Zone Flowing Shut-in Well Safety Min. Safety Safety Clear Spread MD TVD Dist Dist MPK-5 MWD 88.2 99.4 900 900 13.5 2.2 MPK-17 MWD 133.0 146.1 1050 1050 15.8 2.6 MPK-18 Wp2 98.7 111.2 1000 1000 15.0 2.5 MPK-25 MWD 188.6 198.6 800 800 12.0 2.0 MPK-37 Wp3 270.7 283.2 1000 1000 15.0 2.5 MPK-38 MWD 254.7 267.2 1000 1000 15.0 2.5 CASCADE-lA 1458.9 1467.7 700 700 10.5 1.8 CASCADE-01 1458.9 1467.7 700 700 10.5 1.8 Enter Enter Exit Exit Shut-in Danger Danger Shut-in Zone Zone Zone Zone MD MD MD MD Close Approach Status OK OK OK OK OK OK OK OK Halliburton Travelling Cylinder Report Computed using WIN-CADDS REV2.2.1 Page I Date: 4/I 7/96 Time: 7:04 am Normal Plane Method All distances are between EXPECTED Positions REFERENCE WELL: BPX - Shared Services Drilling Alaska State Plane: ZoneA Milne Pt: MPK MPK-02 Est MPK-02 Wpl Feas N/$ and FffW are measured from the WELLHEAD TVD is measured from the WELLHEAD Interval Step Depth 50.00 fl.(MD) From 0.00 To 10142.07 ft.(MD) All Directions using BP Highside Method in Dec. Deg. All Depths and Distance are in FEET All distances are between EXPECTED Positions Closest Points Slot Wellpath MPK-5 As-Built MPK-5 MWD Distance Direction Ref MD Ref TVD Sep Factor 106.81 233.70 750.00 750.00 1902.33 100.62 7550.00 5564.69 MPK-17 As-Built MPK-17 MWD 155.34 198.86 208.79 178.70 MPK-18 As-Built MPK-18 Wp2 AWD 119.62 158.50 130.31 157.04 MPK-25 As-Built MPK-25 MWD 205.56 190.10 389.79 167.69 MPK-37 As-Built MPK-37 Wp3 AWD 291.61 180.52 6275.23 170.27 MPK-38 As-Built MPK-38 MWD 270.25 158.35 636.80 148.55 CASCADE-lA CASCADE- lA 1473.54 87.16 3729.28 169.63 CASCADE-01 CAS CADE-O 1 1473.54 87.16 6973_52 137.52 1050.00 1049.99 1550.00 1542.43 21.0 5.5 23.6 20.8 0.00 0.00 31088.5 1200.00 1199.63 18.7 650.00 650.00 1800.00 1776.81 44.7 28.3 0.00 0.00 70251.7 3550.00 3024.15 32.9 0.00 0.00 25302.8 2050.00 1997.90 33.1 500.00 500.OO 6700.00 5024.82 500.00 500.00 5950.00 4548.47 377.9 9.5 377.9 36.7 RECEIVED APR '1 8 199~ Alaska Oil & G~.~ r,n,., ..:~ .... (;on-m'ussion , ; ": i' ~ ": .':: WELL PERMIT CHECKLIST redrll [] serv [] wellbore seg [] ON/OFF S~O~ ~ ~k ADMINISTRATION ENGINEERING 1. Permit fee attached ................... ~ N 2. Lease number appropriate ................ ~ N 3. Unique well name and number ............... ~ N 4. Well located in a defined pool ............. ~ N 5. Well located proper distance from drlg unit boundary. . N 6. Well located proper distance from other wells..... '9 N 7. Sufficient acreage available in drilling unit.' ' ' ' 'O N 8. If deviated, is wellbore plat included ......... ~ N 9. Operator only affected party .............. ~ N 10. Operator has appropriate bond in force ......... ~ N 11. Permit can be issued without conservation order ..... ~ N 12. Permit can be issued without administrative approval.. ~ N 13. Can permit be approved before 15-day wait ........ ~ N REMARKS 14. Conductor string provided ............... 15. Surface casing protects all known USDWs ........ 16. CMT vol adequate to circulate on conductor & surf csg. 17. CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............. 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed .......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to ~6~ pslg 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............. GEOLOGY DATE 30. Permit can be issued w/o hydrogen sulfi~ 31. Data presented on potentia~zones ..... .Y. .N. 33~. Seismic analys~as zones ......... _Y_ _N_ ontact name/phone for weekly progress reports ..... Y N [exploratory only] z z m GEOLOGY: ENGINEERING: COMMISSION: BEW DWJ TAB HOW/lib - A:\FORM~cheklist rev 11195 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. * ALASKA COMPUTING CENTER * . . ****************************** . ............................ . * ....... SCHLUFiBERGER ....... * . ............................ * COMPANY NAME : BP Exploration (Alaska), Inc. WELL NAME : MPU K-02 FIELD NAME : Milne Point BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292267500 REFERENCE NO : 98442 LIS Tape Verification Listing SJhlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: **** REEL HEADER **** SERVICE NA~E : EDIT DATE : 98/10/20 ORIGIN : FLIC REEL NAME : 98442 CONTINUATION # : PREVIOUS REEL : COf~4ENT : BP EXPLORATION, MPU K-02, MILNE POINT, API# 50-029-22675-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/10/20 ORIGIN : FLIC TAPE NA~E : 98442 CONTINUATION # : 1 PREVIOUS TAPE : COA~!ENT : BP EXPLORATION, MPU K-02, MILNE POINT, API# 50-029-22675-00 TAPE HEADER MILNEPOINT CASED HOLE WIRELINELOGS WELL NAF~E: MPU K-02 API NUFiBER: 500292267500 OPERATOR: BP EXPLORATION (ALASKA) LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 20-0CT-98 JOB NUFI~ER: 98442 LOGGING ENGINEER: C. YON OPERATOR WITNESS: L HINCKLE SURFACE LOCATION SECTION: 3 TOWNSHIP: 12N RANGE: lie FNL: FSL: 3800 FEL: 2042 FWL: ELEVATION(FT FROM MSL O) KELLY BUSHING: 61.00 DERRICK FLOOR: 60.00 GROUND LEVEL: 33.00 WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 10110.0 26. O0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:~o BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: CCL LDWG CURVE CODE: GR RUN NUPIBER : PASS NUMBER: DATE LOGGED: 08-JUL-96 LOGGING COMPANY: WESTERN ATLAS BASELINE DEPTH .............. 88888.0 10021.5 10018.5 10008.0 9998.0 9986.5 9984.0 9980.0 9978.5 9972.5 9971.5 9969.5 9964. $ 9960 5 9952 5 9950 0 9948 5 9947 0 9941 0 9931 0 9929 5 9928 0 9918.0 9908.5 9905.5 9900.5 9900.0 9897.5 9895.5 9879.5 9879.0 9876.5 9875.0 9871.5 9867.0 9861.5 9849.5 9840.0 9838.5 9836.5 9834.0 9833.5 9823.0 9811.0 9806.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88888.0 88889.0 10008.0 9996.5 9987.0 9979.0 9972.0 9961.0 9950.5 9948.5 9938.5 9933.0 9930.0 9920.5 9906.5 9900.5 9896.0 9878.5 9877.0 9874.5 9871.5 9862.0 9850.0 9839.5 9837.5 9835.0 9823.5 9811.5 10022.5 10019.0 9986.5 9979.5 9974.0 9971.5 9964.0 9952.5 9949.0 9929.5 9920.5 9910.0 9902.5 9899.0 9881.0 9867.5 9839.0 9835.5 9824.0 9808.0 PAGE: LIS Tape Verification Listing S~hlumberger Alaska Computing Center 20-0CT-1998 16:~o 9804.0 9799.5 9796.0 9795.5 9792.0 9790.5 9765.0 9758.0 9756.5 9739.5 9735.5 9732.5 9729.0 9724.0 9716.5 9714.5 100.0 $ 9804.0 9798.0 9796.5 9796.0 9792.5 9789.5 9767.0 9759.0 9757.0 9741.5 9735.0 9733 0 9730 0 9724 0 9717 0 9715 5 101 0 99.5 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE RST DATA AQUIRED ON BP EXPLORATION'S MPU K-02 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #1 AND THE CCL GAI4MA RAY, ALSO BASE PASS #1 SIGMA AND THE CCL GAF~VA RAY, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAI~E : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE iV-UMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 1 DEPTH INCREMeNT: 0.5000 FILE SUFfiVlARY LDWG TOOL CODE START DEPTH STOP DEPTH ................................... GRCH 10016.0 9715.0 RST 10028.0 9713.5 $ CURVE SHIFT DATA - PASS TO PASS (PiEASURED DEPTH) BASELINE CURVE FOR SHIFTS LIS Tape Verification Listing SJhlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REFiARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAM~ SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUIT~ SAMP ELEM CODE (HEX) DEPT FT 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 NBAC RST CPS 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 FBAC RST CPS 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SBNA FIL CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SFNA FIL CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SBFA FIL CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SFFA FIL CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 TRAT FIL 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 IRAT FIL 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing · Schlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: 5 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) CIRN FIL 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 CIRF FIL 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 BSALRST PPK 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SIBF RST CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 TPHI RST PU-S 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SFFC RST CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SFNC RST CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 SIGM RST CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 DSIG RST CU 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 FBEF RST UA 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 CRRARST 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH RST GAPI 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 TENS RST LB 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 CCL RST V 1160731 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10028.000 NBAC. RST 2391.622 FBAC.RST 3128.822 SBNA.FIL SFNA.FIL 31.280 SBFA.FIL 47.198 SFFA.FIL 29.010 TRAT. FIL IRAT. FIL 0.475 CIRN. FIL 0.734 CIRF. FIL 1.377 BSAL.RST SIBF. RST 43.788 TPHI.RST 40.053 SFFC.RST 25.882 SFNC.RST SIGM. RST 25.843 DSIG.RST 1.843 FBEF.RST 66.748 CRRA.RST GRCH. RST -999.250 TENS.RST 2839.000 CCL.RST 0.003 DEPT. 9713 500 NBAC.RST 2479.004 FBAC.RST 3101.646 SBNA.FIL SFNA.FIL 40 576 SBFA.FIL 49.864 SFFA.FIL 41.478 TRAT. FIL IRAT. FIL 0 459 CIRN. FIL 0.528 CIRF. FIL 0.872 BSAL.RST SIBF. RST 40 341 TPHI.RST 48.921 SFFC.RST 38.969 SFNC. RST SIGM. RST 39 000 DSIG.RST 0.960 FBEF.RST 69.194 CRRA.RST GRCH.RST -999 250 TENS.RST 2741.000 CCL.RST 0.020 53.788 1.128 60.992 28.141 2.043 57.678 1.336 51.568 39.807 2.044 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .001 SERVICE ' FLIC VERSION : O01COi DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing SJhlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: **** FILE HEADER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIFiBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NI374~ER: 2 DEPTH INCREFiENT: 0.5000 FILE SD?4~L~RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10015.0 9736.0 RST 10027.5 9736.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS 1VUFiBER: 1 .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH RST 88888.0 88887.0 88888.5 10021.5 10022.0 10018.0 10019.0 10002.0 10002.0 9997.5 9996.5 9999.5 9986.5 9987.0 9985.0 9985.0 9984.5 9986.5 9979.0 9979.0 9979.5 9977.0 9978.0 9973.0 9974.5 9970.0 9971.5 9965.0 9964.5 9959.5 9959.0 9959.0 9959.0 9952.5 9952.5 9949.0 9950.5 9947.5 9949.0 9936.5 9938.0 9933.0 9933.0 9929.5 9929.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: 9928.5 9929.5 9925.0 9925.5 9919.0 9920.5 9920.5 9914.0 9916.0 9906.0 9906.5 9904.5 9906.0 9900.0 9902.5 9898.0 9900.5 9899.0 9879.5 9881.0 9876.5 9877.0 9874.5 9874.0 9874.0 9875.0 9867.5 9867.5 9864.0 9864.5 9862.0 9862.0 9857.5 9857.5 9854.5 9856.5 9850.5 9850.0 9843.0 9842.5 9840.0 9839.5 9834.5 9835.5 9833.5 9834.5 9824.5 9823.5 9812.0 9812.0 9805.5 9805.5 9801.5 9800.0 9796.5 9796.0 9794.0 9796.0 9791.5 9794.0 9771.0 9771.5 9763.0 9764.0 9754.5 9756.5 9739.5 9741.5 100.0 102.0 102.0 REMARKS: THIS FILE CONTAINS CASED HOLE RST BASE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH BASE PASS #2AND GRCH BASE PASS #1, ALSO SIGMA BASE PASS #2ANDSIGMABASE PASS #1, CARRYING ALL RST CURVES WITH THE SIGMA SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Sc'hlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELaM CODE (HEX) DEPT FT 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 BSALRST PPK 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SFFC RST CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 SIGM RST CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST CU 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 CRRARST 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1160731 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing S~hlumberger Alaska Computing Center 20-0CT-1998 16:~u PAGE: ** DATA ** DEPT. 10027.500 NBAC.RST SFNA.FIL 30.768 SBFA.FIL IRAT. FIL 0.479 CIRN. FIL SIBF.RST 40.130 TPHI.RST SIGM. RST 26.175 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 9736.000 NBAC.RST SFNA.FIL 39.945 SBFA.FIL IRAT. FIL 0.489 CIRN. FIL SIBF. RST 41.465 TPHI.RST SIGM. RST 39.923 DSIG.RST GRCH. RST 65.209 TENS.RST 2169.340 FBAC.RST 41.983 SFFA.FIL 0.734 CIRF. FIL 39.443 SFFC. RST 1.899 FBEF. RST 2813.000 CCL.RST 2319.073 FBAC.RST 47.251 SFFA.FIL 0.548 CIRF. FIL 49.553 SFFC.RST 0.560 FBEF. RST 2752.000 CCL.RST 3045.035 SBNA.FIL 29.155 TRAT. FIL 1.356 BSAL.RST 26.142 SFNC.RST 65.782 CRRA.RST 0.000 2952.763 SBNA.FIL 42.502 TRAT.FIL 0.825 BSAL.RST 39.935 SFNC.RST 67.958 CRRA.RST -0.124 54.266 1.131 50.990 27.839 1.988 57. 869 1. 362 54. 655 38. 944 2.016 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER: 3 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS RST 1, 2, $ LIS Tape Verification Listing S~hlumberger Alaska Computing Center 20-0CT-1998 16:~ PAGE: 10 REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF BASE PASSES 1 & 2. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 NBAC RST CPS 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 FBAC RST CPS 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SBNA RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SFNA RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SBFA RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SFFA RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 TRAT RSAV 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 IRAT RSAV 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 CIRNRSAV 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 CIRFRSAV 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 BSALRSAV PPK 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SIBF RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 TPHI RSAV PU-S 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SFFC RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 SFNC RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Sc'hlumberger Alaska Computing Center 20-0CT-1998 16:eu PAGE: 11 NA~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) SIGM RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 DSIG RSAV CU 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 FBEF RSAV UA 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 CRRA RSAV 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH RST GAPI 1160731 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10028. 000 NBAC.RST 2391. 622 FBAC.RST 3128. 822 SBNA.RSAV -999. 250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT. RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999. 250 TPHI. RSAV -999. 250 SFFC. RSAV -999. 250 SFNC. RSAV -999. 250 SIGM. RSAV - 999 . 250 DSIG. RSAV - 999. 250 FBEF. RSAV - 999. 250 CRRA. RSAV -999.250 GRCH. RST - 999 . 250 DEPT. 9713. 500 NBAC.RST 2479. 004 FBAC.RST 3101 . 646 SBNA.RSAV -999.250 SFNA.RSAV -999.250 SBFA.RSAV -999.250 SFFA.RSAV -999.250 TRAT.RSAV -999.250 IRAT. RSAV -999.250 CIRN. RSAV -999.250 CIRF. RSAV -999.250 BSAL.RSAV -999.250 SIBF. RSAV -999.250 TPHI.RSAV -999.250 SFFC.RSAV -999.250 SFNC.RSAV -999.250 SIGM. RSAV -999. 250 DSIG. RSAV - 999. 250 FBEF. RSAV - 999. 250 CRRA. RSAV - 999. 250 GRCH. RST -999. 250 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT . 003 SERVICE : FLIC VERSION · O01COi DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NA~E : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Sc'hlumberger Alaska Computing Center 20-0CT-1998 16:~u PAGE: 12 FILE HEADER FILE19IIM~ER 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 10055.5 $ LOG HEADER DATA 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): STOP DEPTH 9663.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS 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): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE lO-MAY-98 8C0-609 1847 lO-MAY-98 10110.0 9714.0 10027.0 TOOL NUMBER ........... CGRS-A RST-A 8.500 10110.0 PRODUCED FLUIDS THERMAL SANDSTONE 2.65 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:4o PAGE: 13 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): 6 NEAR COUNT RATE LOW SCALE (CPS): 1 NEAR COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Western Atlas GR/CCL log dated 08-Ju1-1996. Logging interval from 10050' - 9700' PBTD tagging was deemed unnecessary by co. rep Ail depth correlations and tie-in witnessed by co. rep THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFIE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP Er,EM CODE (HEX) DEPT FT 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CS PS1 F/HR 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:~ PAGE: 14 NAi~E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NU~B SAMP ELEM CODE (HEX) TENS PS1 LB 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 NPHVPS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 NPDE PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 NSCE PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CRRA PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 NSCR PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 AQTMPS1 S 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CHV PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CPSV PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CP2V PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CM2V PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RCFR PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RCLC PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RCRC PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RCAK PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RTDF PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FPHVPS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FPDE PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FSCE PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FSCR PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 AQTF PS1 S 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SF6P PS1 PSIG 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 HVPV PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BMCUPS1 UA 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 GDCU PS1 MA 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 EXCU PS1 UA 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 NBEF PS1 UA 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF PS1 UA 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 NPGF PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FPGF PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BSTR PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BSPR PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 MARC PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 Xh~ PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 XPSV PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 XP2V PSi V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 X~42V PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RXFR PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RXLC PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 R3fRC PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RXAK PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SHCU PS1 MA 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL PSi PPK 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BSAL SIG PPK 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNPS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNFIL 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF FIL 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC PS1 CPS 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:~6 PAGE: 15 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 4 1 1 4 68 0000000000 IR_AT FIL 1160731 NBAC PS1 CPS 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA SIG CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA SIG CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA SIG CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA SIG CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA FIL CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA FIL CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA FIL CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA FIL CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM PS1 CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF SIG CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM SIG CU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT SIG 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT FIL 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 GR PS1 GAPI 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RDIX PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CRNI PSi KHZ 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CRFI PS1 B2qZ 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CTM PS1 DEGC 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 XTM PS1 DEGC 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 TAV PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 FICU PS1 AMP 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CACU PSi AMP 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BUST PSi 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 BUSP PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RSXS PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI PS1 PU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI SIG PU 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 CCLC PS1 V 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 RSCS PS1 1160731 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK.PS1 FSCE. PS1 HVPV. PS1 10040 000 1563 073 1 322 -12 201 2 000 2 079 160 954 CS.PS1 2015.525 TENS.PSi NSCE. PS1 2.634 CRRA.PS1 CHV. PS1 202.066 CPSV. PS1 RCFR. PS1 0.000 RCLC. PS1 RTDF. PS1 0.000 FPHV. PS1 FSCR.PS1 0.003 AQTF. PS1 BMCU. PS1 37.050 GDCU. PS1 2764 000 NPHV. PSl 2 022 NSCR.PS1 5 045 CP2V. PS1 0 000 RCRC. PS1 1497 804 FPDE. PS1 1 102 SF6P.PS1 60 318 EXCU. PS1 1564.943 0.088 12.209 0.000 1489.411 122.202 2.893 LIS Tape Verification Listing Sc'hlumberger Alaska Computing Center 20-0CT-1998 16:~6 PAGE: 16 NBEF. PS1 32.979 FBEF. PS1 BSTR.PS1 38.905 BSPR.PS1 XPSV. PS1 5.046 XP2V. PS1 RXLC. PS1 0.000 RXRC.PS1 BSAL.PS1 45.353 BSAL.SIG CIRN. FIL 0.722 CIRF. FIL IRAT. PS1 0.497 IRAT. FIL SFFA.PS1 30.862 SBNA.PS1 SFFA.SIG 0.648 SBNA.SIG SFFA.FIL 31.279 SBNA.FIL SFNC. PS1 30.747 SFFC.PS1 SIGM. SIG 0.519 TRAT. PS1 GR.PS1 94.211 RDIX. PSl CTM. PS1 72.510 XTM. PS1 CACU. PS1 2.612 BUST.PSi TPHI. PS1 36.049 TPHI.SIG DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XPSV. PS1 RXLC. PS1 BSAL.PS1 CIRN. FIL IRAT. PSI SFFA.PS1 SFFA. SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PSI TPHI.PS1 9700.000 1562.005 0.661 -12.211 O. 000 2. 081 161. 227 33. 963 40.543 5. 050 0.000 50 614 0 553 0 487 41 031 1 002 41 669 38 106 0 991 71 524 71.289 2.608 49.126 CS.PS1 NSCE.PS1 CHV. PS1 RCFR.PS1 R TDF. PS1 FSCR . PS1 BMCU. PS1 FBEF.PS1 BSPR. PSi XP2V. PS1 RXRC. PS1 BSAL. SIG CIRF. FIL IRAT. FIL SBNA.PS1 SBNA.SIG SBNA.?IL SFFC.PS1 TRAT. PS1 RDIX. PS1 XTM. PS1 BUST. PSI TPHI.SIG 66.691 NPGF. PS1 1.082 MARC. PSi 12.053 X~2V. PS1 0.000 RXAK. PS1 5.894 CIRN. PS1 1.317 DSIG. PS1 0.498 NBAC. PS1 57.592 SBFA.PS1 2.798 SBFA.SIG 54.695 SBFA.FIL 28.533 SIGM. PS1 1.102 TRAT. SIG 65204. 000 CRNI. PS1 72. 624 TAV. PS1 3. 000 BUSP. PS1 1 . 098 CCLC. PS1 2097.456 TENS.PSI 2.651 CRRA.PS1 201.823 CPSV. PS1 0.000 RCLC. PS1 0.000 FPHV. PS1 -0.794 AQTF. PS1 37.522 GDCU. PS1 68.549 NPGF. PS1 1.329 MARC. PSI 12.056 XM2V. PS1 0.000 RXAK. PS1 2.970 CIRN. PS1 0.854 DSIG.PS1 0.489 NBAC. PS1 55.271 SBFA.PS1 4.530 SBFA.SIG 54.224 SBFA.FIL 39.276 SIGM. PS1 1.342 TRAT. SIG 74095.000 CRNI.PS1 71. 777 TAV. PS1 3. 000 BUSP. PS1 1 . 830 CCLC. PS1 0.987 0.000 -12.241 1.000 0.725 2.685 3468.428 44.117 3.839 45.946 28.434 0.022 455.657 94.955 3.000 0.000 2721.000 2.018 5.040 0.000 1499.024 0.661 60.214 1.006 0.000 -12.240 0.000 0.562 1.104 2366.845 48.911 3 481 48 392 39 218 0 038 445 688 94 954 3 000 0 000 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS. PS1 RSCS. PS1 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS. PS1 RSCS. PS1 0.993 200.725 0.000 35.815 1.324 4019.662 33.087 0.623 33.539 38.088 2.129 1.101 225.325 2.440 8878.000 8463.000 1562.501 0.109 12.187 0.000 1490.060 123.011 2.762 0.997 200.780 0.000 36.647 0.825 3099.508 38.242 1.313 38.889 39.993 1.079 1.346 220.822 2.456 8878.OO0 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing S~hlumberger Alaska Computing Center 20-0CT-1998 16:~6 PAGE: 17 **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREglFJFT: 0.5000 FILE SUMFLARY VENDOR TOOL CODE START DEPTH RST $ LOG HEADER DATA DATE LOGGED: 10054.0 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): STOP DEPTH 9679.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAf~VA RAY RST RESERVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : lO-MAY-98 8C0-609 1847 lO-MAY-98 10110.0 9714.0 10027.0 TOOL NUMBER CGRS-A RST-A 8.500 10110.0 PRODUCED FLUIDS LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:~ PAGE: 18 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): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION 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) : 6 NEAR COUNT RATE LOW SCALE (CPS): 1 NEJU~ COUNT RATE HIGH SCALE (CPS): 3 TOOL STANDOFF (IN): REMARKS: Thank you for using Schlumberger This log was depth referenced to a Western Atlas GR/CCL log dated 08-Ju1-1996. Logging interval from 10050' - 9700' PBTD tagging was deemed unnecessary by co. rep Ail depth correlations and tie-in witnessed by co. rep THIS FILE CONTAINS THE RAW DATA FOR BASE PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:~ PAGE: 19 TYPE REPR CODE VALUE 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS2F/HR 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS2 LB 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 AQTM PS2 S 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RCAK PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS2 V 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 FPDE PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS2 S 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS2 PSIG 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 HVPV PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS2 UA 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 GDCU PS2 MA 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 EXCU PS2 UA 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NBEF PS2 UA 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 FBEF PS2 UA 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS2 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 FPGF PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS2 V 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 XPSV PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS2 V 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 XM2V PS2 V 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS2 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 RXLC PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing S~hlumberger Alaska Computing Center 20-0CT-1998 16:~o PAGE: 20 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RXAKPS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PS2 MA 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS2 PPK 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRNPS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNFIL 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 DSIG PS2 CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 FBAC PS2 CPS 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS2 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 IRAT FIL 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS2 CPS 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS2 CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS2 CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS2 CU 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 SBFA PS2 CU 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 SFNA SIG CU 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 SFFA SIG CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA SIG CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS2 CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PS2 CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PS2 CU 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 SIGMPS2 CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 TRAT PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT FIL 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS2 GAPI 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS2 KttZ 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS2 K~Z 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS2 DEGC 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS2 DEGC 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS2 AMP 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS2 AMP 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 BUST PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS2 PU 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 CCLC PS2 V 1160731 O0 000 O0 0 $ 1 1 4 68 0000000000 RSCS PS2 1160731 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing sChlumberger Alaska Computing Center 20-0CT-1998 16:46 PAGE: 21 ** DATA ** DEPT. 10040.000 CS.PS2 3035 NPDE. PS2 1558.725 NSCE. PS2 2 AQTM. PS2 0.661 CHV. PS2 201 CM2V. PS2 -12.231 RCFR.PS2 0 RCAK. PS2 0.000 RTDF. PS2 0 FSCE. PS2 2.095 FSCR.PS2 -0 HVPV. PS2 160.767 BMCU. PS2 36. NBEF. PS2 32.544 FBEF. PS2 65 BSTR.PS2 32.168 BSPR.PS2 1 XPSV. PS2 5.050 XP2V. PS2 12 RXLC. PS2 0.000 RXRC. PS2 0 BSAL.PS2 64.251 BSAL.SIG 10 CIRN. FIL 0.760 CIRF. FIL 1 IRAT. PS2 0.498 IRAT. FIL 0 SFFA.PS2 27.260 SBNA.PS2 55 SFFA.SIG 0.886 SBNA.SIG 3 SFFA.FIL 27.602 SBNA.FIL 56 SFNC. PS2 27.500 SFFC. PS2 24 SIGM. SIG 0.642 TRAT. PS2 1 GR.PS2 67.293 RDIX. PS2 55010 CTM. PS2 73.731 XTM. PS2 74 CACU. PS2 2.620 BUST. PS2 3. TPHI.PS2 34.507 TPHI.SIG 1. 659 TENS.PS2 2766.000 NPHV. PS2 646 CRRA.PS2 2.026 NSCR.PS2 339 CP5V. PS2 5.060 CP2V. PS2 000 RCLC. PS2 0.000 RCRC. PS2 000 FPHV. PS2 1499.024 FPDE. PS2 175 AQTF. PS2 0.441 SF6P. PS2 416 GDCU. PS2 59.848 EXCU. PS2 944 NPGF. PS2 0.999 FPGF. PS2 070 MARC. PS2 0.000 XHV. PS2 057 3~42V. PS2 -12.236 RXFR.PS2 000 RXAK. PS2 0.000 SHCU. PS2 504 CIRN. PS2 0.770 CIRF. PS2 462 DSIG.PS2 2.415 FBAC. PS2 496 NBAC.PS2 3545.989 SFNA.PS2 163 SBFA.PS2 40.332 SFNA.SIG 801 SBFA.SIG 6.324 SFNA.FIL 130 SBFA.FIL 45.836 SIBF. PS2 592 SIGM. PS2 24.643 SIBF. SIG 051 TRAT. SIG 0.023 TRAT. FIL 000 CRNI.PS2 450.340 CRFI.PS2 121 TAV. PS2 94.960 FICU. PS2 000 BUSP.PS2 3.000 RSXS.PS2 205 CCLC. PS2 0.001 RSCS.PS2 1562. 501 -0.117 12. 202 0.000 1486.817 120.138 2.919 0.999 200.878 0.000 35.511 1.472 4014.795 31.549 0.819 31.229 44.988 3.878 1.056 222.246 2.460 8878.O00 8463.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/20 ORIGIN : FLIC TAPE NA~E : 98442 CONTINUATION # : 1 PREVIOUS TAPE COMF~Ff : BP EXPLORATION, MPU K-02, MILNE POINT, API# 50-029-22675-00 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-0CT-1998 16:4o PAGE: 22 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE : 98/10/20 ORIGIN : FLIC REEL NA~E : 98442 CONTINUATION # : PREVIOUS REEL : COMPIENT : BP EXPLORATION, MPU K-02, MILNE POINT, API# 50-029-22675-00 * ALASKA COMPUTING CENTER * . * . ............................ . * ....... SCHLU~iBERGER ....... * COMPANY NAME : ARCO ALASKA INC. WELL NAME : D.S. 5-41 FIELD NAFIE : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUPIBER : 500292269600 REFERENCE NO : 98515 OCT 29 1998 /~aska Oil & Gas ,~n,s. Oommi~ion LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3~ PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/10/13 ORIGIN : FLIC REEL NAME : 98515 CONTINUATION # : PREVIOUS REEL : COMPIFlVT : ARCO ALASKA, INC., DS 5-41, PRUDHOE BAY, # 50-029-22696-00 **** TAPE HEADER **** SERVICE NAlVlE : EDIT DATE : 98/10/13 ORIGIN : FLIC TAPE NAME : 98515 CONTINUATION # : 1 PREVIOUS TAPE : COf4~IF2Fr : ARCO ALASKA, INC., DS 5-41, PRUDHOE BAY, # 50-029-22696-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 5-41 API NUMBER: 500292269600 OPERATOR: ARCO ALASKA INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 13-0CT-98 JOB NUlViBER : 98515 LOGGING ENGINEER: G. ELMORE OPERATOR WITNESS: WORTHINGTON SURFACE LOCATION SECTION: 32 TOWNSHIP: 1 IN RANGE: 1SE FNL: FSL: 2292 FEL: FWL: 1177 ELEVATION(FT FROM MSL O) KELLY BUSHING: 72.40 DERRICK FLOOR: 69.70 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 9986.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (f4EASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3~ BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: DTE LDWG CURVE CODE: GR RUN ~ER: PASS NUMBER: DATE LOGGED: SEP-96 LOGGING COMPANY: SCHLUMBERGER WELL SERVICES BASELINE DEPTH 88888.0 9739.5 9731.5 9710.5 9701.0 9694.0 9693.0 9673.0 9667.5 9652.0 9619.5 9617.5 9601.0 9600 0 9583 0 9581 5 9521 0 9519 5 9510 0 9509 5 9501 5 9501.0 9493.5 9493.0 9487.0 9468.0 9461.0 9460.5 9443.0 9441.5 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88887.5 88887.0 9739.0 9730.5 9730.5 9710.5 9710.5 9701.5 9701.5 9693.5 9693.5 9672.5 9672.5 9667.0 9667.0 9651.0 9651.0 9619.5 9601.0 9583.0 9521.5 9509.5 9501.5 9493.5 9487.0 9468.5 9460.5 9443.0 100.0 9619.5 9601.0 9583.0 9521.5 9509.5 9501.5 9493.5 9487.0 9468.5 9460.5 9443.0 101.5 COITTAINED HEREIN IS THE RST SIGMA MODE DATA ACQUIRED ON ARCO ALASKA, INC. WELL DS 5-41 ON 3-0-UN-98. THE DEPTH SHIFTS SHOWN ABOVE REFLECT RST SIGMA MODE PASS #1 GRCH TO THE BASELINE GAMMA RAY PROVIDED BY THE CLIENT (GR.DTE) ; AND RST SIGMA MODE PASS #1 SIGM TO GR.DTE. ALL OTHER RST SIGMA MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ $ PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3L PAGE: **** FILE HEADER **** FILE NAFIE : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~ER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS ~ER : 1 DEPTH INCREMENT: 0.5000 FILE SUB, VARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9750.0 9425.0 RST 9770.0 9425.0 $ CURVE SHIFT DATA - PASS TO PASS (f4EASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUM~ER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. REMARKS: THIS FILE CONTAINS THE CLIPPED ANDDEPTHCPRRECTEDDATA FOR RST SIGMA MODE PASS #1. NO PASS TO PASS SHIFTS WERE APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 96 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: TYPE REPR CODE VALUE 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 10 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) O0 000 O0 0 1 i 1 4 68 0000000000 DEPT FT 1175307 NBAC RST CPS 1175307 FBAC RST CPS 1175307 SBNA FIL CU 1175307 SFNA FIL CU 1175307 SBFA FIL CU 1175307 SFFA FIL CU 1175307 TRAT FIL 1175307 IRAT FIL 1175307 CIRN FIL 1175307 CIRF FIL 1175307 BSAL RST PPK 1175307 SIBF RST CU 1175307 TPHI RST PU-S 1175307 SFFC RST CU 1175307 SFNC RST CU 1175307 SIGM RST CU 1175307 DSIG RST 1175307 FBEF RST UA 1175307 CRRA RST 1175307 GRCH RST GAPI 1175307 TENS RST LB 1175307 CCL RST V 1175307 GR DTE GAPI 1175307 00 000 O0 0 1 1 1 4 68 0000000000 00 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~_ PAGE: DEPT. 9930.000 NBAC.RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST -999.250 TENS.RST DEPT. 9074.000 NBAC. RST SFNA.FIL -999.250 SBFA.FIL IRAT. FIL -999.250 CIRN. FIL SIBF. RST -999.250 TPHI.RST SIGM. RST -999.250 DSIG.RST GRCH. RST -999.250 TENS.RST -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 -999 250 FBAC.RST SFFA.FIL CIRF. FIL SFFC.RST FBEF.RST CCL.RST FBAC.RST SFFA.FIL CIRF. FIL SFFC.RST FBEF. RST CCL.RST -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST -999.250 CRRA.RST -999.250 GR.DTE -999.250 SBNA.FIL -999.250 TRAT. FIL -999.250 BSAL.RST -999.250 SFNC. RST -999.250 CRRA.RST -999.250 GR.DTE -999.250 -999.250 -999.250 -999.250 -999.250 39.810 -999.250 -999.250 -999.250 -999.250 -999.250 125.371 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NIIf4~ER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9750.0 9428.0 RST 9770.0 9428.0 $ LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: CURVE SHIFT DATA - PASS TO PASS (M~LgURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NDlVi~ER : 1 BASELINE DEPTH .............. 88888.0 9737.0 9733.5 9724.5 9717.5 9711.0 9704.5 9697.5 9693.5 9681.0 9675.0 9672.0 9668.0 9663.5 9657.5 9645.0 9636.5 9628.5 9623.5 9620.0 9606.0 9601.5 9600.5 9597.0 9596.5 9591.5 9583.0 9581.0 9562.5 9550.5 9550.0 9546.0 9521.5 9520.0 951 O. 0 9509.5 9501.5 9495.0 9492.0 9465.5 9460.5 9452.0 9443.5 9429.0 100.0 $ .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST 88888.5 88887.5 9736.5 9734.0 9724.5 9717.0 9710.5 9705.0 9698.0 9693.5 9681.0 9674.5 9672.0 9667.5 9663.0 9657.0 9644.5 9637.0 9627.5 9625.0 9619.5 9607.5 9601.0 9601.0 9596.0 9597.5 9593.0 9583.0 9582.5 9563.0 9552.0 9550.0 9547.5 9521.5 9521.5 9509.5 9509.5 9501.0 9496.0 9491.0 9464.5 9460.5 9453.0 9444.5 9430.0 99.0 1 O1.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA MODE PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #2 GRCH TO PASS #1 GRCH; AND PASS #2 SIGM TO PASS #1 SIGM. ALL OTHER RST SIGMA MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 NBAC RST CPS 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 FBAC RST CPS 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SBNA FIL CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SFNA FIL CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SBFA FIL CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SFFA FIL CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 TRAT FIL 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 IRAT FIL 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 CIRNFIL 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 CIRF FIL 1175307 O0 000 O0 0 2 1 I 4 68 0000000000 BSAL RST PPK 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SIBF RST CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 TPHI RST PU-S 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: NA~E SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP EL~4 CODE (HEX) SFFC RST CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SFNC RST CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 SIGMRST CU 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 DSIG RST 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 FBEF RST UA 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 CRRA RST 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH RST GAPI 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 TENS RST LB 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 CCL RST V 1175307 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 9769.500 NBAC.RST 2192.174 FBAC.RST 3530.158 SBNA.FIL SFNA.FIL 17.181 SBFA.FIL 34.932 SFFA.FIL 15.208 TRAT. FIL IRAT. FIL 0.503 CIRN. FIL 1.474 CIRF. FIL 2.908 BSAL.RST SIBF. RST 25.464 TPHI.RST 28.453 SFFC.RST 12.707 SFNC.RST SIGM. RST 12.722 DSIG.RST 1.561 FBEF.RST 67.629 CRRA.RST GRCH. RST -999.250 TENS.RST 1104.000 CCL.RST 0.000 DEPT. 9427.000 NBAC.RST -999.250 FBAC.RST -999.250 SBNA.FIL SFNA.FIL -999.250 SBFA.FIL -999.250 SFFA.FIL -999.250 TRAT. FIL IRAT. FIL -999.250 CIRN. FIL -999.250 CIRF.FIL -999.250 BSAL.RST SIBF. RST -999.250 TPHI.RST -999.250 SFFC.RST -999.250 SFNC.RST SIGM. RST -999.250 DSIG.RST -999.250 FBEF.RST -999.250 CRRA.RST GRCH. RST 30.613 TENS.RST -999.250 CCL.RST -999.250 46.779 1.003 9.632 13.673 1.995 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAM~ : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: **** FILE HEADER **** FILE NAi~E : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILENIIf4~ER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NU~ER : 3 DEPTH INCRE~T : 0.5000 FILE SUR~b%RY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 9750.0 9425.0 RST 9770.0 9425.0 $ CURVE SHIFT DATA - PASS TO PASS (FiEASUR-F~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUM~ER: 1 BASELINE DEPTH 88888.0 9737.5 9724.5 9717.0 9708.5 9697.0 9681 0 9674 5 9667 5 9664 0 9651 0 9645 0 9636 0 9624.5 9623.5 9609.0 9603.5 9600.5 9583.0 9581.0 9567.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH RST .............. 88888.0 88887.0 9724.5 9708.5 9674.5 9667.5 9650.5 9636.5 9624.5 9609.0 9601.0 9583.0 9567.5 973 6.5 9716.5 9698.0 9681.0 9663.5 9644.5 9625.0 9605.0 9582.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3~ PAGE: 10 9550.5 9550.0 9552.0 9527.5 9529.5 9521.0 9521.5 9519.5 9521.5 9510.0 9509.5 9509.5 9509.5 9501.0 9501.5 9495.0 9496.0 9486.5 9487.0 9482.0 9482.0 9467.0 9467.5 9460.0 9460.5 9449.0 9450.5 9442.0 9443.0 9441.0 9443.0 9433.0 9434.0 9429.0 9430.0 100.0 101.0 101.0 $ REMARKS: THIS FILE CONTAINS THE CLIPPED AND DEPTH CORRECTED DATA FOR RST SIGMA MODE PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT PASS #3 GRCH TO PASS #1 GRCH; AND PASS #3 SIGM TO PASS #1SIGM. ALL OTHER RST SIGMA MODE CURVES WERE CARRIED WITH THE SIGM SHIFT. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 92 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 1i 66 11 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~v PAGE: 11 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUmB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1175307 O0 000 NBAC RST CPS 1175307 O0 000 FBAC RST CPS 1175307 O0 000 SBNA FIL CU 1175307 O0 000 SFNA FIL CU 1175307 O0 000 SBFA FIL CU 1175307 O0 000 SFFA FIL CU 1175307 O0 000 TRAT FIL 1175307 O0 000 IRAT FIL 1175307 O0 000 CIRNFIL 1175307 O0 000 CIRF FIL 1175307 O0 000 BSALRST PPK 1175307 O0 000 SIBF RST CU 1175307 O0 000 TPHI RST PU-S 1175307 O0 000 SFFC RST CU 1175307 O0 000 SFNC RST CU 1175307 O0 000 SIGMRST CU 1175307 O0 000 DSIG RST 1175307 O0 000 FBEF RST UA 1175307 O0 000 CRRARST 1175307 O0 000 GRCH RST GAPI 1175307 O0 000 TENS RST LB 1175307 O0 000 CCL RST V 1175307 O0 000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 9769.000 NBAC.RST 2297.683 FBAC.RST 3803.377 SBNA.FIL SFNA.FIL 17.190 SBFA.FIL 36.144 SFFA.FIL 15.054 TRAT. FIL IRAT. FIL 0.498 CIRN. FIL 1.445 CIRF. FIL 3.027 BSAL.RST SIBF. RST 22.408 TPHI.RST 25.111 SFFC.RST 12.595 SFNC.RST SIGM. RST 12.625 DSIG.RST 1.023 FBEF.RST 69.322 CRRA.RST GRCH. RST -999.250 TENS.RST 1112.000 CCL.RST 0.000 DEPT. 9426.000 NBAC.RST 2248.222 FBAC.RST 3551.775 SBNA.FIL SFNA.FIL 17.078 SBFA.FIL 34.650 SFFA.FIL 15.502 TRAT. FIL IRAT. FIL 0.700 CIRN. FIL 1.375 CIRF. FIL 2.614 BSAL.RST SIBF. RST 16.625 TPHI.RST 8.095 SFFC.RST 12.116 SFNC.RST SIGM. RST 12.197 DSIG.RST -2.016 FBEF.RST 41.778 CRRA.RST GRCH. RST 33.549 TENS.RST 1103.000 CCL.RST 0.003 42.742 0.970 0.732 13.560 2.036 42. 939 O. 751 -16.410 9.916 1. 468 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 13~0CT-1998 16:~o PAGE: 12 **** FILE TRAILER **** FILE NAFiE : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : 001C01 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER: 4 AVERAGED CURVES Pulsed Neutron: Unaveraged edited Pass 1 Gamma Ray and backround counts; arithmetic average of edited static baseline passes for all other curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS--ERS .......................... 1, 2, 3, RST $ REMARKS: THE ARITHMETIC AVERAGE WAS CALCULATED AFTER CLIPPING AND DEPTH CORRECTIONS WERE APPLIED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 84 4 66 1 5 66 6 73 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3o PAGE: 13 TYPE REPR CODE VALUE 7 65 8 68 0.5 9 65 FT 11 66 12 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~iE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELE~ CODE (HEX) DEPT FT 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 NBAC RST CPS 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 FBAC RST CPS 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SBNA RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SFNA RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SBFA RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SFFA RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 TRAT RSAV 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 IRAT RSAV 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 CIRNRSAV 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 CIRF RSAV 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 BSALRSAV PPK 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SIBF RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 TPHI RSAV PU-S 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SFFC RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SFNC RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 SIGM RSAV CU 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 DSIG RSAV 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 FBEF RSAV UA 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 CRRARSAV 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH RST GAPI 1175307 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 9769.000 NBAC.RST 2041.177 FBAC.RST 3654.201 SBNA.RSAV SFNA.RSAV 17.078 SBFA.RSAV 37.147 SFFA.RSAV 15.040 TRAT. RSAV IRAT.RSAV O. 504 CIRN. RSAV 1. 457 CIRF. RSAV 2. 928 BSAL. RSAV SIBF. RSAV 25. 261 TPHI. RSAV 26. 964 SFFC. RSAV 12. 532 SFNC. RSAV SIGM. RSAV 12. 555 DSIG. RSAV 1.164 FBEF. RSAV 68. 035 CRRA. RSAV GRCH. RST -999. 250 44.374 0.984 9.021 13.440 2.014 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:Jo PAGE: 14 DEPT. 9425. 000 NBAC. RST -999. 250 FBAC. RST SFNA. RSAV -999. 250 SBFA. RSAV -999. 250 SFFA. RSAV IRAT. RSAV -999. 250 CIRN. RSAV -999.250 CIRF. RSAV SIBF. RSAV -999. 250 TPHI . RSAV - 999. 250 SFFC. RSAV SIGM. RSAV -999.250 DSIG.RSAV -999.250 FBEF. RSAV GRCH. RST 14. 932 - 999. 250 SBNA. RSAV - 999. 250 TRAT. RSAV - 999. 250 BSAL. RSAV - 999. 250 SFNC. RSAV -999. 250 CRRA. RSAV -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NURIBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCREM~2FT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH RST 9790.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : STOP DEPTH .......... 9388.5 3-JUN-98 8C1-205 1814 3-JUN-98 10000.0 9450.0 9750.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:or PA GE: 15 LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): 3000.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A 964 RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN) DRILLERS CASING DEPTH (FT) LOGGERS CASING DEPTH (FT) 8.500 9986.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TE~IPERATURE (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): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): REMARKS: CORRELATED TO SWS CArL LOG DATED 9-8-96. PUMPED 100 BBLS SEAWATER @ 5 BPM TO LOAD WELL, CUT RATE TO .6 BPM TO KEEP PRESSURE AT 1400 PSI. LOGGED 3 BASELINE PASSES AT 50 FPM WHILE PI AT .6 BPM/1400 PSI. JOB ABORTED AFTER BASELINE PASSES. NO BORAX WAS PUMPED. FIELD PICK GOC: 9562'. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #1. $ LIS FORMAT DATA LIS Tape Ver=~cation Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~o PAGE: 16 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 3 68 4 66 1 5 66 6 73 7 65 8 68 O. 5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) DEPT FT 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CS PS1 F/HR 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 NPHVPS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 NPDE PSi V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 NSCE PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CRRA PSi 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 NSCR PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 AQTMPS1 S 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CHV PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CPSV PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CP2V PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CM2V PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RCFR PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RCLC PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RCRC PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RCAKPS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RTDF PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FPHVPS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FPDE PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FSCE PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FSCR PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 AQTF PS1 S 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SF6P PS1 PSIG 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Ver~cation Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~o PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUmB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) HVPV PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BMCU PS1 UA 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 GDCU PSl MA 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 EXCU PS1 UA 1175307 O0 000 O0 0 $ 1 1 4 68 0000000000 NBEF PS1 UA 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FBEF PS1 UA 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 NPGF PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FPGF PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BSTR PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BSPR PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 MARC PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 XHV PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 XPSV PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 XP2V PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 XM2V PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RXFR PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RXLC PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RXRC PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RXAKPSi 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SHCU PSi MA 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL PS1 PPK 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BSAL SIG PPK 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CIRNPS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF PS1 1175307 O0 000 O0 0 $ 1 1 4 68 0000000000 CIRNFIL 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CIRF FIL 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 DSIG PSi 1175307 O0 000 O0 0 5 1 I 4 68 0000000000 FBAC PSi CPS 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 IRAT FIL 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 NBAC PS1 CPS 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA PS1 CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA PS1 CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA PS1 CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA PS1 CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA SIG CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA SIG CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA SIG CU 1175307 O0 000 O0 0 $ 1 1 4 68 0000000000 SBFA SIG CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFNA FIL CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFFA FIL CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SBNA FIL CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SBFA FIL CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF PS1 CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFNC PSi CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SFFC PSi CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM PS1 CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SIBF SIG CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 SIGM SIG CU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 TRAT SIG 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~o PAGE: 18 NAME SERV UNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUlV~ SAMP ELE~I CODE (HEX) TRAT FIL 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RDIX PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CRNI PS1 KHZ 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CRFI PS1 KHZ 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CTM PS1 DEGC 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 XTM PS1 DEGC 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 TAV PS1 KV 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 FICU PS1 AMP 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CACU PS1 AMP 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BUST PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 BUSP PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RSXS PS1 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI PS1 PU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 TPHI SIG PU 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 CCLC PS1 V 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 RSCS PSi 1175307 O0 000 O0 0 5 1 1 4 68 0000000000 ** DATA ** DEPT. NPDE. PS1 AQTM. PS1 CM2V. PS1 RCAK. PS1 FSCE. PS1 HVPV. PS1 NBEF. PS1 BSTR. PS1 XPSV. PSi RXLC. PS1 BSAL.PS1 CIRN. FIL Ii{AT. PSi SFFA.PS1 SFFA.SIG SFFA.FIL SFNC. PS1 SIGM. SIG GR.PS1 CTM. PS1 CACU. PS1 TPHI.PS1 DEPT. NPDE. PS1 AQTM. PS1 CM2 V. PS1 RCAK. PS1 9790.500 1446.992 0.661 -12.270 0.000 2.427 0.244 519.210 0 808 5 089 0 000 -999 250 -999 250 -999 250 -999 250 -999.250 -999.250 -999.250 -999.250 20.188 71.289 0.000 -999.250 CS.PS1 3056.027 TENS.PSi NSCE. PS1 2.362 CRRA.PS1 CHV. PS1 202.308 CP5V. PS1 RCFR.PS1 0.000 RCLC. PS1 RTDF. PS1 0.000 FPHV. PS1 FSCR.PS1 0.427 AQTF. PS1 BMCU. PS1 0.000 GDCU. PS1 FBEF. PS1 211.204 NPGF. PS1 BSPR.PS1 0.899 MARC. PSi XP2V. PS1 12.202 XM2V. PS1 RXRC.PS1 0.000 RXAK. PS1 BSAL.SIG -999.250 CIRN. PS1 CIRF. FIL -999.250 DSIG.PS1 IRAT. FIL -999.250 NBAC. PS1 SBNA.PS1 -999.250 SBFA.PS1 SBNA.SIG -999.250 SBFA.SIG SBNA.FIL -999.250 SBFA.FIL SFFC.PS1 -999.250 SIGM. PS1 TRAT.PS1 -999.250 TRAT. SIG RDIX. PS1 98719.000 CRNI.PS1 XTM. PS1 70.313 TAV. PS1 BUST.PSI 3.000 BUSP.PS1 TPHI.SIG -999.250 CCLC.PS1 9388.000 CS.PS1 2966.402 TENS.PSi 1459.581 NSCE. PS1 2.324 CRRA.PS1 0.661 CHV. PS1 202.308 CPSV. PS1 -12.270 RCFR.PS1 0.000 RCLC. PS1 0.000 RTDF. PS1 0.000 FPHV. PS1 634.000 0 407 5 079 0 000 1513 673 0 661 0 000 1 004 0 000 -12.348 0.000 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 1.274 0.000 3.000 0.010 1098. 000 1.968 5. 069 O. 000 1518.556 NPHV. PS1 NSCR.PS1 CP2V. PS1 RCRC. PS1 FPDE. PS1 SF6P. PS1 EXCU. PS1 FPGF. PS1 XHV. PS1 RXFR.PS1 SHCU. PS1 CIRF. PS1 FBAC. PS1 SFNA.PS1 SFNA.SIG SFNA.FIL SIBF. PS1 SIBF. SIG TRAT. FIL CRFI.PS1 FICU. PS1 RSXS. PS1 RSCS.PS1 NPHV. PS1 NSCR. PS1 CP2 V. PS1 RCRC. PS1 FPDE. PS1 1472.169 0.676 12.158 0.000 1482. 011 130. 372 2. 762 1. 002 199.885 0.000 25.365 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 3.131 0.000 8192.000 8463.000 1489.259 0.196 12.217 0.000 1490.441 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:36 PAGE: 19 FSCE. PS1 1.994 FSCR.PS1 HVPV. PS1 158.399 BMCU. PS1 NBEF. PS1 27.156 FBEF. PS1 BSTR.PS1 64.644 BSPR. PS1 XPSV. PS1 5.087 XP2V. PS1 RXLC. PS1 0.000 RXRC. PS1 BSAL.PS1 -6.856 BSAL.SIG CIRN. FIL 1.246 CIRF.~IL IRAT. PS1 0.678 IRAT. FIL SFFA.PS1 17.387 SBNA.PS1 SFFA.SIG 0.290 SBNA.SIG SFFA.FIL 17.300 SBNA.FIL SFNC. PS1 12.088 SFFC. PS1 SIGM. SIG 0.213 TRAT. PS1 GR.PS1 6.322 RDIX. PS1 CTM. PS1 71.777 XTM. PS1 CACU. PSi 2.504 BUST. PSi TPHI.PS1 9.586 TPHI.SIG -0.058 AQTF. PS1 33.867 GDCU. PS1 53.451 NPGF.PS1 1.036 MARC.PSi 12.191 XM2V. PS1 0.000 RXAK. PS1 3.556 CIRN. PS1 2.397 DSIG.PS1 0.680 NBAC. PS1 50.527 SBFA.PS1 4.193 SBFA.SIG 50.416 SBFA.FIL 14.289 SIGM. PS1 0.769 TRAT. SIG 108901.000 CRNI.PS1 72.412 TAV. PS1 3.000 BUSP.PS1 0.521 CCLC. PS1 0.661 SF6P. PS1 60.307 EXCU. PS1 0.997 FPGF. PS1 0.000 XHV. PS1 -12.373 RXFR.PS1 0.000 SHCU. PS1 1.230 CIRF. PS1 -1.844 FBAC. PS1 2052.825 SFNA.PS1 30.126 SFNA.SIG 4.387 SFNA.FIL 31.898 SIBF. PS1 14.181 SIBF. SIG 0.013 TRAT. FIL 445.310 CRFI.PS1 91.974 FICU. PS1 3.000 RSXS. PS1 -999.250 RSCS. PS1 131.268 3.590 0.999 200.103 0.000 45.723 2.343 3495.832 19.466 0.394 18.740 19.831 1.201 0.769 226.243 2.379 8878.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFiBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFiBER: 2 DEPTH INCREMFlVT: 0.5000 FILE SUM~NU~Y VENDOR TOOL CODE START DEPTH STOP DEPTH LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~o PAGE: 2O RST 9791.5 $ LOG HEADER DATA DATE LOGGED: 9378.5 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): 3 -JUN-98 8Cl -205 1814 3-JUN-98 10000.0 9450.0 9750.0 3000.0 NO TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY RST RESEVOIR SATURATION $ TOOL NUMBER CGRS-A 964 RST-A BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT): 8.500 9986.0 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): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION 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): FAR COUNT RATE HIGH SCALE (CPS): ~ COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:Jo PAGE: 21 REMARKS: CORRELATED TO SWS CNL LOG DATED 9-8-96. PUMPED 100 BBLS SEAWATER @ 5 BPM TO LOAD WELL, CUT RATE TO . 6 BPM TO KEEP PRESSURE AT 1400 PSI. LOGGED 3 BASELINE PASSES AT 50 FPM WHILE PI AT .6 BPM/1400 PSI. JOB ABORTED AFTER BASELINE PASSES. NO BORAX WAS PUMPED. FIELD PICK GOC: 9562'. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NA~iE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NLC4B SAMP ELEM CODE (HEX) DEPT FT 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CS PS2 F/HR 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NPHVPS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NPDE PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NSCE PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CRRA PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NSCR PS2 1175307 O0 000 O0 0 6 1 1 4 68 00000~0000 AQTMPS2 S 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CHV PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:Jo PAGE: 22 NARiE SERV UNIT SERVICE API API API API FILE NUF~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELEM CODE (HEX) CPSV PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CP2V PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CM2V PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RCFR PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RCLC PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RCRC PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RCAKPS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RTDF PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FPHVPS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FPDE PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FSCE PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FSCR PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 AQTF PS2 S 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SF6P PS2 PSIG 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 HVPV PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BMCU PS2 UA 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 GDCU PS2 MA 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 EXCU PS2 UA 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NBEF PS2 UA 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FBEF PS2 UA 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NPGF PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FPGF PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BSTR PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BSPR PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 MARC PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 XHV PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 XPSV PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 XP2V PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 XM2V PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RXFR PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RXLC PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RXRC PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RXAKPS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SHCU PS2 MA 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL PS2 PPK 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BSAL SIG PPK 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNPS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CIRFPS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CIRNFIL 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CIRF FIL 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 DSIG PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FBAC PS2 CPS 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 IRAT FIL 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 NBAC PS2 CPS 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA SIG CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA SIG CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3o PAGE: 23 NA~IE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUmB SAMP ELEM CODE (HEX) SBNA SIG CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA SIG CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFNA FIL CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFFA FIL CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SBNA FIL CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SBFA FIL CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFNC PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SFFC PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM PS2 CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SIBF SIG CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 SIGM SIG CU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT SIG 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TRAT FIL 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RDIX PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CRNI PS2 K~tZ 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CRFI PS2 KHZ 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CTM PS2 DEGC 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 XTM PS2 DEGC 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TAV PS2 KV 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 FICU PS2 AMP 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CACU PS2 AMP 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BUST PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 BUSP PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RSXS PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI PS2 PU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 TPHI SIG PU 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 CCLC PS2 V 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 RSCS PS2 1175307 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 9791.500 CS. PS2 3103.448 TENS.PS2 NPDE. PS2 1458.512 NSCE. PS2 2.393 CRRA.PS2 AQTM. PS2 0.661 CHV. PS2 202.066 CPSV. PS2 CM2V. PS2 -12.270 RCFR.PS2 0.000 RCLC.PS2 RCAK. PS2 0.000 RTDF. PS2 0.000 FPHV. PS2 FSCE. PS2 2.021 FSCR.PS2 -0.294 AQTF. PS2 HVPV. PS2 158.692 BMCU. PS2 40.722 GDCU. PS2 NBEF. PS2 33.731 FBEF. PS2 68.301 NPGF. PS2 BSTR.PS2 53.981 BSPR.PS2 1.063 MARC.PS2 XPSV. PS2 5.089 XP2V. PS2 12.188 X~2V. PS2 RXLC. PS2 0.000 RXRC. PS2 0.000 RXAK. PS2 BSAL.PS2 -999.250 BSAL.SIG -999.250 CIRN. PS2 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG. PS2 IRAT. PS2 -999.250 IRAT. FIL -999.250 NBAC. PS2 SFFA.PS2 -999.250 SBNA.PS2 -999.250 SBFA.PS2 833.000 NPHV. PS2 2.025 NSCR.PS2 5.069 CP2V. PS2 0.000 1528.322 0.661 60.012 0 995 0 000 -12 387 0 000 -999 250 -999 250 -999 250 -999 250 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR.PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA.PS2 SFNA.SIG 1481.935 0.090 12.202 0.000 1489.450 133.698 1.973 0.991 199.643 0.000 39.024 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:3~ PAGE: 24 SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL SFNC. PS2 -999.250 SFFC.PS2 -999.250 SIGM. PS2 SIGM. SIG -999.250 TRAT. PS2 -999.250 TRAT.SIG GR.PS2 20.188 RDIX. PS2 112252.000 CRNI.PS2 CTM. PS2 71.777 XTM. PS2 69.336 TAV. PS2 CACU. PS2 2.515 BUST. PS2 3.000 BUSP.PS2 TPHI.PS2 -999.250 TPHI.SIG -999.250 CCLC. PS2 DEPT. NPDE. PS2 AQTM. PS2 CM2V. PS2 RCAK. PS2 FSCE. PS2 HVPV. PS2 NBEF. PS2 BSTR.PS2 XPSV. PS2 RXLC. PS2 BSAL.PS2 CIRN. FIL IRAT. PS2 SFFA.PS2 SFFA.SIG SFFA.FIL SFNC.PS2 SIGM. SIG GR.PS2 CTM. PS2 CACU. PS2 TPHI.PS2 9378.000 1458 856 0 661 -12 270 0 000 2 000 158 285 27. 638 71.247 5.087 0.000 -6.039 1.363 0.703 15.987 0.257 15.735 9.909 0.195 22.647 70. 801 2.505 8.473 CS.PS2 NSCE. PS2 CHV. PS2 RCFR.PS2 RTDF. PS2 FSCR.PS2 BMCU. PS2 FBEF. PS2 BSPR.PS2 XP2V. PS2 RXRC. PS2 BSAL.SIG CIRF. FIL IRAT. FIL SBNA. PS2 SBNA. SIG SBNA.FIL SFFC. PS2 TRAT. PS2 RDIX. PS2 XTM. PS2 BUST. PS2 TPHI. SIG 2970.841 2. 342 201.581 0.000 0.000 -0. 096 34. 017 51. 842 1.113 12.206 0 000 3 571 2 610 0 704 47 119 4 369 48. 763 12. 403 O. 741 119058. 000 70. 801 3. 000 O. 482 TENS.PS2 CRRA.PS2 CP5V. PS2 RCLC.PS2 FPHV. PS2 AQTF. PS2 GDCU. PS2 NPGF. PS2 MARC. PS2 X~2V. PS2 RXAK.PS2 CIRN. PS2 DSIG.PS2 NBAC. PS2 SBFA.PS2 SBFA.SIG SBFA.FIL SIGM. PS2 TRAT. SIG CRNI.PS2 TAV. PS2 BUSP.PS2 CCLC.PS2 -999.250 -999.250 -999.250 -999.250 452.794 91.873 3.000 0.029 1050.000 1 876 5 089 0 000 1523 439 0 661 59 720 1.001 0.000 -12.368 0.000 1.395 -2.532 2259.819 39.716 4.582 36.197 12.315 0.012 453.5O5 92.001 3.000 -999.250 SFNA.FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI.PS2 FICU. PS2 RSXS.PS2 RSCS.PS2 NPHV. PS2 NSCR. PS2 CP2 V. PS2 RCRC. PS2 FPDE. PS2 SF6P. PS2 EXCU. PS2 FPGF. PS2 XHV. PS2 RXFR. PS2 SHCU. PS2 CIRF. PS2 FBAC. PS2 SFNA. PS2 SFNA. SIG SFNA. FIL SIBF. PS2 SIBF. SIG TRAT. FIL CRFI. PS2 FICU. PS2 RSXS. PS2 RSCS. PS2 -999.250 -999.250 -999.250 -999.250 223.615 2.407 8878.000 8463.000 1484.376 -0.276 12.202 0.000 1491.471 132.163 3.726 0.999 200.020 0.000 45.672 2.628 3479.139 16.801 0.345 17.130 20.107 1.208 0.743 241.771 2.378 8878.000 8459.000 ** END OF DATA ** **** FILE TRAILER **** FILE NA~E : EDIT .006 SERVICE :-FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 I6:~_ PAGE: 25 **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUFI~ER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUFi~ER: 3 DEPTH INCR_EM~IVT: 0.5000 FILE S~Y VENDOR TOOL CODE START DEPTH ........................... RST $ LOG HEADER DATA DATE LOGGED: 9792.0 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): STOP DEPTH .......... 9374.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ......................... GR GAMMA RAY RST RESEVOIR SATURATION $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : 3-JUN-98 8Cl-205 1814 3-JUN-98 10000.0 9450.0 9750.0 3000.0 NO TOOL NUMBER ........... CGRS-A 964 RST-A 8.500 9986.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: 26 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): THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION 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): FAR COUNT RATE HIGH SCALE (CPS): NEAR COUNT RATE LOW SCALE (CPS): NEAR COUNT RATE HIGH SCALE (CPS): TOOL STANDOFF (IN): RE~iAR~S: CORRELATED TO SWS CNL LOG DATED 9-8-96. PUMPED 100 BBLS SEAWATER @ 5 BPM TO LOAD WELL, CUT RATE TO .6 BPM TO KEEP PRESSURE AT 1400 PSI. LOGGED 3 BASELINE PASSES AT 50 FPM WHILE PI AT .6 BPM/1400 PSI. JOB ABORTED AFTER BASELINE PASSES. NO BORAX WAS PUMPED. FIELD PICK GOC: 9562'. THIS FILE CONTAINS THE RAW RST SIGMA-MODE DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 368 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 2 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-i998 16~_~ PAGE: 27 TYPE REPR CODE VALUE 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CS PS3F/HR 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TENS PS3. LB 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NPHVPS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NPDE PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NSCE PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CRRAPS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NSCR PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 AQTMPS3 S 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CHV PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CP5V PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CP2V PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CM2V PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RCFR PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RCLC PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RCRC PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RCAK PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RTDF PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FPHVPS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FPDE PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FSCE PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FSCR PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 AQTF PS3 S 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SF6P PS3 PSIG 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 HVPV PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BMCU PS3 UA 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 GDCU PS3 MA 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 EXCU PS3 UA 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NBEF PS3 UA 1175307 O0 000 O0 0 7 1 i 4 68 0000000000 FBEF PS3 UA 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NPGF PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FPGF PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BSTR PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BSPR PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 MARC PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 XHV PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 XPSV PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 XP2V PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 3C42V PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RXFR PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RXLC PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:~ PAGE: 28 NAFiE SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) RX~C PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RXAKPS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SHCU PS3 MA 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL PS3 PPK 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BSAL SIG PPK 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNPS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CIRFPS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CIRNFIL 1175307 00 000 O0 0 7 1 1 4 68 0000000000 CIRF FIL 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 DSIG PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FBAC PS3 CPS 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 IRAT FIL 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 NBAC PS3 CPS 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA SIG CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA SIG CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA SIG CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA SIG CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFNA FIL CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFFA FIL CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SBNA FIL CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SBFA FIL CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFNC PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SFFC PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM PS3 CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SIBF SIG CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 SIGM SIG CU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT SIG 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TRAT FIL 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 GR PS3 GAPI 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RDIX PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CRlVI PS3 KHZ 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CRFI PS3 K~tZ 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CTM PS3 DEGC 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 XTM PS3 DEGC 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TAV PS3 KV 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 FICU PS3 AMP 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CACU PS3 AMP 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BUST PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 BUSP PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RSXS PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI PS3 PU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 TPHI SIG PU 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 CCLC PS3 V 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 RSCS PS3 1175307 O0 000 O0 0 7 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:__ PAGE: 29 ** DATA ** DEPT. 9792.000 CS.PS3 3015.076 TENS.PS3 606.000 NPHV. PS3 NPDE.PS3 1458.741 NSCE. PS3 2.416 CRRA.PS3 1.990 NSCR.PS3 AQTM. PS3 0.661 CHV. PS3 202.792 CPSV. PS3 5.079 CP2V. PS3 CM2V. PS3 -12.270 RCFR.PS3 0.000 RCLC.PS3 0.000 RCRC. PS3 RCAK. PS3 0.000 RTDF.PS3 0.000 FPHV. PS3 1520.997 FPDE. PS3 FSCE. PS3 2.060 FSCR.PS3 -0.269 AQTF.PS3 0.661 SF6P. PS3 HVPV. PS3 158.447 BMCU. PS3 40.722 GDCU. PS3 60.012 EXCU. PS3 NBEF. PS3 34.036 FBEF.PS3 67.747 NPGF.PS3 0.995 FPGF. PS3 BSTR.PS3 45.857 BSPR.PS3 1.122 MARC.PS3 0.000 XHV. PS3 XPSV. PS3 5.089 XP2V. PS3 12.188 X~2V. PS3 -12.387 RXFR.PS3 RXLC. PS3 0.000 RXRC.PS3 0.000 RXAK.PS3 0.000 SHCU. PS3 BSAL.PS3 -999.250 BSAL.SIG -999.250 CIRN. PS3 -999.250 CIRF. PS3 CIRN. FIL -999.250 CIRF. FIL -999.250 DSIG.PS3 -999.250 FBAC. PS3 IRAT. PS3 -999.250 IRAT. FIL -999.250 NBAC.PS3 -999.250 SFNA.PS3 SFFA.PS3 -999.250 SBNA.PS3 -999.250 SBFA.PS3 -999.250 SFNA.SIG SFFA.SIG -999.250 SBNA.SIG -999.250 SBFA.SIG -999.250 SFNA.FIL SFFA.FIL -999.250 SBNA.FIL -999.250 SBFA.FIL -999.250 SIBF. PS3 SFNC. PS3 -999.250 SFFC.PS3 -999.250 SIGM. PS3 -999.250 SIBF. SIG SIGM. SIG -999.250 TRAT.PS3 -999.250 TRAT. SIG -999.250 TRAT. FIL GR.PS3 222.068 RDIX. PS3 121265.000 CRIVI.PS3 444.953 CRFI.PS3 CTM. PS3 68.848 XTM. PS3 68.359 TAV. PS3 92.017 FICU. PS3 CACU. PS3 2.520 BUST. PS3 3.000 BUSP. PS3 3.000 RSXS.PS3 TPHI.PS3 -999.250 TPHI.SIG -999.250 CCLC.PS3 0.019 RSCS.PS3 DEPT. 9373.500 CS.PS3 NPDE. PS3 1457.330 NSCE. PS3 AQTM. PS3 0.661 CHV. PS3 CM2V. PS3 -12.270 RCFR.PS3 RCAK. PS3 0.000 RTDF. PS3 FSCE. PS3 2.009 FSCR.PS3 HVPV. PS3 158.423 BMCU. PS3 NBEF. PS3 27.577 FBEF. PS3 BSTR.PS3 60.245 BSPR.PS3 XPSV. PS3 5.087 XP2V. PS3 RXLC. PS3 0.000 RXRC. PS3 BSAL.PS3 -7.776 BSAL.SIG CIRN. FIL 1.092 CIRF. FIL IRAT. PS3 0.658 IRAT. FIL SFFA.PS3 17.876 SBNA.PS3 SFFA.SIG 0.308 SBNA.SIG SFFA.FIL 17.590 SBNA.FIL SFNC. PS3 12.674 SFFC. PS3 SIGM. SIG 0.229 TRAT. PS3 GR.PS3 16.359 RDIX. PS3 CTM. PS3 69.824 XTM. PS3 CACU. PS3 2.510 BUST. PS3 TPHI.PS3 7.973 TPHI.SIG 2999.276 2.341 202.550 0.000 0.000 -0.299 33 926 53 034 1 184 12 188 0 000 3 566 2 280 0 658 42 400 5 149 44 609 14 458 0 739 128171 000 70 166 3 000 0 538 TENS.PS3 1069.000 NPHV. PS3 CRRA.PS3 1.923 NSCR.PS3 CPSV. PS3 5.079 CP2V. PS3 RCLC.PS3 0.000 RCRC. PS3 FPHV. PS3 1523.439 FPDE. PS3 AQTF. PS3 0.661 SF6P. PS3 GDCU. PS3 59.782 EXCU. PS3 NPGF. PS3 1.005 FPGF. PS3 MARC. PS3 0.000 XHV. PS3 XM2V. PS3 -12.375 RXFR.PS3 RXAK. PS3 0.000 SHCU. PS3 CIRN. PS3 1.067 CIRF. PS3 DSIG.PS3 -2.066 FBAC. PS3 NBAC.PS3 2207.665 SFNA.PS3 SBFA.PS3 36.742 SFNA.SIG SBFA.SIG 4.461 SFNA.FIL SBFA.FIL 39.077 SIBF. PS3 SIGM. PS3 14.390 SIBF. SIG TRAT. SIG 0.014 TRAT. FIL CRNI.PS3 448.192 CRFI.PS3 TAV. PS3 91.988 FICU. PS3 BUSP.PS3 3.000 RSXS.PS3 CCLC. PS3 -999.250 RSCS. PS3 1491.700 0 630 12 202 0 000 1490 861 133 442 1 973 1 007 199 885 0 000 38 048 -999 250 -999 250 -999 250 -999 250 -999.250 -999 250 -999 250 -999 250 223 540 2 471 8878 000 8463 000 1481 -0 12 0 1491 132 3 1 199 0 36 2 3487 19 0 19 19 1 0 233. 2. 8878. 8463. 935 343 187 000 395 726 511 002 885 000 259 258 224 700 527 712 520 203 747 058 380 000 000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 13-0CT-1998 16:_- PAGE: 3O ** END OF DATA ** **** FILE TRAILER **** FILE NAFiE : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/10/13 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/10/13 ORIGIN : FLIC TAPE NAME : 98515 CONTINUATION # : 1 PREVIOUS TAPE : COF~iENT : ARCO ALASKA, INC., DS 5-41, PRUDHOE BAY, # 50-029-22696-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/10/13 ORIGIN : FLIC REEL NAM~ : 98515 CONTINUATION # : PREVIOUS REEL : COf~tVT : ARCO ALASKA, INC., DS 5-41, PRUDHOE BAY, # 50-029-22696-00 Iil enid 'MMIq GMM~ :~OO/HO SZDIAHZS OMI©DO% S~%L~ N%IZLSZM 96-DQ~-£I I I HDH© HLdZ(I ZNI~IZStf~ :XN-lfd~OO DNIDDOq :MZMMflN :MZ~MflN NflM :ZGOD ZAPCO :Z~OD ~00~ SL~IHS HO~ ZAHflD (HLdZ~ GZM~S~ZM) GH~fGNIf£S 0£ SZSS~d ~qlf - ~i~ L~IHS 00'AP 0'g9££ S~9'6 ©NI~LS MOIiO~O~~ (L,4/~I) LH©IZM (,I,M) H,I, dZ~ (MI) ZZIS (MI) ZZIS DMIStfD SMZ~I%IH~ DMIgtfO Z~IOH 00'5I O~'IP 068[ PL£I Z0I 9 XO~ '£ 00'PL£9 96-dMS-6I SZDIAHZS ©NI©©O2 SV%L~ NEZLSZM 'OMI (tf>tS~) NOIitfaO~dXZ dS 00£L9E~6E00S F~q :~clK~ s! ~ si!~qns @del FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GRCH $ .5000 START DEPTH STOP DEPTH 40.0 3280.0 CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ REMARKS: PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPF - 02 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 52 Tape File Start Depth = 35.000000 Tape File End Depth = 3285.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 13003 datums Tape Subfile: 2 137 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 1 DEPTH INCREMENT: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 39.0 $ LOG HEADER DATA 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): STOP DEPTH 3288.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR SBAR SINKER BAR PCM PULSE CODE MODULATOR GR GAMMA RAY $ 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): 13-AUG-96 FSYS REV. J001 VER. 1.1 0431 13-AUG-96 3269.0 3286.0 40.0 3281.0 1500.0 YES TOOL NUMBER 8250EA/8248EA 8220XA 0.000 3362.0 0.0 BRINE 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0.0 BASE NORMALIZING ,~INDOW (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) : 0.0 REMARKS: PASS 1. $ CN : BP EXPLORATION WN : MPF - 02 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA o0 * 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 GAP I 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: 260 Tape File Start Depth = 40.000000 Tape File End Depth = 3285.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TPJtILER **** LIS representation code decoding summary: Rep Code: 68 64906 datums Tape Subfile: 3 334 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 4 is type: LIS 96/ 9/19 O1 **** REEL TRAILER **** 96/ 9/19 01 Tape Subfile: 4 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 19 SEP 96 2:52p Elapsed execution time = 2.69 seconds. SYSTEM RETURN CODE = 0 * ALASKA COMPUTING CENTER * ....... SCHLUMBERGER COMPANY NAME : B.P. EXPLORATION WELL NAME : MPK-02 FIELD NAME : MILNE POINT BOROUGH : NORTH SLOPE STATE · ALASKA API NUMBER : 50-029-22675-00 REFERENCE NO : 96163 $ EP 0 5 ~99~o LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 10:32 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC REEL NAME : 96163 CONTINUATION # : PREVIOUS REEL : COfZgVlENT : B.P. EXPLORATION, MILNE POINT MPK-02, API #50-029-22675-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 96/08/20 ORIGIN : FLIC TAPE NAME : 96163 CONTINUATION # : 1 PREVIOUS TAPE : CO~kdENT : B.P. EXPLORATION, MILNE POINT MPK-02, API #50-029-22675-00 TAPE HEADER MILNE POINT MWD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL : FSL: FEL: FWL: ELEVATION (FT FROM MSL O) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING MPK-02 500292267500 B. P. EXPLORATION SCHLUMBERGER WELL SERVICES 20-AUG-96 BIT RUN 1 96163 ST. AMOUR ANGLEN BIT RUN 2 BIT RUN 3 3 12N lie 3800 2042 61. O0 60. O0 33. O0 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9. 625 4300.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 10:32 3RD STRING PRODUCTION STRING R~KS: Well drilled 5-MAY through lO-MAY-96 with CDR/CDN. Ail data was collected in a single bit run. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE . FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE H~ER FILE NUMBER: 1 EDITED MERGEDMWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: 0.5000 FILE S~Y LDWG TOOL CODE START DEPTH STOP DEPTH MWD 4232.5 10212.0 $ BASELINE CURVE FOR SHIFTS: NONE CURVE SHIFT DATA (MEAStrREDDEPTH) BASELINE DEPTH $ MERGED DATA SOURCE LDWG TOOL CODE $ REM_ARKS: No depth adjustments were made to this data as per Matt Linder. This file also contains the Very Enhanced QRO resisitivitywith 2' average that was reprocessed at GeoQuest. $ .......... EQUIVALENT UNSHIFTED DEPTH BIT RUN NO. MERGE TOP MERGE BASE LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 10:52 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630373 O0 000 O0 0 1 1 1 4 68 0000000000 RA MWD 0P~4~630373 O0 000 O0 0 1 1 1 4 68 0000000000 RP MWD OHMM 630373 O0 000 O0 0 1 1 1 4 68 0000000000 VRA MWD OHMM630373 O0 000 O0 0 1 1 1 4 68 0000000000 VRP MWD OHMM 630373 O0 000 O0 0 1 1 1 4 68 0000000000 DER MWD OH~4M630373 O0 000 O0 0 1 1 1 4 68 0000000000 ROP MWD FPHR 630373 O0 000 O0 0 1 1 1 4 68 0000000000 FET MWD HR 630373 O0 000 O0 0 1 1 1 4 68 0000000000 GR MWD GAPI 630373 O0 000 O0 0 1 1 1 4 68 0000000000 RHOBMWD G/C3 630373 O0 000 O0 0 1 1 1 4 68 0000000000 DRHOMWD G/C3 630373 O0 000 O0 0 1 1 1 4 68 0000000000 PEF MWD BN/E 630373 O0 000 O0 0 1 1 1 4 68 0000000000 CALNMWD IN 630373 O0 000 O0 0 1 1 1 4 68 0000000000 NPHIMWD PU-S 630373 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10211.500 RA.I~gD -999.250 RP.MWD -999.250 VRA.MWD VRP.MWD -999.250 DER.MWD -999.250 ROP.MWD 65.037 FET.MWD GR.MWD -999.250 RHOB.MWD -999.250 DRHO.MWD -999.250 PEF.MWD CALN.MWD -999.250 NPHI.MWD -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 10:52 PAGE: DEPT. 4233.000 RA.MWD VRP.MWD -999.250 DER.MWD GR.MWD -999.250 RHOB.MWD CALN.MWD -999.250 NPHI.MWD -999.250 RP.MWD -999.250 ROP.MWD -999.250 DRHO.MWD 46.700 -999.250 -999.250 -999.250 VRA . MWD FET. MWD PEF. MWD -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE · 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE · FLIC VERSION · O01CO1 DATE · 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: O. 5000 FILE S~Y VENDOR TOOL CODE START DEPTH MWD 4232.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE: SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY or REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : STOP DEPTH .......... 10212.0 lO-MAY-96 FAST2.5 4.0 MEMORY 10212.0 4233.0 10212.0 60 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 lO:b2 PAGE: HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: 47.1 53.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CDR RESIST./GR CDN NEUT./DENS. $ TOOL NUMBER RGS752 NDS022 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : 8.500 4300.0 BOREHOLE CONDITIONS MUD TYPE: LSND MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S) : 43.0 MUD PH: 9.0 MUD CHLORIDES (PPM) : 1700 FLUID LOSS (C3): 4.9 RESISTIVITY (OH~) AT TEMPERATURE (DEGF) : MUD AT MEASURED TEMPERATURE (MT): 1. 730 MUD AT MAX CIRCULATIONG TEMPERATURE : MUD FILTRATE AT (MT): 1. 410 MUD CAKE AT (MT): NEUTRON TOOL ~IA TRIX : SANDSTONE MATRIX DENSITY: 2.65 HOLE CORRECTION (IN): TOOL STANDOFF (IN): 1.0 EWR FREQUENCY (HZ): 20000 REN2ARKS: ***RUN 1 - TCB 4315'-10212'*** RES TO BIT: 64.20'; GR TO BIT: 74.62' DEN TO BIT: 119.38'; NEUT TO BIT: 126.36' Rm=l. 73@64 DEG, Rmf=l. 41@64 DEG MUD WEIGHTED WITH BARITE DATA FROM DOWNHOLE MEMORY WELL TD'D AT 0704 lO-MAY-96 MAX DEVIATION 53.74 DEG AT 10115' $ LIS FORMAT DATA 64.0 64.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 lO:b2 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 630373 O0 000 O0 0 2 1 1 4 68 0000000000 ATR LW1 OPff~l630373 O0 000 O0 0 2 1 1 4 68 0000000000 PSR LW1 OH~M 630373 O0 000 O0 0 2 1 1 4 68 0000000000 DER LW1 0I~4~ 630373 O0 000 O0 0 2 1 1 4 68 0000000000 ROPE LW1 F/HR 630373 O0 000 O0 0 2 1 1 4 68 0000000000 TABR LW1 HR 630373 O0 000 O0 0 2 1 1 4 68 0000000000 GR LW1 GAPI 630373 O0 000 O0 0 2 1 1 4 68 0000000000 RHOB LW1 G/C3 630373 O0 000 O0 0 2 1 1 4 68 0000000000 DRHO LW1 G/C3 630373 O0 000 O0 0 2 1 1 4 68 0000000000 PEF LW1 BN/E 630373 O0 000 O0 0 2 1 1 4 68 0000000000 TNPH LW1 PU 630373 O0 000 O0 0 2 1 1 4 68 0000000000 TABD LW1 630373 O0 000 O0 0 2 1 1 4 68 0000000000 DPHI LW1 PU 630373 O0 000 O0 0 2 1 1 4 68 0000000000 DCAL LW1 IN 630373 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10211 .500 ATR.LW1 -999.250 PSR.LW1 -999.250 DER.LW1 ROPE.LW1 65. 037 TABR.LW1 -999.250 GR.LW1 -999.250 RHOB.LW1 DRHO.LW1 -999.250 PEF. LW1 -999.250 TNPH.LW1 -999.250 TABD.LW1 DPHI.LW1 -999.250 DCAL.LW1 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification Listing Schlumberger Alaska Computing Center 20-AUG-1996 10:~2 PAGE: ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 96/08/20 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAlViE : EDIT DATE . 96/08/20 ORIGIN . FLIC TAPE NA~E : 96163 CONTINUATION # : 1 PREVIOUS TAPE : CO~4ENT . B.P. EXPLORATION, MILNE POINT MPK-02, API #50-029-22675-00 **** REEL TRAILER **** SERVICE NA~E : EDIT DATE . 96/08/20 ORIGIN · FLIC REEL NAME : 96163 CONTINUATION # : PREVIOUS REEL : COMMENT : B.P. EXPLORATION, MILNE POINT MPK-02, API #50-029-22675-00 Tape Subfile 2 is type: LIS 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 MPK - 02 500292267500 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 02-AUG-96 6728.00 B. ESARY O'MALLEY 3 12N liE 3800 2042 61.00 60.00 33.00 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 20.000 112.0 91.10 3RD STRING 9.625 4296.0 40.00 PRODUCTION STRING 7.000 10110.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS GR GRCH 2 1 08-JUL-96 WESTERN ATLAS LOGGING SERVICES PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ REMARKS: GR/CCL. EQUIVALENT UNSHIFTED DEPTH GRCH *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** LOG TIED TO WIRELINE MARKS. SHIFT PROCEDURE AS FOLLOWS: 1) SECOND PASS GAMMA RAY DEPTH MATCHED TO FIRST PASS GAMMA RAY. FILE HE~DER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 35.0 10100.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS) . NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN : BP EXPLORATION WN : MPK - 02 FN : MILNE POINT COUN : NORTH SLOPE STAT : 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 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 * DATA RECORD (TYPE# 0) Total Data Records: 159 1022 BYTES * Tape File Start Depth = 30.000000 Tape File End Depth = 10105.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet '~*** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 40303 datums Tape Subfile: 2 250 records... Minimum record length: 62 bytes Maximum record length: 1022 bytes Tape Su~file 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH~ PASS NUMBER: 1 START DEPTH 9800.0 BASELINE DEPTH GRCH 9811.5 9811.0 9830.5 9830.0 9832.0 9831.5 9835.5 9836.0 9839.5 9839.5 9850.0 9849.5 9854.0 9853.0 9856.0 9855.0 9857.0 9855.5 9857.5 9856.0 9871.5 9871.5 9877.0 9876.0 9883.0 9883.0 9891.0 9890.5 9904.5 9903.5 9905.0 9904.0 9941.5 9941.5 9942.0 9942.0 9943.0 9942.5 9947.0 9946.5 9948.0 9947.0 9949.0 9948.0 9949.5 9949.0 9990.0 9989.5 10013.5 10013.5 10083.5 10083.5 10095.0 10095.0 10095.5 10095.5 $ STOP DEPTH 10100.0 (MEASURED DEPTH) REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 2 (REPEAT PASS). / ? ?MATCH2A . OUT CN : BP EXPLORATION WN : MPK- 02 FN : MILNE POINT C~UN : NORTH SLOPE STAT : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 995 99 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 5 Tape File Start Depth = 9800.000000 Tape File End Depth = 10105.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1223 datums Tape Subfile: 3 64 records... Minimum record length: 62 bytes Maximum record length: 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: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 35.0 $ LOG HEADER DATA 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): STOP DEPTH 10110.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR CCL CASING COLLAR LOC. PCM PULSE CODE MODULATOR GR GAMMA RAY $ 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): 08-JUL-96 FSYS REV. J001 VER. 1.1 1805 08-JUL-96 10110.0 10102.0 35.0 10100.0 3600.0 YES TOOL NUMBER 8248XA 8250XA 8262XA 0.000 10110.0 0.0 BRINE/DIESEL CAP 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): 0.0 BASE NORMALIZI'~,~ WINDOW (FT) : 0.0 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): REMARKS: PASS 1 (MAIN PASS). $ 0.0 CN : BP EXPLORATION WN : MPK - 02 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * 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: 807 Tape File Start Depth = 35.000000 Tape File End Depth = 10110.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 241809 datums Tape Subfile:'4 881 records... Minimum record length: Maximum record length: 26 bytes 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: 0.2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9800.0 $ LOG HEADER DATA 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): STOP DEPTH 10114.0 08-JUL-96 FSYS REV. J001 VER. 1.1 1748 08-JUL-96 10110.0 10102.0 35.0 10100.0 1800.0 YES TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE SBAR SINKER BAR CCL CASING COLLAR LOC. PCM PULSE CODE MODULATOR GR GAMMA RAY $ TOOL NUMBER 8248XA 8250XA 8262XA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): LOGGER'S CASING DEPTH (FT): 0.000 10110.0 0.0 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): BRINE/DIESEL CAP 0.00 0.0 0.0 0 0.0 0.000 0.000 0.000 0.0 0.00 0.000 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 0 . 0 BASE NORMALIZIh~ WINDOW (FT): 0.0 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): REMARKS · · PASS 2 (REPEAT PASS). $ 0.0 CN : BP EXPLORATION WN : MPK - 02 FN : MILNE POINT COUN : NORTH SLOPE STAT : ALASKA * 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: 25 Tape File Start Depth = 9800.000000 Tape File End Depth = 10110.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 7429 datums Tape Subfile: 5 99 records... Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape S~bfile.6 is type: LIS 96/ 8/ 1 01 **** REEL TRAILER **** 96/ 8/ 1 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Thu 1 AUG 96 2:34p Elapsed execution time = 28.40 seconds. SYSTEM RETURN CODE = 0
