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190-101
· . 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. /9 (J- /01 File Number of Well History File PAGES TO DELETE Complete RESCAN o Color items - Pages: o Grayscale, halftones, pictures, graphs, charts - Pages: o Poor Quality Original - Pages: o Other - Pages: DIGITAL DATA o Diskettes, No. o Other, NofType OVERSIZED o Logs of various kinds o Other COMMENTS: , 05rc~ Scanned by: Lowell Date:S, h * O} Is! Ern o TO RE-SCAN Notes: Re-Scanned by: Beverly Bren Vincent Nathan Lowell Date: Is! NOTScanned.wpd STATE OF ALASKA ^4-1` "' ALASKA OIL AND GAS CONSERVATION COMMISSION "'�' . WELL COMPLETION OR REC PLETION REPORT AND LdG o z 2Q1 la. Well Status: 1 b. Well Class (;C. ❑Oil 0Gas 0 SPLUG 0 Ot F®Abandoned •❑ uspended °� -v,�„ 20AAC 25.105 OAAC 25.110 0 Ex lorato Pa I!graphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Ot r No.of Completions Zero 0 Development ®Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 3/12/2014 . 190-101 • 313-594 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 3/15/1991 50-029-22075-00-00 ' 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 3/29/1991 MPL-09 t 3527'FSL,4769' FEL, Sec.08,T13N, R10E, UM 8. KB(ft above MSL): 56 15. Field/Pool(s) Top of Productive Horizon: 1287'FSL, 593'FEL, Sec.06,T13N, R10E, UM GL(ft above MSL): 17' • Milne Point/Kuparuk River Oil , Total Depth: 9.Plug Back Depth(MD+TVD) 1540 FSL,698'FEL,Sec.06,T13N, R10E, UM 8128' 7124' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 545109 y- 6031719 Zone- ASP4 8610' 7529' • ADL 025509 TPI: x- 543977 y- 6034751 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 543869 y- 6035004 Zone- ASP4 None 18.Directional Surve : 19.Water depth,if offshore: 20. Thickness of Permafrost(ND): Y ❑Yes ® No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1500' 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: VSP/DIL/LDT/CNL/NGT/GYRO/CBL N/A 23. CASING, LINER AND CEMENTING RECORD \SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 13-3/8" 54.5# _ K-55 35' 115' 35' 115' _ 30" 500 sx Permafrost E 9-5/8" 36# L-80 35' 5029' 35' 4619' 12-1/4" 82 Bbls Class'G',512 Bbls Permafrost E 7" 26# L-80 35' 8597' 35' 7518' 8-1/2" 97 Bbls Class'G' 24. Open to production or injection? 0 Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) of Top&Bottom;Perforation Size and Number): 4-1/2", 12.6#,L-80 7942' 7860'/6906' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. SCANNED APR 2 5 2014 WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 8128' Set Whipstock -8128' 15 Bbls Class'G', 16 Bbls Class'G' 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Injection N/A Date of Test Hours Tested. Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 No Sidewall Core(s)Acquired? 0 Yes 0 No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS APR 18 24 Form 10-407 Revised 10/2012 CONTINUED ON REVERS -?lam 11/k(//l f Submit Original Only VLF 4123It - le,My ✓e 29. GEOLOGIC MARKERS(List all formations anc' kers encounter 30. FORMATION TESTS NAME TVD Well Tested? ,Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Ugnu 3714' 3547' None HRZ 7617' 6707' Kuparuk D 7920' 6955' Kuparuk C 8103' 7103' Kuparuk B 8114' 7112' Kuparuk A 8205' 7186' Miluveach 8322' 7283' Formation at Total Depth: 31.List of Attachment Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Trevor Hyatt,564-4627 Email: Trevor.Hyatt@bp.com Printed Name: Joe Lastu a Title: Drilling Technologist Signature: Phone 564-4091 Date: / II4 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only MPL-09, Well History (Pre-Rig Sidetrack) Date Summary 12/27/13 PULLED DMY SSSV FROM HXO SVLN @ 2216'MD. PULLED BALL&ROD AND RHC PLUG BODY FROM X-NIPPLE @ 7878' MD. LRS FREEZE PROTECT TBG W/40 BBLS OF 60/40. RAN 20'x 3.70" DRIFT,TAGGED TD @ 8190'SLM/8207'MD, SAW NO RESTRICTIONS. RAN 40 ARM PDS CALIPER AS PER PROGRAM***GOOD DATA***. 01/22/14 INITIAL T/I/O=200/0/0 PSI. RIH W/BAKER H-150 WHIPSTOCK. TOOLSTRING SHORTS OUT DURING RIH. POOH ANDTROUBLESHOOT. 01/23/14 TROUBLESHOOT TOOL. MOTOR CARTRIDGE WAS FOUND TO BE BAD. RIH WITH WPP/BAKER WHIPSTOCK. SET TOP OF WHIPSTOCK AT 8128'AT 26.5 DEG ROHS. FINAL T/I/O= 100/0/0 PSI. 01/29/14 CTU#8 1.5"Coil Job Objective:Cement Whipstock. Stand-by on fluids/Doyon move. 01/30/14 CTU 8 w/1.5"CT 24.3 bbls coil volume. Scope; Side track prep, cmt sqz past whipstock. Rig up. Function test BOP's with primary and backup controls. RIH w/BHA; 1.75"ctc, 1.69"crossover,two 1.75" stingers, 2"crossover,2.5"CMT nozzle. (oal=9.24'), Load well with 150 bbls 1% kcl. 01/31/14 CTU 8 w/1.5"CT 24.3 bbls coil volume. Scope; Side track prep, cmt sqz past whipstock. Performed injection WHP 1100 psi at 1 bpm, Static WHP 600 psi. Unable to pump 1st cement batch due to mixing issues, cleanup and freeze protect, send unit to SLB yard reload cement. Held WC Drill. Pumped 15 bbls of 15.8 ppg cement, laid in 7 bbls at whipstock pressure 1314 psi,did not achieve 500 psi bump, pulled up hole bumped pressure and bled down, attempt hesitate sqz. 02/01/14 CTU 8 w/1.5"CT 24.3 bbls coil volume. Scope; Side track prep, cmt sqz past whipstock. Currently in hole with w/BHA; 1.75"ctc, 1.69"crossover,two 1.75"stingers,2"crossover, 2.5"CMT nozzle. (oal= 9.24'), Hesitate squeeze and unable to get 500 psi bump, over displaced cement. Re-order fluids. Park nozzle at flag and pump 16 bbls of 15.8 ppg Class G cement. Bullhead 10 bbls past whipstock and lay in remaining cement. Perform hesitation sqz to 700 psi over static pressure. Cleanout w/gel to flag and chase returns at 80%.w/1:1 returns. Freeze protected well to 2500'with 60/40,Wash BOPs. Recovered ball. Final WHP 900 psi.Start BOP test. 02/02/14 CTU 8 w/1.5"CT 24.3 bbls coil volume. Scope; Side track prep, cmt sqz past whipstock. Performed weekly BOP test, passed per procedure. Perform chain inspection and change packoff..RDMO and well shut in with 900 psi. 02/12/14 T/I/O=386/25/24 Well temp=Shut in MIT-T to 2400psi (Pre-rig work) Rig up, PT equipment. 02/13/14 MIT-T to 2400 psi***FAIL***(Pre-rig Work) Pumped 15 bbls DSL down TBG to establish liguid leak rate of 2 bbls a min. at 1930 psi. see log for details. FWHP=300/25/27 MV=open WV/SV/SSV=Closed IA/OA=OTG. 02/24/14 T/I/0=100/100/0 Conduct PJSM Performed LTT on barriers SV&SSV Installed Lubricator&PT'd to 300 psi low/3500 psi high. Set 4 1/16"CIW"H"BPV#MPP-29 @ 110"w 1-1'ext. Second I/A installed. Page 1 of 1 North America-ALASKA-BP Page 1424 Operation Summary Report Common Well Name:MPL-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2014 End Date: X3-0140J-C:(3,629,934.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:NORDIC 2 Spud Date/Time:3/15/1991 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292207500 Active datum:ORIG KELLY BUSHING @56.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/8/2014 18:00 - 19:00 1.00 MOB P PRE I PREPARE TO MOVE RIG OFF MPF-78A WELL. 19:00 - 20:00 1.00 MOB P ' PRE PJSM. BACK RIG OFF WELL. SPOT AND START MOVING MATTS TO L-PAD. - ---- ___ - ------.._.._-__.._..----- 20:00 - 21:30 1.50 MOB P PRE CLEAN UP AROUND MPF-78A. DRILLER AND TOUR PUSHER PERFORM ROUTE DRIVE. } CONTINUE TO MOVE MATTS. _ 21:30 - 00:00 2.50 MOB P . PRE •PJSM. MOVE RIG FROM MPF PAD TO MPL PAD. SPOT ON LOCATION AND LAY MATTING ON MPL-09 WELL. 3/9/2014 00:00 - 01:00 1.00 MOB P PRE CONTINUE TO SPOT MATTING AROUND MPL-09. 01:00 - 03:00 1.00 MOB P PRE PJSM. SPOT RIG AND SET ON MPL-09 WELL. ACCEPT RIG AT 03:00 ON 3/9/2014 03:00 - 06:00 3.00 BOPSUR P PRE LEAK TIGHT TEST TREE VALVES.NIPPLE DOWN TREE CAP. CONTINUE TO RIG UP _ ANCILLARY EQUIPMENT. 06:00 - 11:00 5.00 Ir BOPSUR P PRE NU BOPEAND'WING MANIFOLD. LOWER 2"REEL AND INSTALL 2-3/8"REEL IN REEL HOUSE. INCIDENT:LEAKING HARDLINE MISSING FROM INJECTOR.DURING REEL SWAP, POWER PACK WAS BROUGHT ONLINE RESULTING IN RELEASE OF 20 GAL OF HYDRAULIC FLUID TO RIG FLOOR.IR 4660857 11:00 - 18:00 5.00 BOPSUR P PRE OPEN UP RAM DOORS AND CHANGE OUT RAMS TO FOLLOWING CONFIGURATION(TOP DOWN): BLIND SHEARS 2-3/8"COMBIS 3"COMBIS 3"COMBIS 2-3/8"X 3-1/2"VBRS 2-3/8"COMBIS RU INSPECTED AND VERIFIED BY WSL AND NORDIC TP. 16:00 - 18:00 2.00 BOPSUR N PRE TEST POWERPACK HYDRAULIC SYSTEM •AFTER HARDLINE REPLACEMENT. 18:00 - 19:30 1.50 BOPSUR P PRE CONTINUE WORKING ON POWER PACK. 19:30 - 21:00 1.50 BOPSUR P PRE PICK UP INJECTOR MAKE UP STUFFING BOX. 21:00 - 00:00 3.00 BOPSUR P PRE INSTALL GRAPPLE AND PULL TEST. PULL COIL ACROSS,NO GO INTO INJECTOR CUT 8'COIL. INSTALL GRAPPLE AND PULL TEST. COIL CAME OFF REEL AT AND ANGLE THAT MADE IT DIFFICULT TO STAB INTO THE INJECTOR. MADE MULTIPLE ATTEMPTS. PULL COIL ACROSSAND STAB INTO INJECTOR. 3/10/2014 00:00 - 01:30 1.50 BOPSUR P PRE CONTINUE TO PULL COILACROSS AND STAB INTO INJECTOR. COIL CAME OFF REELATAN ANGLE THAT MADE IT DIFFICULT TO STAB INTO THE INJECTOR. MADE MULTIPLE ATTEMPTS BEFORE BEING ABLE TO STAB IT SUCCESSFULLY. Printed 3/24/2014 10:20:36AM North America-ALASKA-BP Page 2 o ej' Operation Summary Report Common Well Name:MPL-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2014 End Date: X3-0140J-C:(3,629,934.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:NORDIC 2 Spud Date/Time:3/15/1991 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292207500 Active datum:ORIG KELLY BUSHING @56.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 03:30 2.00 BOPSUR P PRE PJSM. FILL STACK. SHELL TEST BOPS TO 250/4500 PSI. 03:30 - 04:00 0.50 BOPSUR P PRE HELD H2S/RIG EVACUATION DRILL. GOOD RESPONSE. DRILL WAS UNANNOUNCED AND ALL PERSONNEL MUSTERED EFFICIENTLY AND AS PER PROCEDURE. 04:00 - 15:30 11.50 BOPSUR P PRE CONTINUE WITH BOP TESTING. PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,AND CRT-AK-10-45 -AOGCC INSPECTOR JEFF JONES WAIVED WITNESSING THE BOP TEST AT 17:41 03/09/2014 TEST IS WITNESSED BY TOOLPUSHER AND WSL. -TEST BOPE TO 250/3500 PSI FOR 5 CHARTED MIN -TEST CHOKE VALVES,CHOKE HCR,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES, BOP RAMS AND ANNULAR PREVENTER. VBR AND ANNULAR TESTED WITH BOTH 2-3/8"AND 3"TEST JOINTS -2-3/8"RAMS TESTED WITH 2-3/8"TEST JOINT -3"RAMS TESTED WITH 3"TEST JOINT -TEST FULL OPENING SAFETY VALVES -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS AND DRAW DOWN TEST OF ACCUMULATOR. NO FAILURES 15:30 - 16:00 0.50 BOPSUR P PRE RIG EVAC/MAN DOWN/H2S WITH AAR APPROPRIATE RESPONSE. 16:00 - 20:00 4.00 BOPSUR P PRE TEST MANAGED PRESSURE DRILLING EQUIPMENT TO INITIAL BOPE TEST CRITERIA:250/3500 PSI FOR 5 CHARTED MIN. -MPD LOOP -WING VALVE AND DEPLOYMENT LUBRICATOR -SURFACE SAFETY VALVE AND CHECK VELVE ON THE WING 20:00 - 21:30 1.50 BOPSUR P PRE STAND BACK MPD LUBRICATOR. -RIG DOWM MPD LOOP. 21:30 - 23:00 1.50 BOPSUR P PRE PICK UP INJECTOR. -CUT 100'COIL. -REHEAD COIL CONNECTOR,PULL TEST 35K. -REHEAD WITH BAKER. MAKE UP LUBRICATORS. 23:00 - 00:00 1.00 BOPSUR P PRE STAB ON WELL FILL COIL WITH WATER. 3/11/2014 00:00 - 01:00 1.00 BOPSUR P PRE CONTINUE TO FILL COIL WITH FRESH WATER. 01:00 - 01:45 0.75 BOPSUR P PRE PRESSURE TEST INNER REEL HARD LINE TO 3800 PSI. 01:45 - 03:00 1.25 BOPSUR P PRE TEST INNER REEL VALVE AND PACKOFF TO 300/3500 PSI. 03:00 - 03:45 0.75 BOPSUR P PRE PJSM INSTALL BAKER CHECKS AND PRESSURE TEST SAME TO 300/3500 PSI. Printed 3/24/2014 10:20:36AM ' North America-ALASKA-BP Page 3 Q924/ Operation Summary Report Common Well Name:MPL-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2014 End Date: X3-0140J-C:(3,629,934.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:NORDIC 2 Spud Dame:3/15/1991 12:00:00AM Rig Release: ` Rig Contractor:NORDIC CALISTA UWI:500292207500 Active datum:ORIG KELLY BUSHING @56.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) ' I 03:45 - 04:30 0.75 BOPSUR P PRE PJSM. PICKUP LUBRICATOR AND TOOLS FOR PULLING BPV. BEGIN LOADING 290 BBL OF 11.8 PPG BRINE IN PITS. 04:30 - 05:00 0.50 BOPSUR P PRE PJSM. MAKE UP LUBRICATOR AND TOOLS FOR PULLING BPV. 05:00 - 06:00 1.00 BOPSUR P PRE I FILL LUBRICATOR WITH MEOH AND PRESSURE TEST SAME. PULL BPV,300 PSI ON WELL. 06:00 - 07:30 1.50 BOPSUR P PRE CREW CHANGE. FILL COIL WITH 11.8 PPG BRINE. 07:30 - 08:30 1.00 BOPSUR P PRE I MU WELL KILL BHA:CHECKS,STINGER, NOZZLE 08:30 - 11:00 2.50 BOPSUR P PRE PJSM FOR INITIAL ENTRY. 'BLOW DOWN KILL LINE I OPEN UP DOUBLE SWABS AND MASTER VALVE,WHP=175 PSI ' RIH PUMPING MIN RATE TAKING RETURNS TO TIGER TANK HOLDING 300 PSI BACK PRESSURE WITH HAND CHOKE.0 PSI DOWN STREAM.1 FOR 1 RETURNS 11:00 - 12:00 1.00 BOPSUR P PRE TAG WHIPSTOCK AT 8143'UNCORRECTED PULL UP TO 8130'AND CIRCULATE 11.8 PPG . I BRINE UP THE BACKSIDE TO SURFACE. START WITH 300 PSI WHP FOR 1 FOR 1 RETURNS.REDUCE WHP AS KWF I CONTINUES UP ANNULUS. 'OUT DENSITY 11.7 PPG. 12:00 - 12:30 0.50 BOPSUR P PRE SHUT DOWN PUMP AND FLOW CHECK 15 MIN.NO FLOW. 12:30 - 14:30 2.00 BOPSUR P PRE HOLD CREW MEETING WITH G.MATSON AND G SARBER IN OPS CAB. DISCUSS IMPORTANCE OF OPERATING DISCIPLINE,PROCESS SAFETY AND HOW THESES RELATE TO NORDIC 2 OPERATIONS. 14:30 - 16:00 1.50 BOPSUR P PRE HOLD PJSM. CIRCULATE OUT OF HOLE. 16:00 - 17:00 1.00 BOPSUR P PRE HOLD PJSM.AT SURFACE. FLOW CHECK. GET OFF WELL.UNSTAB COIL. LD NOZZLE BHA. 17:00 - 18:30 1.50 STWHIP P WEXIT MU 3.8"WINDOW MILLING BHA.STAB COIL. • GET ON WELL.PRESS TEST QTS TO 250/3500 PSI FOR 5/5 MIN. 18:30 - 19:00 0.50 STWHIP P WEXIT RIH WITH MILLING BHA TO 2200'MD -100'/MIN AT 0.45 BPM WITH 275 PSI 19:00 -I 19:30 0.50 STWHIP N SFAL 2,200.00 WEXIT ENCOUNTER PROBLEMS WITH SLB . I ENCODER ON INJECTOR -STOP AND CIRC AT MIN RATE WHILE REPLACE ENCODER 19:30 - 20:00 0.50 STWHIP P WEXIT CONTINUE RIH WITH MILLING BHA F/2200'T/ 3500'MD -100'/MIN AT 0.45 BPM WITH 280 PSI 20:00 - 20:30 0.50 STWHIP N SFAL 3,500.00 WEXIT PROBLEMS WITH ENCODER CONTINUE '-STOP AND CIRC AT MIN RATE WHILE REPLACE CABLES ON ENCODER,SOLVED THE PROBLEMS 20:30 - 21:30 1.00 STWHIP P WEXIT CONTINUE RIH WITH MILLING BHA F/3500'T/ 7900'MD -100'/MIN AT 0.45 BPM WITH 290 PSI Printed 3/24/2014 10:20:36AM North America-ALASKA-BP Page 4,9,41.1 Operation Summary Report Common Well Name:MPL-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2014 End Date: X3-0140J-C:(3,629,934.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:NORDIC 2 Spud Date/Time:3/15/1991 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292207500 Active datum:ORIG KELLY BUSHING©56.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:00 0.50 STWHIP P WEXIT LOG TIE IN AT 7900'WITH-14'CORRECTION ESTABLISH FRICTION PRESSURES WITH BRINE ABOVE WHIPSTOCK FRICTION PRESSURES WITH BRINE: TAKEN AT 8000'MD/6900'TVD,11.7 PPG FOR 4200 PSI HYDROSTATIC BPM PUMP PRESS PWD ANNULAR FRICTION LOSS 2.0 1690 PSI 4357 PSI -20 PSI/1000' 2.5 2475 PSI 4430 PSI -29 PSI/1000' 3.0 3296 PSI 4484 PSI -36 PSI/1000' 22:00 - 23:00 1.00 STWHIP P WEXIT DISPLACE WELL TO 9.2 PPG POWER PRO HOLDING 11.8 PPG EMW WITH SUPER CHOKE. -TAG AT 8126.4'CIRCULATING THROUGH AN OPEN EDC 23:00 - 23:30 0.50 STWHIP P WEXIT CLOSE EDC AND ESTABLISH FRICTION PRESSURES ABOVE WHIPSTOCK WITH MUD -HOLE 11.8 PPG EMW ON WINDOW AND TAKE SPRS TAKEN AT 8000'MD/6900'TVD,9.2 PPG FOR 3300 PSI HYDROSTATIC HOLD 4200 ANNULAR PRESSURE FOR 11.8 PPG EMW BPM PUMP PRESS WHP FRICTION LOSS 0.5 1622 PSI 700 PSI -25 PSI/1000' 1.0 1945 PSI 650 PSI -31 PSI/1000' 2.8 3475 PSI 564 PSI -42 PSI/1000' 23:30 - 00:00 0.50 STWHIP P WEXIT RUN IN HOLE TAG UP AT 8125.2'MD. MILL CEMENT FROM 8125.2'TO 8125.6'MD -3363 PSI FS AT 2.75 BPM IN/OUT. 200-250 PSI MTR WORK. -0.5-2.0 K#WOB. IA/OA:825 PSI/90 PSI. PVT:113 BBLS. -WHP/BHP/ECD:630 PSI/4337 PSI/11.94 PPG -SIGNIFICANT LATERAL VIBRATION,LITTLE TO NO METAL IN CUTTINGS,AND INDISTICT WOB CHANGE INDICATES MILLING CEMENT ON TOP OF THE WHIPSTOCK AND NOT YET MILLING THE WINDOW -NO STALLS DURING MILLING 3/12/2014 00.00 - 02:00 2.00 STWHIP P WEXIT MILL CEMENT FROM 8125.6'TO 8131.7'MD -3363 PSI FS AT 2.75 BPM IN/OUT. 200-250 PSI MTR WORK. -0.5-2.0 K#WOB. IA/OA:288 PSI/115 PSI. PVT:113 BBLS. -WHP/BHP/ECD:604 PSI/4340 PSI/11.93 PPG -SIGNIFICANT LATERAL VIBRATION,LITTLE TO NO METAL IN CUTTINGS,AND INDISTICT WOB CHANGE INDICATES MILLING CEMENT ON TOP OF THE WHIPSTOCK AND NOT YET MILLING THE WINDOW -NO STALLS DURING MILLING KICK WHILE DRILLING DRILL WITH AAR" -DISCUSS ROLES OF CREW MEMBERS DURING AAR Printed 3/24/2014 10:20:36AM ' North America-ALASKA-BP Page 5ag, Operation Summary Report ---- ----- - -- - - --_ _ -------- -------- — --------..._----------- Common Well Name:MPL-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2014 End Date: X3-0140J-C:(3,629,934.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:NORDIC 2 Spud Date/Time:3/15/1991 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292207500 Active datum:ORIG KELLY BUSHING @56.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 06:00 4.00 STWHIP P WEXIT MILL WINDOW FROM 8131.7'MD TO 8134.8' � ,9-6VVt MD300-4000 n" -3363 PSI FS AT 2.75 BPM IN/OUT. 4 n' PSI MTR WORK. 1►N V0-t K -1.5-3.5 K#WOB. IA/OA:415 PSI/143 PSI. ' �((� /. PVT:113 BBLS. j) 0 -WHP/BHP/ECD:604 PSI/4339 PSI/11.93 n PPG 1" -DECREASE IN LATERAL VIBRATION,ABILITY TO STACK DOWN WEIGHT,AND METAL SHAVINGS IN CUTTINGS INDICATE THAT THE WHIPSTOCK PINCH POINT HAS BEEN REACHED AND NOW MILLING WINDOW -NO STALLS DURING MILLING 06:00 - 06:30 0.50 STWHIP P WEXIT CREW CHANGE. DISCUSS CURRENT OPERATIONS. CHECK FLUIDS AND EQUIPMENT. CONTINUE TO MILL WINDOW. 06:30 - 12:00 5.50 STWHIP P WEXIT MILL WINDOW FROM 8135'. 3370 PSI FS AT 2.71 BPM IN/OUT. 175 PSI MOTOR WORK. 2.01 K#WOB WHP/BHP/ECD:590 PSI/4334 PSI/11.92 PPG IA/OA/PVT:558 PSI/267 PSI/112 BBLS. CONTINUE TO SEE METAL CUTTINGS IN RETURNS/ON MAGNETS. MILL TO 8140'. ESTIMATE EXITING WINDOW AT THIS DEPTH. 12:00 - 16:30 4.50 STWHIP P WEXIT MILL AHEAD FROM 8140'. 3350 PSI FS AT 2.73 BPM IN/OUT. 150 PSI MOTOR WORK. WOB:0.65K#. APPEAR TO HAVE EXITED CASING BASED ON VIBRATION AND ROP. CONTINUE TO MILL AHEAD. UP TO 40% CUTTINGS FOUND IN BOTTOMS UP SAMPLES. MILL RAT HOLE AT 2 FPH TO 8149.7'. 16:30 - 18:00 1.50 STWHIP P WEXIT REAM AND BACKREAM WINDOW. MAKE THREE PASSES AT 1 FPM. DRY DRIFT WINDOW. SMOOTH. 3450 PSI FS AT 2.74 BPM. 18:00 - 20:30 2.50 STWHIP P WEXIT POOH DISPLACING WELL TO 11.8 PPG BRINE. -100'/MIN AND 1172 PSI WITH 1.65/1.05 BBLS IN/OUT -FOLLOW MPD PRESSURE SCHEDULE 20:30 - 21:30 1.00 STWHIP P WEXIT PJSM AND LAY DOWN MILLING BHA -FLOW CHECK AT SURFACE,NO FLOW -GET OFF WELLAND UNSTAB COIL.MOVE INJECTOR OVER BUNG HOLE. -LAY DOWN MILL AND MOTOR -WSLAND BTT REP GAGE MILLS,BOTH MILL AND STRING REAMER 3.79"GO(TIGHT)3.78" NO-GO -LAY DOWN BOT SMART TOOLS -CHECK TREE BOLTS,BOLTS TIGHT Printed 3/24/2014 10:20:36AM • North America-ALASKA-BP Page 6.0124--- Operation Summary Report Common Well Name:MPL-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2014 End Date: X3-0140J-C:(3,629,934.00) Project:Milne Point Site:M Pt L Pad Rig Name/No.:NORDIC 2 Spud Date/Time:3/15/1991 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292207500 Active datum:ORIG KELLY BUSHING©56.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:30 - 22:30 1.00 DRILL P PROD1 PJSM AND PICK UP BUILD BHA -PICK UP BOT SMART TOOLS WITH RESISTIVITY -PICK UP ULTRA LS MOTOR WITH 3.62 DEG AKO -HELIOS C3 3-3/4"X 4-1/4"BICENTER BIT -STAB COIL AND GET ON WELL -PRESS TEST QTS TO 250/3500 PSI FOR 5/5 MIN,GOOD TEST 22:30 - 00:00 1.50 DRILL P PROD1 RUN IN HOLE WITH BUILD BHA -100'MIN.0.71 IN/1.20 OUT BPM WITH 311 PSI. -TIE-IN WITH-14.5'CORRECTION 3/13/2014 00:00 - 00:30 0.50 DRILL P PROD1 CONTINUE TO RUN IN HOLE WITH BUILD BHA -100'MIN.0.71 IN/1.20 OUT BPM WITH 311 PSI. CLOSE EDC AND RUN INTO OPEN HOLE,TAG AT 8151'MD 00:30 - 06:00 5.50 DRILL P PROD1 DRILL AHEAD FROM 8151'MD TO 8190'MD -3250 PSI FS AT 2.60 BPM IN/OUT. 100-250 PSI MTR WORK. -2.0-4.0 K#WOB. IA/OA:15 PSI/60 PSI. PVT: 194 BBLS. -WHP/BHP/ECD:520 PSI/4345 PSI/11.82 PPG 06.00 - 06:30 0.50 DRILL P PROD1 CREW CHANGE. DISCUSS OPERATIONS. CHECK EQUIPMENT AND FLUIDS. CONTINUE TO DRILL BUILD SECTION. 06 30 - 13:00 6.50 DRILL P PROD1 DRILL AHEAD FROM 8190'. 3245 PSI FS AT 2.61 BPM IN/OUT. 100-150 PSI MTR WORK. WOB:3-4K#. MW IN/OUT:M9.5 PPG/9.5 PPG. WHP/BHP/ECD:515 PSI/4354 PSI/11.79 PPG. IA/OA/PVT:20 PSI/81 PSI/195 BBLS. CONTINUE TURN AND BUILD TO 8400'. MAKE PERIODIC BHA WIPERS AS NEEDED. 13:00 - 17:00 4.00 DRILL P PROD1 DRILL AHEAD FROM 8400'. 3250 PSI FS AT 2.54 BPM IN/OUT. 100 PSI MTR WORK. WOB:1.67 K# WHP/BHP/ECD:455 PSI/4372 PSI/11.74 PPG. DRILL AHEAD TO 8495'. 17:00 - 19:30 2.50 DRILL P PROD1 DRILL AHEAD FROM 8495'. -3250 PSI FS AT 2.60 BPM IN/OUT. 100-250 PSI MTR WORK. -2.0-3.0 K#WOB. IA/OA:110 PSI/164 PSI. PVT:197 BBLS. -WHP/BHP/ECD:450 PSI/4364 PSI/11.74 PPG -TD BUILD SECTION AT 8561'. 19:30 - 21:00 1.50 DRILL P PROD1 WIPER TRIP BACK TO WINDOW -20'/MIN,IN 2.59 OUT 2.45 BPM WITH 3220 PSI. -REDUCE PUMP RATE THROUGH SHALE PACKAGE 8250'-8150'.1BPM IN 0.86 BPM OUT WITH 1670 PSI. WIPER TRIP CLEAN,NO OVER PULLS Printed 3/24/2014 10:20:36AM Tree: Cameron 4 1/16", 5M MPU L-09 i KB Elevation: 56.00' Wellhead:FMC 11" x 11"5M, GL Elevation: 21.00' Gen.5 w/ 11"x 4.5"FMC Tbg Hgr w/4.5" NSCT threads top and 3.5" 4-1/16" CIW Tree bottom and 4" CIW H BPV profile 13 3/8",54.5 ppf, K-55 csg. 115' 3.5"HES X-Nipple(2.813 id) 2,214' A Num: Starter Head was repaired with Furmanite 9-5/8",38#,K-55 btrs 5029' clamp.Do Not MIT-OA above clamp rating of 1200 psi. ► �--Y2., l2.(_,'• '76142: 7"26 ppf, L-80, Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) 01 Z "x4—Yj,tI-3E C�N1" Max hole angle 37 degrees at 6700' 7 SG° E-Line Jet cut TBG @ 7941' on 11-18-13 I 4-Vi' 1..g, Stimulation Summary -79 142.: 4/1/91 pumped 150,300#of 16/20 ` carbolite&25,710#of 12-18 carbo. Perforation Summary Ref log:SWS CBT dated 3/31/91 N$Izb To C. Size SPF Interval (TVD) • -!1k4,44 O� L PEl�� 4.5" 5 8107'-8128' 7106'-7123' ► Vi •1 Aro l�P �^► Oi 4.5" 5 8135'-8150' 7128'-7141' ♦'�i 4.5" 5 8218'-8248' 7197'-7221' ♦ 4.5" 5 8263'-8276' 7234'-7244' /'; -,��'/ 4,�► x + PBTD 8500' FISH: W/L tool string and cutter bar ih."'• ,�vk. ' Fish: 1-7/8"ball and catcher seat " 7",26#,L-80 shoe 8597' DATE REV.BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27-E WELL L-09 06/25/98 MDO RWO Tbg.change out 27E API NO: 50-029-22075 BP EXPLORATION (AK) • • \�� I 7 �4N THE STATE Alaska Oil and Gas �� 0fl 1L1 lSJ��l 1 i o QTR, GOVERNOR SEAN PARNELL 333 West Seventh Avenue O ��e. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1 433 SCANNED F7 ij i Fax: 907.276.7542 John McMullen d Engineering Team Leader oy D ,■ BP Exploration (Alaska), Inc. V' P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit, Kuparuk River Oil Pool, MPL-09 Sundry Number: 313-594 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair, ommissioner DATED this kw d y of November, 2013. Encl. a • STATE OF ALASKA RECEIVED • ALASKA OIL AND GAS CONSERVATION COMMIS ON APPLICATION FOR SUNDRY APPROVAL NOV 1 4 2013 20 AAC 25.280 AOGCC 1. Type of Request: ;.(4,U - -L•-t ❑Abandon - ®Plug for Redrill ❑Perforate New Pool ❑Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ❑Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 190-101 ' 3. Address: ❑Development ®Service 1 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22075-00-00 , 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? MPL-09 • Will planned perforations require a Spacing Exception? ❑Yes ®No 9. Property Designatior 10.Field/Pool(s): ADL 025509 • Milne Point/Kuparuk River Oil • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 8610'- 7529' - 8498' 7432' None Unknown Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 13-3/8" 35'- 115' 35'- 115' 2730 1130 Surface 4994' 9-5/8" 35'-5029' 35'-4619' 5120 2370 Intermediate Production 8562' 7" 35'-8597' 35'-7518' 7240 5410 Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 8107'-8276' . 7107'-7245' 3-1/2",9.3# L-80 8044' Packers and SSSV Type: 3-1/2"x 7" Baker SB-3 Packer; Packers and SSSV 7944'/6974' • 7"Otis BWD Packer MD(ft)and TVD(ft): 7986'/7008' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ❑Development IN Service . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation December 15,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Trevor Hyatt,564-4627 Printed Name: John McMullen Title: Engineering Team Leader Email: Trevor.Hyall @bp.com Signature: 1205 c Phone: 564-54711 Date: 1 / 1,, Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry Number: `2 r- - J q ❑Plug Integrity LV BOP Test ❑Mechanical Integrity Test ❑Location Clearance Other: -1( 3500 / 5` e6r -re-5 t p MC 2 ". tail) Spacing Exception Required? ❑Yes "No Subsequent Form Required: `0---'1p7 / . APPROVED BY 2 Approved By: COMMISSIONER THE COMMISSION Date: ,/—24 —/✓ Form 10-403 Revised 1 " 112 $ .4jnIsj4irE pp -?l li'r6/l3 Submit In Duplicate Appr• •• months from the date of approval �(•2.G•13 )3C c i 0-1/5 t\W13 ,oje „jf�B :, DEC 13 Lip, • • To: Alaska Oil & Gas Conservation Commission From Trevor Hyatt CTD Engineer Date: November 13, 2013 Re: MPL-09i Sundry Approval Sundry approval is requested to plug the MPL-09i perforations as part of the pre-rig prior to drilling and completing the proposed MPL-09Ai coiled tubing sidetrack. History of MPL-09i: MPL-09i was drilled and completed as an injection well in April of 1991. The well was cored, RFT'd, and frac'd before 2-7/8" tubing was run. It is completed in the A, B, and C sands of the Kuparuk. It was produced via natural flow until facilities injection tie-in was possible for L-Pad wells, and it was put on injection in early 1992. A RWO in 1998 installed 3-1/2" tubing and a stacker packer above the original 2-7/8" completion. The well received its first WAG slug in 1998 and remains a WAG injector. The well supports a large but baffled region of hydraulic unit 1L. Offset producer MPL-02 was sidetracked in 2010 and MPL-09 was planned to be sidetracked in tandem to support the new tri-lateral producer. However shortly before MPL-09 was supposed to be sidetracked the small ID tubing tail was discovered, preventing the ability of CTD to enter the well. J Reason for sidetrack: The bottom hole pressure of MPL-02A has been dropping over the tor(' 'i3 years and is in need of injection support. This MPL-09Ai sidetrack will •r•vi:- • sort for 'S tt'I� MPL-02A and also retain injection at its curren oca ion o support the other offset wells., f Proposed plan for MPL-09Ai: Drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around March 1st, 2014 with Nordic 2 using the managed pressure drilling technique. The sidetrack, MPL-09Ai, will exit the existing 7" casing anci-kla off in Kuparuk B sands. This sidetrack will be completed with a 3-1/4" liner x 2-7/8" solid/slotted liner. This Sundry covers plugging the existing MPL-09i perforations via the pre-rig coil cement job and MPL-09Ai liner top packer (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Po r. l 49 e x;sf ci wr� at- , r rr•2.0.3 i- v Pre-Rig Work (scheduled to begin Dec 15th,2013) PDS Caliper log inside 7" Casing from 8,200' MD up to 4-1/2" tubing tail. 1. S Drift for 4-1/2" x 7" TT whipstock. 2. E Set 4-1/2" x 7" TT whipstock top at 8,128' MD (WS pinch point at -8,132' MD). Cement whipstock in place by pumping 17 bbls of 15.8 ppg class G cement (attempt to down squeeze 16 bbls). Cement volume: Top WS to top open perfs: 1 bbls Squeeze: 8 bbls 3.* C Excess: 8 bbls 4. F MIT-T to 2,400psi. LLR if test fails. 5. V Torque tree & PT Tree/barriers - MV, SV, WV. 6. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange. 7. 0 Remove wellhouse, level pad, and install mouse hole and barricade. 8. V If MIT-T fails, set BPV & leave for the rig. * Approved alternate plug placement per 20 AAC 25.112(i) PEA" Rig Work (scheduled to begin March lst, 2014) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (2,749 psi MASP) 2. Mill 3.80" window at 8,128' and 10' of rathole. 3. Drill build section: 4.125" OH, 450' (40° deg/100 planned). 5. Drill lateral section: 4.125" OH, 1,793' (12° deg/100 planned) with resistivity. P"'J 6. Run 3-1/4" x 2-7/8" L-80 solid/slotted liner leaving TOL at 7,905' MD. (,D 7. Freeze protect well to 2500' MD 8. Set BPV, RDMO Post-Rig Work: 1. Pull mouse hole and fill with dirt, re-install wellhouse, flowline and pull BPV. 2. Set liner top packer with slickline &test to 2,500psi. 3. Set generic GLV's, SBHPS, ASRC flow back, SIT. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 0 • Tree: Cameron 4 1/16", 5M MPU L-09A KB Elevation: 56.00' Wellhead:FMC 11" x 11"5M, CTD Planned Sidetrack GL Elevation: 21.00' Gen.5 w/ 11"x 4.5"FMC Tbg Hgr w/4.5" NSCT threads top and 3.5" bottom and 4" CIW H BPV profile 4-1/16" CIW Tree 13 3/8",54.5 ppf, K-55 csg. 115' —2200'MD 4-1/2"XXO Nipple for SCSSSV w/Control lines 1 NOTE: 9-5/8",38#,K-55 btrs 5029' Starter Head was repaired with Furmanite clamp.Do Not MIT-OA above clamp rating of 1200 psi. 3.5"9.3 ppf,L-80 mod.eue 8rd tbg. ��� r,w � 14' (cap.=0.0087 bpf,drift=2.867' ` 7"26 ppf,L-80, Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) Max hole angle 37 degrees at 6700' 1 1 =7,788'MD-4.5"HES X-Nipple(3.813 id) --7,828'MD-4-1/2"x 7"HES pkr. --7,868'MD 4.5"HES X-Nipple(3.813 id) I I ,-,,,,,w/RHC plug Stimulation Summary u -7,905'MD TOL w LTP 3-1/2" at'MD 4/1/91 pumped 150,300#of 16/20 \_ 7928'MD-4-1/2"WLEG carbolite&25,710#of 12-18 carbo. Perforation Summary t.r-- Ref log:SWS CBT dated 3/31/91 350 I TOWS at 8,128'MD-Baker 4-1/2"x 7"TTWS 6 slotted beyond fault 0/" Size SPF Interval (TVD) C' 2� 4.5" 5 8107'-8128' 7106'-7123' • _, 2-7/8"Hyd 511 L-80 To-10,373' 4.5" 5 8135'-8150' 7128'-7141' 4.5" 5 8218'-8248' 7197'-7221' 4.5" 5 8263'-8276' 7234'-7244' — w v I I. PBTD 8500' FISH: W/L tool string and cutter bar �y Fish: 1-7/8" ball and catcher seat =" n7, 44.A 7", 26#, L-80 shoe 8597' DATE REV.BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27-E WELL L-09 06/25/98 MDO RWO Tbg.change out 27E API NO: 50-029-22075 BP EXPLORATION (AK) • • Tree: Cameron 4 1/16", 5M M P U L-09 i KB Elevation: 56.00' Wellhead:FMC 11" x 11"5M, GL Elevation: 21.00' Gen.5 w/ 11"x 4.5"FMC Tbg Hgr w/4.5" NSCT threads top and 3.5" bottom and 4" CIW H BPV profile y 4-1/16" CIW Tree 13 3/8",54.5 ppf, K-55 csg. 115' 3.5"HES X-Nipple(2.813 id) 2,214' i t y NOTE• 9-5/8",38#,K-55 btrs 5029' Starter Head was repaired with Furmanite clamp.Do Not MIT-OA above clamp rating of 1200 psi. i k. ,4 a IA fi D rte'" kb6 citi f 3.5"9.3 ppf,L-80 mod.eue 8rd tbg. , , � (cap.=0.0087 bpf,drift=2.86T f 7"26 ppf,L-80,Btrc.production casing . 1 (drift ID=6.151",cap.=0.0383 bpf) ; �f Max hole angle 37 degrees at 6700' r 3.5"HES X-Nipple(2.813 id) 7,931' • w41•111 " 3.5"x 7"Baker SB-3 pkr. 7,944' i I Stimulation Summary 3.5"HES XN-Nipple 7,969' 4/1/91 pumped 150,300#of 16/20 (No-Go 2.75 id; carbolite&25,710#of 12-18 carbo. 7"Otis BWD packer 7,986' w/4.00" ID w/seal. Perforation Summary _ 2-7/8" Otis XN nipple(2.2 5 id) 8,042, Ref log:SWS CBT dated 3/31/91 -- o• 2-7/8" PH Catcher sub 8,043' Size SPF Interval (TVD) 2-7/8"Otis WLEG 8,044' 4.5" 5 8107'-8128' 7106'-7123' ELMD 8,038' 4.5" 5 8135'-8150' 7128'-7141' _ 4.5" 5 8218'-8248' 7197'-7221' — 4.5" 5 8263'-8276' 7234'-7244' PBTD 8500' FISH: W/L tool string and cutter bar • ■ Fish: 1-7/8" ball and catcher seat .a z4, '' ' A 7",26#, L-80 shoe 8597' DATE REV.BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27-E WELL L-09 06/25/98 MDO RWO Tbg.change out 27E API NO: 50-029-22075 BP EXPLORATION (AK) I I w • I • o c 1 I Q N *► k \ S i e M 11 m i _t as m AI I \ war i� N .__...�- I °,2 s = : <, at VI S ° m I VI 1,1 ►41 • III 3 a a 3 I N d a jr� a ! i' I 3 ! i4 a I• I• = G m m1°� > G / 2-1 a a N m mo d a ® t 1 m O 60 0 ---. .J I 5 E 1O O w g t E 1` ' IA 1 i = P eprinet a< I E m 1 �j 1 a fa w W °' C9 i .� '0 1 H 1 1 aUla" I,4" (1:1 ... ......... I 1 y 0 u I I 1 ., �' OJ I M g u .. 1 Z I M.. 2 Co I . .I I 2' \ m f Z ♦ 1 m o \ u .� c 1 • I `5 1 m ■ i 41 I 1 1. U Q Y Y �: t 1 ` • M 1 •■ ■Ik�■ki NI ,, J 2s mi ° I i \ 1 V1.. II 1 ` 1 \ - 8 I • ® m Y f I fl � \ ° f11 o I y`' \ w j- 1 •rte { `-' 1 J f' I I , a I \ Ili c; W a _ 1 i ! _ \ \► \ °rx j±; �� 0 1 W"2 ='¢ x u_ • ',' y `r• .s. jj IQ O " 5 uj Z •U a o I aw• Ii 1 m 1 N o \� U 1 N w f / s 1 i'x U i, \ iI 1 qI \•.�• w•s . n o u il . I Z I �. • ?" J N iA, • ': \ :4 u 1 * a x I 11 .n ,.I 7 x,1, I O U 1a L �o I U O m g _ •• N n • ,_i f m '\ g a __ f ro f ✓ v \Q �7I f I = -�• u y o r O o c 0 U .I II I Ce p _ _1 x �W I i Z .c N N 2 _i a i . � U n z 6 I ° 1 I ht1 i•n � C o x u I u c I U i§d rya 11101.1.141 (ate. d 1 a 1_ Ea x I �a _ E �x �° a i 1 I a • • Page 1 of 1 Subject: FW: INTENT PLUG for RE-DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE-DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE-DRILL WELLS (IPBRD)Type Work Code in RBDMS 1. When a Form 10-403 is submitted requesting approval to plug a well for redrill,the initial reviewer(Art or Steve D.)will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2. On the Form 10-403 if"Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10-403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10-407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re-drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10-407. Steve will also change the status on the 10-407 form to SUSPENDED,and will date and initial his change. If Steve does not see the"Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10-407 into RBDMS. 5. When the Form 10-407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July,Steve M.and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D.will also review the list of suspended wells for accuracy. Thanks, Steve D. ,cv THE STATE Alaska Oil and Gas or LAsiKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, ALAS e, Alaska 99501-3572 i ,,, Main: 907.279.1433 O8A51 .P Fax: 907.276.7542 SC Alex Youngmum Production Engineer ©' BP Exploration (Alaska), Inc. Igo- I P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Kuparuk Oil Pool, KUP MPL-09 Sundry Number: 313-590 Dear Ms. Youngmum: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy '. Foerster Chair, Commissioner DATED this' day of November, 2013. Encl. • • -' VRECEWE STATE OF ALASKA ,13: ALASKA OIL AND GAS CONSERVATION COMMISSION V NOV 13 2013 APPLICATION FOR SUNDRY APPROVALS '�//��Sff�����/ 8/((``I!!3 20 AAC 25.280 O''►V GC,✓ 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Convert to Injector 0• 2.Operator Name: 4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Exploratory ❑ Development IS 190-101-0 3.Address: Stratigraphic ❑ Service ❑ 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22075-00-00 • 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? KUP MPL-09 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 , MILNE POINT, KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft):? Total Depth TVD(ft):043 Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): X97.$(e I O 75 Z'( 8500 . 7434 • None 8477,8478 Casing Length Size MD TVD Brest Collapse Structural Conductor 79 13-3/8"54.5#J-55 36-115 36-115 2734 1128 Surface 4994 9-5/8"36#K-55 35-5029 35-4619.34 3520 2020 Intermediate None None None None None None Production 8562 7"26#L-80 35-8597 35-7517.67 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program IS BOP Sketch ❑ Exploratory ❑ Development ❑ Service El 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 0 � Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Alex Youngmum Email .1JtirNGk(_bc •r, r- Printed Name Alex Youngmum Title Production Engineer I Signature (102,4 Phone 564-4864 Date I I I 1,2/0/013 Prepared by Garry Catron 564-4424 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 1 V " 5ck.U Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Spacing Exception Required? Yes ❑ No 12 Subsequent Form Required: RBEAVIS APPROVED BY / Approved by: COMMISSIONER THE COMMISSION Date: //_ ( 3 RoleGI A ' A h l� 11� lI � ///��' Form 10-403 Revised 10/2 12 • ``I).0 iQ�jtr f v lid for 12 months from the date of approval. Submit orm and Attachments in Duplicate VVV 1 r///"'111 0 Perforation Attachment ADL0025509 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPL-09 4/4/91 PER 8107 8128 7107 7124 MPL-09 4/4/91 PER 8135 8150 7129 7141 MPL-09 4/4/91 PER 8218 8248 7197 7222 MPL-09 4/4/91 PER 8263 8276 7234 7245 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF Casing Summary ADL0025509 Casing Length Size MD Top MD Base ND Top ND Base Burst Collapse Grade CONDUCTOR 79 13-3/8" 54.5#J-55 36 115 36 115 2734 1128 J-55 PRODUCTION 8562 7"26# L-80 35 8597 35 7518 7240 5410 L-80 SURFACE 4994 9-5/8" 36#K-55 35 5029 35 4619 3520 2020 K-55 TUBING 2 2-7/8"6.5#L-80 8042 8044 7054 7056 10570 11160 L-80 TUBING 18 2-7/8"6.5# L-80 7979 7997 7003 7017 10570 11160 L-80 TUBING 7948 3-1/2" 9.3# L-80 31 7979 31 7003 10160 10530 L-80 411 • S • Packers and SSV's Attachment ADLOO255O9 Well Facility Type MD Top Description TVD Top MPL-09 PACKER 7943 —3-1/2"X 7" Baker SB-3 Packer 6973 MPL-09 PACKER 7986 7"Otis BWD Packer 7008 S • bP BP Exploration(Alaska)Inc. 900 East Benson Blvd. Anchorage,Alaska 99508 1,907.564.5111 November 11th, 2013 Ms.Victoria Ferguson Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage,Alaska 99501 Subject: MPL-09 Reclassification from Producer to Injector Dear Ms. Ferguson, BP Exploration (Alaska) Inc. requests approval for reclassifying MPL-09 from a producer to injector. The nature of MPL-09's isolated bottom hole had previously allowed it to build pressure outside of the range required by the Coil Tubing Drilling rig to safely sidetrack the wellbore. Earlier this year, from June 29th, 2013 through July 27th, 2013(28 days), MPL-09 was allowed to flowback to the Milne Point facility. This flowback resulted in lowering the bottom hole pressure to within an acceptable range for the Coil Tubing Drilling rig to safely sidetrack the well. However, upon pulling downhole gauges which were set for monitoring flowing bottom hole pressures during the flowback, it was noted that the pressure build-up rate would exceed the maximum acceptable sidetracking pressure prior to the rig's arrival. Thus, necessitating the need to flowback an additional volume to provide additional assurance for pressure stabilization prior to the coil sidetrack. Approval was granted on September 5th, 2013 to change the classification of MPL-09 from an injector to producer to allow for flowing back the injector for a period of time greater than 30 days. The second flowback lasted from September 23`x, 2013 through September 24th, 2013 (2 days). MPL-09 flowed back for 2 days opposed to 28 days during the first flowback due to low rates and velocities, with the decision being made to shut the well in due to cold temperatures to prevent the well or surface piping from freezing. MPL-09 is now in an acceptable pressure range for the Coil Tubing Drilling rig to safety sidetrack the well. MPL-09 is the subject of a proposed sidetrack which will relocate the well to provide conformance with its offset producer MPL-02A. In summary, BPXA requests reclassification of MPL-09 from producer to injector status. If you require any additional information, please contact me at 564-4864. Sincerely, (0010 NeY /164.--e Alex Youngmun Milne Point Unit F&L Pad Petroleum Engineer NNW • • Tree: Cameron 4 1/16", 5M M P U L-09i KB Elevation: 56.00' Wellhead:FMC 11" x 11"5M, GL Elevation: 21.00' Gen.5 w/ 11"x 4.5"FMC Tbg Hgr ; w/4.5"NSCT threads top and 3.5" bottom and 4" CIW H BPV profile 4-1/16" CIW Tree ■ 13 3/8",54.5 ppf,K-55 csg. 115' 3.5"HES X-Nipple(2.813 id) 2,214'■ NOTE: 9-5/8',38#,K-55 btrs 5029' Starter Head was repaired with Furmanite clamp.Do Not MIT-OA above clamp rating of 1200 psi. 3.5"9.3 ppf,L-80 mod.eue 8rd tbg. (cap.=0.0087 bpf,drift=2.867' 7"26 ppf, L-80,Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) Max hole angle 37 degrees at 6700' 3.5"HES X-Nipple(2.813 id) 7,931' 3.5"x 7"Baker SB-3 pkr. 7,944' Stimulation Summary 3.5"HES XN Nipple 7,969, 4/1/91 pumped 150,300#of 16/20 (No-Go 2.75 id •carbolite&25,710#of 12-18 carbo. 7"Otis BWD packer 7,986' w/4.00"ID w/seal: Perforation Summary 11 AIR Ref log:SWS CBT dated 3/31/91 2-7/8"Otis XN nipple(2.205 id) 8,042' _ 2-7/8"RH Catcher sub 8,043' Size SPF Interval (TVD) [1 2-7/8"Otis WLEG 8,044' 4.5" 5 8107'-8128' 7106'-7123' ELMD 8,038' 4.5" 5 8135'-8150' 7128'-7141' 4.5" 5 8218'-8248' 7197'-7221' _ 4.5" 5 8263'-8276' 7234'-7244' - i _ PBTD 8500' FISH: W/L tool string and cutter bar •y Fish: 1-7/8"ball and catcher seat 7",26#,L-80 shoe 8597' DATE REV.BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27-E WELL L-09 06/25/98 MDO RWO Tbg.change out 27E API NO: 50-029-22075 BP EXPLORATION (AK) F TAN I%%s� THE STATE Alaska it and s °f Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 LASY' Main: 907.279.1433 `El Fax: 907.276.7542 Christopher Stone ����� � � ' Petroleum Engineer BP Exploration(Alaska), Inc. 0- 101 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Field, Kuparuk River Oil Pool, KUP MPL-09 Sundry Number: 313-457 Dear Mr. Stone: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. Foerster Chair DATED this S day of September, 2013. Encl. 1 t` '11 RECEIVE[ • STATE OF ALASKA O �,� EAU G/22 2013 ALASKA OIL AND GAS CONSERVATION COMMISSION '1 APPLICATION FOR SUNDRY APPROVALS AOGCC 20 AAC 25.280 1.Type of Request: Abandon❑ Plug for Redrill❑ Perforate New Pool❑ Repair Well❑ Change Approved Program❑ Suspend❑ Plug Perforations❑ Perforate❑ Pull Tubing❑ Time Extension❑ Operations Shutdown❑ Re-enter Susp.Well❑ Stimulate❑ Alter Casing❑ Other. Iniection Well Flowback El 2.Operator Name: '4.Current Well Class: 5.Permit to Drill Number. BP Exploration(Alaska),Inc. Development ❑ Exploratory ❑ 190-101-0• 3.Address: Stratigraphic ❑ Service El• 6.API Number. P.O.Box 196612,Anchorage,AK 99519-6612 50-029-22075-00-00 7.If perforating: 8.Well Name and Number. What Regulation or Conservation Order governs well spacing in this pool? 432D KUP MPL-09 • Will planned perforations require a spacing exception? Yes ❑ No ❑ 9.Property Designation(Lease Number): 10.Field/Pool(s): ADL0025509 ' MILNE POINT, KUPARUK RIVER OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth ND(ft): Plugs(measured): Junk(measured): 8597• 7518 - 8500 - 7434 - None See Attachment Casing Length Size MD TVD Burst Collapse Structural Conductor 79 13-3/8"54.4#K-55 36-115 36-115 Surface 4994 9-5/8"36#K-55 35-5029 35-4619.34 3520 2020 Intermediate None None None None None None Production 8563 7"26#L-80 34-8597 34-7517.67 7240 5410 Liner None None None None None None Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): See Attachment• See Attachment See Attachment See Attachment See Attachment Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD(ft)and ND(ft): See Attachment for Packer Depths No SSSV Installed No SSSV Installed 12.Attachments: Description Summary of Proposal ❑ 13.Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service IN 14.Estimated Date for 15.Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16.Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 111 Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Christopher Stone Email Christt,her.StoneCcabo.com Printed Name Christopher Stone Title PE Signature Phone Date Afichj471.0-- 564-5581 8/22/2013 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number. 31 3 -y 67 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: ABE M` OCT 1 0 201,\''\. Spacing Exception Required? Yes ❑ No 7{ Subsequent Form Required: /0 - 4 L7 z APPROVED BY Approved by: , COMMISSIONER THE COMMISSION Date: ' '_ 3-----/ 3 Form 10-403 Revised 1/2010 Appro ty�± i fyy��12 months from the date of approval. Submit in Duplicate k\ �\,� 1/L-r° e7%5/I�3 �V H 072_3* b • • p 0 BP Exploration(Alaska)Inc. 900 East Benson Blvd. Anchorage,Alaska 99508 August 22, 2013 1.907.564.5111 Ms.Victoria Ferguson Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: MPL-09 Reclassification from Injector to Producer Dear Ms. Ferguson, BP Exploration (Alaska) Inc. requests approval for flowing back injector Milne Point well MPL-09 for a period of time greater than 30 days. This request will require the reclassification of MPL-09 from an injector to producer. MPL-09 is an injector located in a hydraulically isolated fault block in the Milne Point Kuparuk formation. It is the subject of a proposed sidetrack which will relocate the well to provide conformance with its offset producer MPL-02A. The nature of MPL-09's isolated bottom hole has allowed it to build pressure outside of the range required by the Coil Tubing Drilling rig to safely sidetrack the wellbore. Earlier this year, from June 29, 2013 through July 27, 2013 (28 days) MPL-09 was allowed to flow back to the Milne Point facility, this flowback resulted in lowering the bottom hole pressure to within an acceptable range for the Coil Tubing Drilling rig to safely sidetrack the well. However, upon pulling downhole gauges which were set for monitoring flowing bottom hole pressures during the flowback, it was noted that the pressure build-up rate would exceed the maximum acceptable sidetracking pressure prior to the rig's arrival. Thus necessitating the need to flowback an additional volume to provide additional assurance for pressure stabilization prior to the coil sidetrack. In summary, BPXA request reclassification of MPL-09 from injector to producer status. If you require any additional information, please contact me at 564-5518. Sincerely, 7141✓���--- Christopher Stone Milne Point Unit F &L Pad Petroleum Engineer • 0 Perforation Attachment ADL0025509 Well Date Perf Code MD Top MD Base TVD Top TVD Base MPL-09 3/15/11 BPP 8107 8128 7107 7124 MPL-09 3/15/11 BPP 8135 8150 7129 7141 MPL-09 3/15/11 BPP 8218 8248 7197 7222 MPL-09 3/15/11 BPP 8263 8276 7234 7245 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK,CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADLOO255O9 Well Facility Type MD Top Description TVD Top MPL-09 PACKER 7944 3-1/2"X 7" Baker SB-3 Packer 6974 MPL-09 PACKER 7986 7"Otis BWD Packer 7008 • • Tree: Cameron 41/16", 5M MPU L-09i KB Elevation: 56.00' Wellhead:FMC 11" x 11"5M, GL Elevation: 21.00' Gen.5 w/ 11"x 4.5"FMC Tbg Hgr 4.5"NSCT threads top and 3.5" bottom and 4" CIW H BPV profile 1 4-1/16" CIW Tree 13 3/8",54.5 ppf,K-55 csg. 115' 3.5"HES X-Nipple(2.813 id) 2,214' I X 9-5/8",38#,K-55 btrs 5029' A V.Z.Head was repaired with Furmanite damp.Do Not MIT-OA above clamp rating of 1200 psi. I 3.5"9.3 ppf,L-80 mod.eue 8rd tbg. (cap.=0.0087 bpf,drift=2.867' 7"26 ppf,L-80,Btrc.production casing (drift ID=6.151",cap.=0.0383 bpf) ' Max hole angle 37 degrees at 6700' If 3.5"HES X-Nipple(2.813 id) 7,931' 3.5"x 7"Baker SB-3 pkr. 7,944' I Stimulation Summary 3.5"HES XN-Nipple 4/1/91 pumped 150,300#of 16/20 (No-Go 2.75 id 7,969 carbolite&25,710#of 12-18 carbo. 7"Otis BWD packer 7,986' w/4.00"ID w/seal= Perforation Summary IN at Ref log:SWS CBT dated 3/31/91 2-7/8"Otis XN nipple(2.205 id) 9,042' _ 2-7/8"RH Catcher sub 8,043' Size SPF Interval (TVD) 2-7/8"Otis WLEG 8,044' 4.5" 5 8107'-8128' 7106'-7123' ELMD 8,038' 4.5" 5 8135'-8150' 7128'-7141' 4.5" 5 8218'-8248' 7197'-7221' r- 4.5" 5 8263'-8276' 7234'-7244' - i• ',... PBTD 8500' FISH: W/L tool string and cutter bar *y Fish:1-7/8"ball and catcher seat 7",26#,L-80 shoe 8597' i DATE REV.BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27-E WELL L-09 06/25/98 MDO RWO Tbg.change out 27E API NO: 50-029-22075 BP EXPLORATION (AK) ! • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: Monday, March 21, 2011 P.I. Supervisor SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC L -09 FROM: Matt Herrera MILNE PT UNIT KR L -09 Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry J — NON- CONFIDENTIAL Comm Well Name: MILNE PT UNIT KR L -09 API Well Number: 50- 029 - 22075 -00 -00 Inspector Name: Matt Herrera . Insp Num: mitMFH110320150319 Permit Number: 190 -101 -0 - Inspection Date: 3/20/2011 - Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well L -o9 ' Type Inj. w" TVD 6974 - IA o 2280 2270 2270 - P.T. 1901010 TypeTest SPT Test psi 1743 - OA 0 160 160 160 Interval 4YRTST L p/F P . Tubing moo I moo moo 1000 Notes: r }r�.t :' AP APE 1 3 2 -U l Monday, March 21, 2011 Page 1 of 1 STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other 0 FURMANITE REPAIR Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waived] Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ r 190 -1010 3. Address: P.O. Box 196612 Stratigraphic Service IS 6. API Number: Anchorage, AK 99519 -6612 . 50- 029 - 22075 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 025509 .. MPL -09 10. Field /Pool(s): MILNE POINT UNIT FIELD / KUPARUK RIVER SANDS POOL 11. Present Well Condition Summary: Total Depth measured 8610 feet Plugs (measured) None feet true vertical 7529 feet Junk (measured) 8477, 8478 feet Effective Depth measured 8500 feet Packer (measured) 7944 7986 feet true vertical 7437 feet (true vertical) 6974 7008 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 13 -3/8" 54.5# K -55 36 - 115 36 - 115 2730 1130 Surface 4994' 9- 5/8 "36# K -55 35 - 5029 35 - 4619 5120 2370 Production 8563' 7" 26# L -80 34 - 8597 34 - 7518 7240 5410 Production Liner �j Liner MAR 2 2 'MI Perforation depth: Measured depth: SEE ATTACHED - _ True Vertical depth: _ Tubing: (size, grade, measured and true vertical depth) 3 -1/2" 9.3# L -80 32 - 7986 32 - 7008 2 -7/8" 6.5# L -80 7986 - 8044 7008 - 7056 Packers and SSSV (type, measured and true vertical depth) 3 -1/2" X 7 BAKER SB -3 PKR 7 6974 7" OTIS BWD PACKER 6ECE V r 12. Stimulation or cement squeeze summary: MAR (1Mk Intervals treated (measured): Alaska Oil 81 Gas Cons. Commission Treatment descriptions including volumes used and final pressure: Anchorage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ❑ Service 0 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ • GSTOR ❑ WINJ ❑ WAG Ell GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -041 Contact Joe Lastufka Printed Na - • - Lastu Title Data Manager Signatu . 111MiliA. Phone 564 -4091 Date 3/14/2011 HBDMS MAR 21 2011 KaVh o � . � i'i Form 10 -404 Revised 10/2010 / 3 Z Submit Original Only oe %40/ MPL-09 190 -101 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPL -09 4/4/91 PER 8,107. 8,128. 7,106.55 7,123.58 MPL -09 4/4/91 PER 8,135. 8,150. 7,129.26 7,141.46 MPL -09 4/4/91 PER 8,218. 8,248. 7,197.01 7,221.65 MPL-09 4/4/91 PER 8,263. 8,276. 7,234. 7,244.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • 1 MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • MPL -09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY � � � �� � F�� , � � �,.... u 3/10/2011 T /I /O =SSV /450/40. Temp =SI. Bleed IA & OA to 0 psi, prep cellar, remove grating, !clean wellhead (pre - Furmanite). IA FL @ surface. OA FL near surface. Bled OAP from 40 psi to 0 psi in 3 mins (all gas). Bled IAP from 450 psi to 0 psi in 4 hrs (fluid /gas). Monitored 30 mins. IAP increased 2 psi, OAP remained the same. Pulled floor grating & Super Sucked 2 yds gravel from cellar. Cleaned SH to prep for Furmanite clamp. Flagged & tagged entry for open cellar. Final T /I /O= SSV /2/0. ** Job in Progress ** SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. 3/13/2011 T /I /O = SSV /0 +/10. Temp = SI. MIT -OA to 1200 psi w /triplex PASSED (post I Furmanite clamp). OA FL @ surface. Furmanite installed clamp_around SH. !Increased OAP to 1190 psi with 1 bbl MEOH (test pressure ok per WIE). OAP lost ;40 psi in 1st 15 min and 10 psi in 2nd 15 min fora total Toss of 50 psi in 30 min. No sign of leaks from clamp. Bled OAP to 10 psi. Job complete. Final WHPs = SSV /0 +/10. SV, WV, SSV =C. MV =O. IA, OA =OTG. NOVP. FLUIDS PUMPED BBLS 1 MEOH 1 TOTAL • • • Tree: Cameron 4 1/16", 5M KB Elevation: 56.00' Wellhead: FMC 11" x 11" 5M, MPU L -09i GL Elevation: 21.00' Gen. 5 w/ 11" x 4.5" FMC Tbg. Hnr. w/ 4.5" NSCT threads top and 3.5" 4 -1 /16" CIW Tree bottom.and 4" CIW H BPV profile 13 3/8 ", 54.5 ppf, K -55 csg. 1 115' 3.5" HES X- Nipple (2.813 id)I 2,214' 9 -5/8 ", 38#,K -55 btrs 5029' [ a' t i 3.5" 9.3 ppf, L -80 mod. eue 8rd tbg. (cap. = 0.0087 bpf, drift = 2.867' 7" 26 ppf, L -80, Btrc. production casing € ( drift ID = 6.151", cap. = 0.0383 bpf) ?, Max hole angle 37 degrees at 6700' 3.5" HES X- Nipple (2.813 id) 1 7,931' 3.5 "x 7" Baker SB -3 pkr. I 7,944' Stimulation Summary 3.5" HES XN- Nipple 4/1/91 pumped 150,300# of 16/20 1 7,969' p p (No Go 2.75 id; carbolite & 25,710# of 12 -18 carbo. 7" Otis BWD packer 7,986' w/ 4.00" ID w/ seal Perforation Summary 2 -7/8" Otis XN nipple ( 2.205 id) 8,042' Ref log: SWS CST dated 3/31/91 2 -7/8" RH Catcher sub 8,043' Size SPF Interval (TVD) 2 -7/8" Otis WLEG 8,044' 4.5" 5 8107' -8128' 7106-7123 ELMD 8,038' 4.5" 5 8135' -8150' 7128' -7141' 4.5" 5 8218' -8248' 7197' -7221' 4.5" 5 8263' -8276' 7234' -7244' - 1 FISH: W/L tool string and cutter bar • PBTD 8500' Fish: 1 -7/8" ball and catcher seat 7 ", 26#, L -80 shoe 1 8597' DATE REV. BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27 -E WELL L -09 06/25/98 MDO RWO Tbg. change out 27E API NO: 50- 029 -22075 BP EXPLORATION (AK) • • S lac [E ARLSEA SEAN PARNELL, GOVERNOR t1 ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276-7542 Josh Chebul I O 1 Petroleum Engineer d BP Exploration (Alaska), Inc. 1 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Milne Point Field, Kuparuk River Sands Pool, MPL -09 Sundry Number: 311 -041 FE43 GA, 52. Dear Mr. Chebul: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this Z. day of February, 2011. Encl. MIL, MI If CVO. z ALAS AND GAS CON ERVAT ON COMMISSIc � 6 c � - � �E 1$ 2011 , ( APPLICATION FOR SUNDRY APPROVALS Gas Con, C® 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change AWSTFIGram ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate Alter Casing ❑ Other: FURMANITE REPAIR El 2. Operator Name: 4. Current Well Class: i 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development �T,jj,Exploratory ❑ 190 -1010 . 3. Address: P.O. Box 196612 Stratigraphic ,i 7,, Service is • 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22075 -00 -00 , 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No ❑ MPL -09 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 025509 • MILNE POINT UNIT Field / KUPARUK RIVER SANDS Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): , Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): / f v r,Ti �'(( 8500 7436.66 NONE 8477,8478 .— SV Z.- Casing k y y I Length 7 a-: ° Size MD TVD Burst Collapse Structural Conductor 79' 13 -3/8" 54.5# K -55 36 115 36 115 2730 1130 Surface 4994' 9 -5/8" 36# K -55 35 5029 35 4619 5120 2370 Production 8563' 7" 26# L -80 34 8597 34 7518 7240 5410 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 3 -1/2" 9.3# L -80 32 7986 - - 2 -7/8" 6.5# L -80 7986 8044 Packers and SSSV Tvpe: 7" BAKER SB -3 PACKER Packers and SSSV MD and TVD (ft): 7944 6974 7" OTIS BWD PACKER 7986 7008 12. Attachments: Description Summary of Proposal © 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 . 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 3/4/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG El • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josh Chebul Printed ■ - e Josh Chebul / , Tit P j Sign ure / / 4 !' J 7 one Date 564 - 4673 2/18/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditi s of approval: Notify Commission so that a representative may witness Sundry Number: �, " O { ( .. ntegrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /d `Lf L/ ) . 1 APPROVED BY (c' Approved by: f COMMISSIONER THE COMMISSION Date: Z 1 yJ 1 I R6 2 5 X01 G I n t / � Form 10 -403 Revised 1/2010 - 1 V t1 Su1 g ntiy . 7 177 MPL-09 . 190 -101 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base MPL -09 4/4/91 PER 8,107. 8,128. 7,106.55 7,123.58 MPL -09 4/4/91 PER 8,135. 8,150. 7,129.26 7,141.46 MPL -09 4/4/91 PER 8,218. 8,248. 7,197.01 7,221.65 MPL -09 4/4/91 PER 8,263. 8,276. 7,234. 7,244.72 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • bp 0 Date: February 17, 2011 To: Jerry Bixby /Rob Liddelow, AK, D &C Wireline Operations Team Lead Clark Olsen/Tyler Norene, AK, D &C Well Services Team Lead From: Tiffany Quy /Mehreen Vazir, Projects Well Integrity Engineer 659 -5098, Harm #2418 Subject: MPL -09 Furmanite Clamp Starting Head Repair Est. Cost: AFE: AMKLPDWL09 IOR: 300 Step Type Procedure 1 D Prep cellar, remove grating, clean wellhead. 1 W Install Furmanite clamp and inject resin to repair SH leak. 2 D MIT -OA to 1200 psi, LLR if Fails. 3 SP Pull TTP. (pending successful SH repair) Objective: This work is to repair an upper starting head thread leak using a clamp injected with a composite resin. Once the leak is mitigated, the TTP will be pulled and the well °1 returned to Operable status. Well Stats: Well Status: Secured with TTP @ 8042' and Not Operable for SH leak Last injectivity: 8/2/10 — 1460 psi & 861 bwpd Deviation: Max 38° @ 6691' MD Min ID: 2.205" XN @ 8042' Last SBHPS: 10/10/10 — 3704 psi & 139 °F @ 7000'TVD SSSV: N/A - 3.5" HES X- Nipple (2.813" ID) @ 2214' MD Last H2S: N/A — injector Last MIT -T: Passed 3200 psi — 10/11/2010 Last MIT -IA: Passed 4200 psi — 10/11/2010 Last MIT -OA: Failed 1000 psi — 10/11/2010 Well Events Summary: MPL -09 is a WAG injector which was completed in 1991 and worked over in 1998 with 3.5" L -80 tubing. It has a SH leak confirmed with a MIT -OA 10/11/10. The upper thread leak was observed at 1500 psi during a MIT -OA 10/11/10. This leak was treated with Seal -Tite to 1500 psi 12/07/06 and has remained Operable since then. Well passed a MIT -IA to 4200 psi 10/11/10. MPL -09 has no other known integrity concerns. > 05/25/06: MP WOS informed well has a bradenhead leak. Notified Maunder with voice mail message. > 12/07/06: Seal -Tite repair on bradenhead successful to 1500 psi > 01/04/07: 10 -404 for Bradenhead repair sent to AOGCC • • > 04/06/07: AOGCC MIT -IA Passed to 2000 psi > 10/09/10: PPPOT -T Passed to 5000 psi, PPPOT -IC Passed to 3500 psi > 10/11/10: Set TTP @ 8042', MIT -T Passed to 3200 psi, MIT -IA Passed to 4200 psi, MIT -OA Failed due to leaking SH at 1000 psi Please call Tiffany Quy /Mehreen Vazir at 907 - 659 -5098, Harm #2418 with any questions or concerns regarding this program. Cc: Well File AK, D &C Well Integrity Engineer Program Discussion BP Alaska has successfully repaired one Starting Head leak with a Furmanite clamp . enclosure patch application to date. Enclosures are an alternative repair to composite wraps or welding. In this wellbore configuration there is not enough overlap to repair the thread leak with a rated composite wrap. An enclosure is preferred over welding due to the reduction in overall risk from open flame or spark sources and the reduction ' in well preparation (securing, circulating, and evacuation of fluids). Enclosure patches are also often used to repair flanges in Gathering Centers and Flow Stations in Prudhoe Bay. Safety & Environmental Plan A full and complete Authorization to Proceed and MOC process will be completed prior to job execution. During this process an in depth review of the project will be conducted ensuring that all aspects adhere to BP's policies and procedures including BP's Integrity Management Standard, Environmental Management System, Drilling and Wells Operations Policy, 8 BP Golden Rules of Safety, and the Alaska Safety Handbook. As per policy and standard operating procedure, each job will begin with a daily Job Safety & Environment Assessment where all pertinent task information and risks will be communicated to all personnel involved. Another Job Safety & Environmental Assessment will be performed at each stage of work and before any scope change. Any and all safety and environmental incidents will be reported, and any injury will be assessed by the local medic. Due to the trial or testing status of these jobs a BP well site leader will be required on location for the entire duration of the project. Safety Focus While all hazards and risks have the potential to cause incidents, the focus of concern for this work include the following. - Lifting the clamp components. Each of the the clamp halves weigh —90 lbs. The plan is to have the two Furmanite technicians carry each clamp half to the Wellhouse and place on the wellhouse floor. They will enter the cellar and place the component on the starting head resting on the Tanko dust cover. A DHD technician or roustabout will assure the clamp remains in place while the Furmanite technicians repeat with the second enclosure half. o The lift plan pre job safety meeting will identify particularly hazardous areas and times of operation that could cause a "pinch" or entrap a poorly placed hand, arm, or foot such as picking, setting, and installing the clamp in place around the starting head. If the manual lift plan needs to be revised, the operation will be shut down and a new plan involving a mechanical lift will be considered to continue work. • • o Chain rigging will be available on location in case it is needed in the positioning and alignment of the clamp halves. This will be determined on site and will be a stop point if required. o Using a lifting plan similar to the previous application on 12 -16 was considered. The 12 -16 program used a boom truck to move the enclosure into the wellhouse and chain riggers attached to the tubing head adapter to lower the clamp into place. The weight of this enclosure is much less ( -90 Ibs vs. 260 Ibs per half). It is thought that with this lighter installation, adding the extra equipment and personnel on location could increase potential risks and exposure to injury for this work. - Working in a cellar with grating removed. Working in a cellar may increase potential exposure to gases and subsidence and the removal of the grating may increase potential tripping hazards. The work area will be flagged and walked down to assure all personnel on location are aware of potential uneven work areas and exposure to the uncovered cellar. The IA & OA will be bled down and the cellar sniffed before entry. A watch will be in place outside the cellar through out all operations within the cellar. Well Integrity Engineer: Pre -Job Planning 1. Ensure 10 -403 has been approved by the AOGCC before progressing this repair. 2. Ensure MOC has been approved internally before progressing this repair. 3. Notify Special projects that the trailer is planned to be in use March 9 -22. DONE 2/12/11 4. Confirm SH condition with UT inspection. DONE 5. Confirm lead paint results. DONE (wellhead tested positive for lead. This will be an awareness topic but no further PPE is required as there will be no blasting or grinding done.) 6. MIT -IA to prove operability within 6 months of repair. DONE - MIT -IA passed to 4200 psi 10/11/10. 7. Obtain clamp engineering design. DONE (attached) 8. Obtain NCE form for resin and include in field binder - NCE Submitted 2/15/11 9. Order the following equipment with Milne Point (or deliver from GPB if needed): a. Air compressor for Furmanite pneumatic pump. b. 2 heaters (1 for the cellar and one for the projects trailer) 10.Assure all cellar prep has been done in advance (grating removal, gravel removal, bleeds, clean SH). 11. Coordinate for chain rigging to be installed on the wellhead for use if needed. 12. Coordinate with Furmanite to deliver clamp and resin in the Special Projects trailer. 13. Confirm with Furmanite if methanol will be a limitation in this installation. 14. Billeting at MP for (1) WSL, (2) Furmanite representatives, and (1) DHD technician. Procedure DHD: Well and Well House Preparation 1. Conduct pre -job safety and hazard identification meeting, ensuring that all known hazards have been adequately mitigated and contingency or emergency plans have been communicated. 2. Bleed IA & OA to 0 psi so that no one will be working around any pressure in the cellar. • 3. Install heater in cellar for at least two days before arrival to thaw out the gravel for removal. 4. Remove grating from Wellhouse to allow easy access to the casing /starting head. 5. Flag and tag the doors of the Wellhouse to alert others of potentially hazardous footing conditions. 6. Remove -2' of gravel from the cellar to expose starting head /conductor to make the casing head easier to access for clamp installation. Try to maintain a cellar depth of less than 4 feet. Level the floor and assure containment is installed. If possible, step the gravel up to assure easier egress of the cellar area. 7. Remove metal clamp /ring attached to the starting head. 8. Clean the starting head from the conductor cover up to the OA flange connection with Orange Sol. Keep markings of SH leak point on wellhead for Furmanite installation. 9. Remove stainless steel risers from IA & OA valves for access. 10. Be sure culvert (7') e su a to note cellar condition, cellar depth, cellar and cu ert measurements, clamp removal, and grating condition in AWGRS. Wellhead: Install Furmanite Clamp 1. Obtain Unit Work Permit from Milne Point. Conduct pre job safety and hazard identification meeting, ensuring that all known hazards have been adequately mitigated and contingency or emergency plans have been communicated (see Attached PJSM sheet). Assure there is a sign in sheet for all personnel on location. Attendees to consider for the pre -job include: Furmanite Technicians DHD Technician assigned to the job Well Integrity Engineer MP WSL Pad / Drill Site Operator (optional) 2. Monitor WHPs to ensure the OA is <50 psi before working in the cellar. 3. Sniff the cellar prior to entering to ensure air quality. 4. Walk down job site and confirm lifting plan of clamp with all involved. The estimated clamp assembly weight is -190 lbs. Each half weighs -90 lbs. There are feet on the clamp which will help support it on the Tanko dust cover over the conductor once in place around the starting head. a. Each half will require two people to lift and transport. b. Once the clamp halves are in place resting on the dust cover, a technician will support each half while the bolts are installed and torqued to Furmanite specifications. c. Chain rigging will be on location if needed due to issues positioning and aligning the clamp. This will be a stop point to asses the situation before continuing with the work. 5. Once the clamp is installed and the bolts tightened, Furmanite Technician will conduct a visual inspection to determine if "peening" is needed. a. The clamp is machined to fit against a perfectly circular starting head. It is finished on top and bottom with a 1/8" 45 degree angle referred to as the 'Peening Groove' to compensate for an imperfect circle. An air hammer with a blunt nosed cold chisel is used to push the metal of the edge of the patch flush against the starting head to contain the sealant during the injection process. b. Peening will be kept to a minimum and does not compromise the integrity or pressure rating of the clamp or starting head. • c. Use of a cold chisel eliminates sparking potential. 6. Install shut off adapters in each injection point in the open position. 7. On the upper seal ring, select starting point for injection. This should be 180° from the leak origin (leak is at 8:00 position). a. Close shut off adapter and attach injection gun to the shutoff adapter and air compressor. b. Open shutoff adapter and begin injection. c. Use minimum injection pressure (not to exceed a maximum pressure of 2000 psi) until sealant is observed to extrude from the neighboring injection points. d. Stop injection, close shut off adapter, and remove the injection gun. e. Install injection adapter plug into port using an approved anti -seize compound. f. Move to neighboring injection point in a clockwise direction and repeat injection steps for each injection port. DHD: MIT -OA and return well to Operations 1. MIT -OA to 1200 psi. LLR if Fails. a. If the clamp enclosure shows no indications of leakage during or after the MIT -OA, the well may be reclassified and returned to injection. b. Once well is brought online, monitor once daily for a period of 3 days to check for signs of continued leakage. 2. Replace riser gauges. 3. Replace floor grating. 4. RDMO DHD and Furmanite. Slickline: Pull TTP 1. Pull XXN TTP from 8042' MD. Plug was set on a second attempt 10/11/10. 2. RDMO SL. Notify MPU Operations of well status. Well Integrity Engineer: Assure clamp is documented as needed 1. Notify Gary Preble that the work is complete and a 10 -404 is required. 2. Assure AWGRS documentation includes patch installation. 3. Assure a package for the enclosure program is filed in the well file. • • Enclosure Clamp Checklist Responsibl 1. Pre -Job Planning e Party Y N Initials 1 Well specifics and history reviewed by Well Integrity Engineer? WIE 2 Specified UT test(s) performed on starting head area within 6 months of proposed WIE application? X 3 Mechanical Integrity Test (MIT -IA or CMIT-TxIA) completed and passed within the WIE previous 6 months of proposed application? X 4 Sketch provided of wellhead and casing components for Furmanite Repair Package? WIE X 5 Lead paint screening of the starting head and surface casing pup joint completed? WIE X 6 WIE Job specific Clamp Package requested from Design Engineer? X 7 Has a 10-403 been approved by the state? WIE 11. Pre -Job Well Preparation 1 Area around wellhead thawed? DHD 2 Gravel removed around wellhead for access? Cellar depth <4 feet? DHD 3 Wellhead cleaned with solvent? No hydrocarbons present on / around wellhead? DHD 4 Pressure bled off IA & OA? DHD 5 Monitors for 02, LEL & CO lined up? WIE 6 Pre -Job site hazard assessment held? To include: WIE Furmanite Technician(s) -- MP WSL -- Well Integrity Engineer -- DHD Technician assigned to job -- 111. Repair Operation Y N Initials 1 Unit Work Permit issued to have open bleeds, spotting of equipment, and application DHD of clamp? 2 Minimize well operations on location or SimOps conducted? DHD 3 Insure working pressures of IA & OA are < 50 psi. DHD 4 Monitor gas level around wellhead for 02, LEL and CO levels. DHD 5 Hold PJSM prior to beginning work. To include: WIE Furmanite Technician(s) -- Milne Point WSL -- Well Integrity Engineer -- DHD Technician assigned to job -- Wells Safety Advisor (optional) -- Pad / Drill Site Operator (optional) -- 6 Has the starting /casing head area been cleaned with isopropyl alcohol? Furmanite Are the conditions in the wellhouse conducive with continuing operations? Furmanite 7 > 70 deg F, ambient humidity below 80% and an open bleed on OA? 8 Has the clamp lifting plan been agreed upon? Furmanite 9 Was the design package followed or were there modifications performed? Furmanite Days After Clamp Operation: 1 Were post clamp conditions maintained per Furmanite engineer / Design Package DHD requirements (pressures, well house temperature)? 2 MIT -OA to 1200psi performed? WIE If the clamp does not leak during the MIT -OA, has the SL step to pull TTP been 3 activated and the well reclassified to POI? WIC Once well resumes operation, was post job inspection performed to look for potential WIE 4 issues with temperature changes while well is injecting? 5 If the well was successfully repaired, has a 10-404 been submitted to the state? WIE 6 Has clamp enclosure paperwork been filed in the well file? WIE • • Potential for Injury / Probability of Environmental Occurrence Energy Source Description of Harm / Economic (Low to Very Category Risk / Hazard Loss High) Remedy / Mitigation MOTION Tripping / Contusion / High Inspect well site for possible Hoses & Cords Musculoskeletal tripping hazards. Eliminate or Injury communicate tripping hazards. Place hoses to the side or outside of walking areas and heighten awareness with flagging. Ingress / Contusion / High Place ladder in cellar or secure Egress in and Musculoskeletal a step to aid in ingress / egress out of cellar Injury in and out of cellar if appropriate. Slips and Falls / Contusion / High Use nut plug / sand / spikes on Ice - Snow - Musculoskeletal icy surfaces. Have snow Cellar Water Injury removal performed at work site. Shovel doorways out. Thaw cellars to remove the hazards due to working on ice. Use vac truck and cellar de- watering equipment to remove cellar water and keep the cellar walking surface as dry as possible. Slips and Falls / Contusion / Low to Med Have grading done to level Uneven Musculoskeletal uneven surfaces. Scarify icy Surface Injury locations for traction. Safe out the work area, fix or remove loose boards or gratings. Crushing / Injury or Death / Low to Med Use caution when moving Vehicles & Damage to Assets equipment due to congested Equipment location. Use spotters and hand signals when moving equipment. Conduct SIMOPS notifications and planning to help reduce congestion on the pad / drill site. Crushing / Musculoskeletal Med Develop lifting plan for moving Strains / Pinch Injury, Hand Injury, enclosure patch. Use caution Points back/shoulder /arm when handling & using straps strains and chain riggers to lift enclosure clamp into place on startinghead. Personnel to use proper body positioning to keep limbs from under suspended load. Personnel to use SIM's training while rigging or lifting from awkward or low positions. Pinch Points / Hand Injury, eye Med Review proper use of Tools injury pneumatically powered cold chisel for peening. Utilize proper PPE. Eyes on task, hand -body positioning, proper tool selection, condition, use. Review wellhead and tree configuration with crew • • members to heighten awareness and understanding of valves, bleeder screws, gland nuts, LDS, and chemical injection lines when working to install enclosure patch. RADIATION -None- There are no radiation sources planned to be on location. CHEMICAL Contaminated Potential of High Environmental and SRT shall soils mishandling be contacted when discovered in materials or not contaminated soils are cellar making proper discovered. Environmental and notifications SRT will then make proper notifications and lead clean -up activities. Excess water in Release to ground High Use vac truck to manage cellar cellar water and disposal. Spill Prevention Release to ground Low to Med Use absorb, buckets, and secondary containments. H2S / Exposure Acute sickness / Low to Med H2S must be <10 ppm to begin Asphyxiation / work. Ensure that personal Death monitors are worn & functional. CO build up Acute sickness / Low Stage vehicles and equipment Asphyxiation / so that exhaust will not pollute Death the work area. Confined Asphyxiation / Med Assess cellar entry, and Space Death determine confined space policy compliance. Do not enter confined space without proper permitting, body harness and atmospheric quality test. Contact with Personal Injury Med Review MSDS prior to sealant commencing work. Wash skin compound thoroughly with water with soap and flush eyes with saline water for 15 minutes and report to medic for evaluation. Keep area well ventilated, wear PPE: glasses /goggles, leather gloves and FRC's while handling sealant. Shock / Static Spark / Fire / Injury Low to Med Ground all hydrocarbon electricity handling, gravel removal, and ELECTRICAL pumping equipment on location. Equipment / Spark / Fire / Injury Low Stage fire extinguisher on Truck fire location. Wellhead fire Spark / Fire / Injury Low Use non - sparking cold chisel to conduct peening process on clamp if necessary. GRAVITY Subsidence Engulfment / Death Low Areas with subsidence will be mitigated before the start of the job; fall protection shall be used in cellars showing signs of subsidence or over 6ft in depth. HEAT / COLD Cold / Potential for High Take warm up breaks as Environmental frostbite and needed; use buddy system to exposure due hypothermia identify frostbite symptoms. to length of job BIOLOGICAL Wildlife Personal Injury Low Awareness of environment. PRESSURE Trapped Personal injury, High Walk the lines, double check Pressure / environmental harm connections. Use whip- checks Unexpected on hoses in case of failure. • • Energy Purge hoses and equipment Release before use. Minimize exposure, observe Line of Fire. Set automated shutdowns on Damage pumping equipment. Confirm Overpressure Low pressure limitations of equipment, o . Confirm pressure Equipment Co P environmental harm gages are within policy standards for calibration. III • • Tree: Cameron 4 Wellhead: MC 1" 5M, MPU L-09i G 21.00' Gen. 5 w/ 11" x 4.5" FMC Tbg. Hnr. w/ 4.5" NSCT threads top and 3.5" bottom.and 4" CIW H BPV profile 4-1/16" CIW Tree 13 3/8 ", 54.5 ppf, K -55 csg. 115' 3.5" HES X- Nipple (2.813 id 2,214' 9 -5/8 ", 38#,K-55 btrs 5029' 3.5" 9.3 ppf, L -80 mod. eue 8rd tbg. (cap. = 0.0087 bpf, drift = 2.867' 7" 26 ppf, L -80, Btrc. production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf Max hole angle 37 degrees at 6700' 3.5" HES X- Nipple (2.813 id) 1 7,931' MMIM 3.5 "x 7" Baker SB -3 pkr. 7,944' Stimulation Summary 3.5" HES XN- Nipple 7,969' 4/1/91 pumped 150,300# of 16/20 (No-Go 2.75 id carbolite & 25,710# of 12 -18 carbo. . 7" Otis BWD P acker 7,986' w/ 4.00" ID w/ seal. Perforation Summary 2 -7/8" Otis XN nipple ( 2.205 id ) 8 Ref log: SWS CBT dated 3/31/91 2 -7/8" RH Catcher sub I 8,043' Size SPF Interval (TVD) $ �' 2-7/8" Otis WLEG 4.5" 5 8107' -8128' 7106' -7123' ELMD 8,038' 4.5" 5 8135' -8150' 7128' -7141 4.5" 5 8218' -8248' 7197' -7221' 4.5" 5 8263' -8276' 7234' -7244' FISH: W/L tool string and cutter bar .A14 PBTD 8500' Fish: 1 -7/8" ball and catcher seat 7 ", 26 #, L-80 shoe I 8597' DATE REV. BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27 -E WELL L -09 06/25/98 MDO RWO Tbg. change out 27E API NO: 50 -029 -22075 BP EXPLORATION (AK) 4 1 1 2 1 3 1 4 7 . NOTES IF IN DOUBT ASK PARTS LIST DRAWING NO. CUS1012087 DWG - 01 I REV. A MATERIAL SPECIFICATION: REMOVE ALL SHARP EDGES. Do Not Scale Off Drawing ITEM D ESCRIPTION PLATE - SA -516 GR.-70 FINISHED FABRICATION TO BE GIVEN QTY. MATERIAL SPEC. PIPE - N/A STAMPED IN 0.375" HIGH LmERS. 1 STUDS, 1 3/4" -8UN x 13 1/2" LG. 2 SA -193 GR. -B7 INSPECTION: REFER QAP 1316.3 0 938 2 NUTS, 1 3/4" -8UN HEAVY HEX 4 5A -194 GR.-2H 3 PACKING, 3/8" SQ. GRAPHITE cy A TYP. 3/8 I/(1 7:3 a " 4 1 3 /4 " -$UN STUDS o a LUBRICATE WITH 7 - 2 -- NICKEL ANTI -SEIZE 3y4 1- 3 TORQUE TO 2060 FT -LBF. MN _ 1IIIIMMB 1111 . lir . , 0 ---1 .111--"1 3 �8 i 4 • B 1Y2 --- n - , c•71 <4 . N 7� ri rn ": II � 3 /8 131/2 ' 8 � o \ 1 B.C. �,� 016y2 r { © !NN laM 017 NOTES: 1. PEENING GROOVE ON BORES: 1/8" X 1/8" X 60'. 2. INJECTABLE PACKING GROOVE ON BORES AND SPLIT LINE: 0.375" WIDE X 0.438" DEEP. PENDING APPROVAL 3. TOLERANCES ON BORES: +0.010/ -0.0. 4. """ DENOTES CRITICAL' DIMENSIONS. _ 5. INJECTION POINTS: DRILL 03/16" THRU INTO THE PACKING GROOVE, TECHNICIAN DAVID GUALAZZI MFG /SHOP MUSKOGEE, OK. DRILL & TAP FOR 3/8"-1 6UNC X 3/8" DEEP, 4 /BORE /HALF AND WPS NO. PER MFG. JOB NO. 186 - 101514 ONE BETWEEN STUDS. UNIT. MILNE POINT t" PAD WELL 09 COMPOUND TYPE. FSC - 5A, 58 6. ALL DIMENSIONS ARE TYPICAL UNLESS NOTED OTHERWISE. WEIGHT EST. 189 LBS. COMPOUND EST. 2 BOXES Zi DESIGN PRESSURE: ® Copyright 2006. rhi, drawing and al rights therein (including copyright, cr a 1200 PSI �% Ea SCALE design right and all like eights) are the property of Fanrgnite Worldwide FURMANITE Inc. and /or its subsidiary companies. and must not be used. distributed MAX. DESIGN TEMP: 1 �O'F N.T.S to others at reproduced without the written permission or consent or l THIRD ANGLE PROJEC110N Furmarute Worldwide Inc. MAXIMISING ASSET UPTIME D MIN. DESIGN TEMP: G At1 ENS INCHES le' DRAWING No. CL1S1 012087 — DWG - R � A STATUS RELEASED cONTENTS:CRUDE 01, NATURAL GAS, DIESEL, NITROGEN GEN. MACHINING TOL ±0.010',±o.5 GEN. FABRICATION TOL•— TITL WELL HEAD, LEAK SEALING ENCLOSURE _ ° Cs1 CUSTOMER NO: BPE002 0 -6"• ±0.060" ° c C USTOMER: >6. <12', ±0•125" SHEET SHEET OF W >12 i' 3 • 191). TITS MANUFACTURING DETAILS 1 1 . BP EXPLORATION ALASKA M0.1• BURN: +1/r --0.o 1-N PRUDHOE BAY ALASKA RA haw BShaw HIJAZI APPROVER 12 j p410 LAST MODIFIED 12/19/2010 CHECKED 12/19/2010 APPROVED N/A � S 1lit4 - i 1d BSh ED L . . • SP i I a.ka.. )..i4,n1... petnt kleil 'V1.- Q 1 3 s" �� ,� II2 ' rt ) -k 1(a 3y K cuz lb P -.. z. ,�_ !- 5 14 1 S dA4v 6 Rpc -e tot/n/S4 . L 6r6twtel ievel Da- s-/ vex' • • 1 FAI . • • Tree: Cameron 4 1/16", 5M KB Elevation: 56.00' Wellhead: FMC 11" x 11" 5M, M P U L-091 GL Elevation: 21.00' Gen. 5 w/ 11" x 4.5" FMC Tbg. Hnr. w/ 4.5" NSCT threads top and 3.5" bottom.and 4" CIW H BPV profile r 1 4- 1/16" CIW Tree 13 3/8 ", 54.5 ppf, K -55 csg. ( 115' I 3.5" HES X- Nipple (2.813 id) 2,214' I i f , 9-5/8", btrs 5029' 3.5" 9.3 ppf, L -80 mod. eue 8rd tbg. S (cap. = 0.0087 bpf, drift = 2.867' 7" 26 ppf, L -80, Btrc. production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf)` Max hole angle 37 degrees at 6700' 3.5" HES X- Nipple (2.813 id) 1 7,931' ' ' 3.5'5 7" Baker SB -3 pkr. 7,944' Stimulation Summary I 1 3.5" HES XN- Nipple 7,969' 4/1/91 pumped 150,300# of 16/20 (No Go 2.75 id; carbolite & 25,710# of 12 -18 carbo. 7" Otis BWD packer I - 7,986' w /4.00 "IDw /seal: Perforation Summary ai 2-7/8" Otis XN nipple 2.205 id Ref log: SWS CBT dated 3/31/91 • PP ( id) 8,042' 2 -7/8" RH Catcher sub 8,043' Size SPF Interval (TVD) 2 -7/8" Otis WLEG 8,044' 4.5" 5 8107' -8128' 7106' -7123' ELMD 8,038' 4.5" 5 8135' -8150' 7128' -7141' 4.5" 5 8218' -8248' 7197' -7221' 4.5" 5 8263' -8276' 7234' -7244' e I PBTD I 8500' FISH: W/L tool string and cutter bar • • Fish: 1 -7/8" ball and catcher seat 7 ", 26#, L -80 shoe I 8597' DATE REV. BY COMMENTS MILNE POINT UNIT 03/31/91 Initial completion Nabors 27 -E WELL L -09 06/25/98 MDO RWO Tbg. change out 27E API NO: 50 -029 -22075 BP EXPLORATION (AK) 4Q2010 Not Operable Injector Fort • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [AKDCWellIntegrityCoordinator @bp.com] Sent: Saturday, February 19, 2011 2:43 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 4Q2010 Not Operable Injector Report Attachments: Not Operable Injector Report 4Q2010.zip Hello Tom, Jim, Phoebe and Guy, Attached is the 4Q 2010 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 4Q2010.zip» Notes on wells: Removed from Quarterly Injection Report: ' �' � 1(1� 01 B1 -14: Passed AOGCC MITIA with Badami field restart R -13: Furmanite wrap repaired startinghead leak. Added to Quarterly Injection Report: MPF -92: Added until injection is requested. MPF -95: Added until injection is requested. PL -09: Adde I urmanite clam) is fabricated and installed to mitigate startinghead leak. Z -12: Added until TxIA communctbn is repaired. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 7/5/2011 Well MPL -09 Injection Plot TIO Plot Well: MPL -09 o PTD #:L1901010 ° AA:17 ❑ _ — IA Approval: ❑ ❑ OA Reason:❑ 0 .a g SH leak confirmed n. a a 0 0 • Last 90 days • Last Month 0 o ` A , 0 0 0 1 1 1 8/18/10 9/8/10 11/29/10 2/19/11 • Injection Rate, MCFPD Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 01/01/11 0 0 01/01/11 -100 440 0 01/01/11 0 0 12/31/10 -100 440 40 12/31/10 0 0 12/30/10 -100 440 40 12/31/10 0 0 12/29/10 -100 440 0 12/30/10 0 0 12/28/10 -100 440 0 12/30/10 0 0 12/27/10 -100 440 0 12/29/10 0 0 12/26/10 -100 440 0 12/29/10 0 0 12/25/10 -100 440 0 12/28/10 0 0 12/24/10 -100 440 0 12/28/10 0 0 12/23/10 -100 440 40 12/27/10 0 0 12/22/10 -100 440 40 12/27/10 0 0 12/21/10 -100 450 0 12/26/10 0 0 12/20/10 -100 450 20 12/26/10 0 0 12/18/10 -100 450 0 12/25/10 0 0 12/17/10 -100 450 0 • 12/25/10 0 0 12/16/10 -100 450 0 12/24/10 0 0 12/15/10 -100 440 0 12/24/10 0 0 12/14/10 -100 440 0 12/23/10 0 0 12/13/10 -100 450 0 12/23/10 0 0 12/12/10 -100 450 0 12/22/10 0 0 12/11/10 -100 450 0 12/22/10 0 0 12/10/10 -100 450 0 12/21/10 0 0 12/09/10 -100 460 20 12/21/10 0 0 12/08/10 -100 460 20 - 12/20/10 0 0 12/07/10 -100 440 0 12/20/10 0 0 12/06/10 -100 440 0 12/19/10 0 0 12/05/10 -100 440 40 12/19/10 0 0 12/04/10 -100 440 40 12/18/10 0 0 12/03/10 -100 440 40 12/18/10 0 0 12/02/10 -100 440 0 12/17/10 0 0 12/01/10 -100 440 40 ( ~ , # . ~~~, . ~_____ _~_____. ,,. P~ActivE D"~nywostic SertvicES, Inc. ~ . VVGLL fo.0~ T`R~4NS~/?°T'~L To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (9C?7) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection{Caliper f MTTj The technical data listed below is being subm+tCed herewith. Please acknowiedge receipt by returning a signed copy of this transmittal (etter ta the following : BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Ancharage, Alaska 99508 and ~'5~~.!~~~~~~ ~~i ',/ ~. ~ ~~~~ ProActive Diagnostic Senrices, Inc. VSC ~gl~ -~d ~ Attn: Robert A. Richey 130 West tnternationat Airport Road Suite C Anchorage, AK 99518 Fa~c (907j 245-6952 1 j Injection Profile 17Sep-09 MPU L-09 ~l ~i i ~ Signed : Print Name: l~~~~ BL / EDE 50-0259-22075-00 Date PROACTIVE DiQGNOSTfC SERVICES, 1NC., 130 W. 1NTERNATIONAL AIRPORT RQ SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fa~c: (907j245-88952 E-MAIL : _ W __ _. .___ __ _ ~_ `___ _ ... _~ __~~ WEBSITE : _, o._~.___ ,. . .. _ _,__ .,a C.\Documen~ and Settings`.Owner~Desktop\Transnut_BP.docx e 0 og escrlpt on ate o or MPL-09 11767141 MEM INJECTION PROFILE 1)\"1' ¡o,n-/t'\/ 09/16/07 1 S400A 40015442 OH MWD/LWD EDIT ..::JI'"'I~ ~ (")+ '-I · t~"'x 09/14/07 2 1 12-12A 40015307 OH MWD/LWD EDIT ::Jr:'?- -U'-1 t~ --r.:,()'1- 06/18/07 3 1 G-17A 40013619 OH MWD/LWD EDIT i9~- A-::J.er,"It 1""(~r<'I_ 06/18/07 3 1 S400A 11855508 CH EDIT PDC GR (USIT) ,::)() ~ - O-:}.c.¡ ..,,~¡Ç' 09/18/07 1 G-26B 10942213 MCNL A-t1~ -()c...(f{ -tt li"\(,,// OS/23/05 1 1 C·32C 11628756 MCNL ,.J/~" - /,":(0, :al-S-~{{) 02/18/07 1 1 E-04A 11801079 RST JC1<X-/~ J P J5&,/")~ 06/23/07 1 1 07 -07B 11216202 MCNL Qt. Co -OX I 'C1 1~(ð1J3 06/28/06 1 1 L2-11 11209603 MCNL Ie, ,y -hq(A # J <Ç00<-r 04/30/06 1 1 E-32A 11767130 MCNL ~N") - 1~'7\ .;t- 1S-~08- 06/19/07 1 1 L-04 11603118 MCNL .;:)oG - I::::w'J -j;I _i)~ 12/30/06 1 (ì) :5 ,.,. .. "Rn..I\ II" - E-19B 11767134 MCNL d'J""9- - ()-::;.--::;. ... 1570 (.) ( 07/21/07 1 1 2-16/M-16 11846803 RST UTI' IJ?s'7f - (2.,'-( µ- J"') t.o ðO 08/13/07 1 1 1-39A1N-16 11628769 MCNL ,BO{ð -I~'+ :tt ',",,:-- "'7"'" 04/15/07 1 1 . Schlumbepger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth W/I J b # 10/19/07 NO. 4449 ~~NED OCT 3 1 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay L D D . BL CD . i CI . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503- 3 ATTN: Beth iJ (~~-or ,~) Z007 Received by: ,~....,..F'.' ."~" ,;:-.:'::..) . ..~.{~ c:-. . .''''':'J STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test o 4/ { Kc¿f1 - c¡; 0 7 Email to:Winton_Aubert@admin.state.ak.us;Bob_Fleckenstein@admin.state.ak.us;Jim_Regg@admin.state.ak.us;Tom_Maunder@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP ACT / Milne Point / S-Pad 04/06/07 Lee Hulme John Crisp on L-08 only I (!¡O-/ol q -, \.. ...-'D M~ Packer Depth Pretest Initial 15 Min. 30 Min. WeIlIMPL-08 I Type Inj. I W TVD I 7,060' Tubing 2,380 2,390 2,385 2,385 Interval I 4 P. T. D.11901 000 I Type test I P Test psi! 1765 Casina 30 1,920 1,880 1,870 P/FI P Notes: 3.9 bbls diesel to 1920 psi Bled back to 500 psi OA 300 510 520 520 WeIlIMPL-09 I Type Inj. I W TVD I 6,974' Tubina 2,400 2,400 2,400 2,400 I ntervall 4 P.T.D. 1901010 I Type test I P Test psil 1744 Casing 170 1,980 1,940 1,940 P/FI P Notes: 4.6 bbls diesel to 2000 psi Bled back to 350 psi OA 0 0 0 0 Hooked up jumper hose from IA and tested OA gauge and injectivity into the OA. Winessing waived bv John Cris J. Weill I Type Inj.1 TVD I Tubing Interval p.T.D.1 I Type testl Test psi! Casing P/F Notes: OA \ tB ~ ~ . c;:¡, c:Þ ~ S TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover 0= Other (describe in notes) . MIT Report Form BFL 9/1/05 2007-0406_MIT _MPU_L-08jc.xls i,,\t:L,t:IVt:U . . fØo1 JAN 0 8 2007 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Alaska Oil & Gas Cons. Commission REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingO Change Approved ProgramO Repair WellŒ Pull TubingD Operation ShutdownD PluQ PerforationsD Perforate New PoolO Perforate 0 Stimulate 0 WaiverO 2. Operator Name: 3. Address: 4. Current Well Class: Development 0 BP Exploration (Alaska), Inc. ExploratoryO P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): StratigraphicO ServiceŒ] 9. Well Name and Number: MPL-09 10. Field/Pool(s): Milne Point Unit I Kuparuk River Sands 56.00 8. Property Designation: ADL-025509 11. Present Well Condition Summary: Total Depth measured 8610 feet true vertical 7529.0 feet Effective Depth measured 8498 feet true vertical 7433.0 feet Plugs (measured) Junk (measured) Casing CONDUCTOR SURFACE PRODUCTION Length Size MD TVD 79 13-3/8" 54.5# K-55 36 115 36.0 115.0 4994 9-5/8" 36# L-80 35 - 5029 35.0 - 4619.0 8563 7" 26# L-80 34 - 8597 34.0 - 7518.0 Perforation depth: SCANNED JAN 1 1 2007 Measured depth: 8107-8128,8135-8150,8218-8248,8263-8276 True vertical depth: 7106-7123,7128-7141,7197-7221,7234-7244 Tubing ( size, grade, and measured depth): 3-1/2" 9.3# L-80 2-7/S" 6.5# L-80 @ 32 7986 @ 79S6 S044 @ 7944 @ 7986 @ 2214 Packers & SSSV (type & measured depth): 7" Baker SB-3 Packer 7" Otis BWD Packer HES X-Nipple 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Anchorage OtherŒ] Bradenhea Repair Time ExtensionO Re-enter Suspended WellO 5. Permit to Drill Number: 19 1010 6. API Number 50-029-22075-00-00 None Fish: W/L Tool String & Cutter Bar Fish: 1-7/8" Ball & Catcher Seat Burst 2730 5120 7240 Collapse 1130 2370 5410 13 Prior to well operation: Subsequent to operation: Representative Dailv AveraQe Production or Iniection Data Gas-Mef Water-Bbl Casin Pressure 51 440 51 0 Tubin Pressure o o WAG ŒI GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or NIA if C.O. Exempt: NIA Oil-Bbl 14. Attachments: 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilD GasD Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact DeWayne R. Schnorr Printed Name DeWayne R. Schnorr Signature Title Petroleum Engineer Phone 564-5174 .\ (ICY \j~ì DevelopmentD ServiceŒ) Date 1/3/07 . . MPL-09 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/21/2006 T/I/O=2800/48010. (F/P for Braden head leak.) Freeze protect tbg w/2 bbls neat meth followed by 22 bbls diesel. Cap wI 2 bbls neat meth. FWHP=3000/48010. 10/19/2006 *** WELL SII ON ARRIVAL *** SBHPS, SET PXN PLUG TO SECURE WELL. RUN DUAL SPARTEK GAUGE.MADE FIFTEEN MINUTE STOP @ 7690' MD AND THREE HOUR STOP @ 8190' MD. DRIFT THRU XN-NIPPLE WI BLB & GAUGE RING. SET 3.5" PXN PLUG BODY & PRONG (1.375" FN, 39" OAL) @ 7969' MD. 1580 PSI BELOW PLUG. *** WELL LEFT SII ON DEPARTURE*** 11/01/2006 TIIIO= SSV/46010 (eval bradenhead leak) Support techs installed a temp liner in cellar. OA FL near surface. Started pumping diesel down OA. Pressured OA to 400 psi and brad en head started leaking at the eight o'clock position. (very small amount of leakage coming from bradenhead). Pressured OA to 500 psi monitored for 5 mins lost 10 psi. Continued to pressure OA to 800 psi. Monitored OA pressure for 30 mins. OA lost 40 psi in 30 mins. Pumped 1 bbl of diesel. IA remained @ 460 psi through out job. Bled OA back to 0 psi. Final WHP's = SSV/46010. 12107/2006 Perform SEAL TITE job on braidenhead leak per procedure. Pressured OA to 1500 psi with no leaks around braidenhead. Monitored for 24 hours. No leaks around braidenhead. **Success !** 12/13/2006 *** WELL SII ON ARRIVAL *** PULL TIP - POST SEAL TITE PULL PRONG & 2.813" PXN PLUG FROM 7969' MD. *** WELL LEFT SII ON DEPARTURE *** BBLS 4 Neat Methanol 23.5 Diesel 27.5 TOTAL FLUIDS PUMPED Page 1 . . Tree: Cameron 41/16", 5M M PU L 09. Wellhead: FMC 11" x 11" 5M, - . Gen. 5 wi 11" x 4.5" FMC Tbg. Hnr. wI 4.5" NSCT threads top and 3.5" bottom.and 4" CIW H BPV profile 133/8",54.5 ppf, K-55 csg. ~ 9-5/8", 38#,K-55 btrs I 5029' I 3.5" 9.3 ppf, L-80 mod. eue 8rd tbg. (cap. = 0.0087 bpf, drift = 2.867' 7" 26 ppf, L-80, Btrc. production casing (drift 10 = 6.151", cap. = 0.0383 bpf) Max hole angle 37 degrees at 6700' Stimulation Summary 4/1/91 pumped 150,300# of 16/20 carbolite & 25,710# of 12-18 carbo. Perforation Summary Ref loa: SWS CBT dated 3/31/91 Size SPF Interval (TVD) 4.5" 5 4.5" 5 4.5" 5 4.5" 5 8107'-8128' 8135'-8150' 8218'-8248' 8263'-8276' 7106'-7123' 7128'-7141' 7197'-7221' 7234'-7244' FISH: WIL tool string and cutter bar Fish: 1-7/8" ball and catcher seat DATE REV. BY KB Elevation: 56.00' GL Elevation: 21.00' 4-1/16" CIW Tree 3.5" HES X-Nipple (2.813 id~ 2,214' I 3.5" HES X-Nipple (2.813 id) 7,931' 3.5"x 7" Baker 8B-3 pkr. 7,944' 3.5" HES XN-Nipple 7,969' (No-Go 2.75 id 7" Otis BWO packer 7,986' wi 4.00" 10 wI sealE 2-7/8" Otis XN nipple ( 2.205 id 8,042' 2-7/8" RH Catcher sub 8,043' 2-7/8" Otis WLEG 8,044' ELMO 8,038' J} psm 8500' 7", 26#, L-80 shoe 8597' 03/31/91 06/25/98 MDO COMMENTS Initial completion Nabors 27-E RWO Tbg. change out 27E MILNE POINT UNIT WELL L-G9 API NO: 50-029-22075 BP EXPLORATION (AK) RE: Request: MPL-09 (PTD 1901010) Temporary Injection e e Thanks Tom. MPL-09 has been added to the monthly UIC report. Clint, would you please help ensure we report the final tubing pressure to Tom once injection is complete. Thanks! Joe 659-5102 \. From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Monday, June 05,20067:38 AM To: NSU, ADW Well Integrity Engineer Cc: jim_regg@admin.state.ak.us; MPU, Well Operations Supervisor; NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; Austin, Paul A; MCCOllUM, CODY 0 (VECO); MPU, Wells Ops Coord; MPU, Wells Ops Coord2 Subject: Re: Request: MPl-09 (PTD 1901010) Temporary Injection Joe, It is acceptable to inject water into the well as you propose. This well should be added to the monitoring list. Please inform us of the tubing pressure after the 7 days of injection planned. Call or message with any questions. Tom Maunder, PE AOGCC NSU, ADW Well Integrity Engineer wrote, On 6/4120068:44 PM: Hi Tom & Jim. We request approval to inject water into MPL-09 (PTD 1901010) for up to a week. Objective is to lower the wellhead pressure from approximately 4500 psi to reduce risk associated with conducting slickline operations. Once the wellhead pressure is lowered, we plan to set a TTP and conduct pressure testing to support an AA request for a surface casing leak. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. , ðþ ~ (f}<rvÞl' ~ p2-'fIV, ç(~ 6/5/2006 9:46 AM RE: MPL-09 (PTD 1901010) Surface Casing Leak e e Hi Tom. The well was on gas injection when the SC leak was identified. It is currently SI. Note the well is MPL-09. The Subject line incorrectly listed MPU-09. Please let me know if you have any other questions. Joe 659-5102 -----Original Message----- From: Thomas Maunder [mailto:tom maunder@admin.state.ak.us] Sent: Tuesday, May 30, 2006 4:21 PM To: NSU, ADW Well Integrity Engineer Cc: Jim Regg Subject: Re: MPU-09 (PTD 1901010) Surface Casing Leak Joe, Our records show the well to be in WAG service. What fluid is presently being injected? Tom Maunder, PE AOGCC NSU, ADW Well Integrity Engineer wrote, On 5/30/2006 4:12 PM: Hello Tom and Jim. Injection well MPL-09 (PTD 1901010) exhibits indications of a surface casing leak. N2 was applied to the OA (which was at 0 psi) and bubbling in the cellar was observed. The well has been shut-in. An MITIA passed to 1745 psi on 4/4/2003 and there are no indications of TxIA communication. Current plans are to conduct an MITIA to 1.2 times the injection pressure and evaluate the well for an AA request. Attached is a wellbore schematic. The well has been added to the monthly injection report. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email :~§1!:0:P?J.~~~~f:Q!:r::.9:E~_!:_Y..§;?:9~!:l~,,":r:~ÞE:C::(?11] «MPL-09.pdf» -+4+ ~ðl').... 6/5/2006 9:46 AM MPU-09 (PTD 1901010) Surface Casing Leak e ~q S\~ f{P Hello Tom and Jim. Injection well MPL-09 (PTD 1901010) exhibits indications of a surface casing leak. N2 was applied to the OA (which was at 0 psi) and bubbling in the cellar was observed. The well has been shut-in. An MITIA passed to 1745 psi on 4/4/2003 and there are no indications of TxlA communication. Current plans are to conduct an MITrA to 1.2 times the injection pressure and evaluate the well for an AA request. Attached is a wellbore schematic. The well has been added to the monthly injection report. Please call with any questions. Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, x1154 Email: NSUADWWelllntegrityEngineer@bp.com ~>P~~~.Nt:'f, 'Î -,Vf .".. ....~.;.."'..,; lb «MPL-09.pdf» Content-Description: MPL-09.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 5/30/2006 5:32 PM e Tree: Cameron 4 1/16", 5M Wellhead: FMC 11" x 11" 5M, Gen. 5 w/ 11" x 4.5" FMC Tbg. Hnr. w/ 4.5" NSCT threads top and 3.5" bottom.and 4" CIW H BPV profile 133/8",54.5 ppf, K-55 csg. ~ 9-5/8", 38#,K-55 btrs I 5029' I 3.5" 9.3 ppf, L-80 mod. eue 8rd tbg. (cap. = 0.0087 bpf, drift = 2.867" 7" 26 ppf, L-80, Btrc. production casing ( drift 10 = 6.151 ", cap. = 0.0383 bpf ) Max hole angle 37 degrees at 6700' Stimulation Summary 4/1/91 pumped 150,300# of 16/20 carbolite & 25,710# of 12-18 carbo. Perforation Summary Ref 109: SWS CBT dated 3/31/91 Size SPF Interval (TVO) 7106'-7123' 7128'-7141' 7197'-7221' 7234'-7244' 4.5" 5 4.5" 5 4.5" 5 4.5" 5 8107'-8128' 8135'-8150' 8218'-8248' 8263'-8276' FISH: W/L tool string and cutter bar Fish: 1-718" ball and catcher seat MPU L-09i e KB Elevation: 56.00' GL Elevation: 21.00' 4-1/16" CIW Tree 3.5" HES X-Nipple (2.813 id~ 2,214' I 3.5" HE5 X-Nipple (2.813 id) 7,931' 3.5"x 7" Baker 58-3 pkr. 7,944' 3.5" HES XN-Nipple 7,969' (No-Go 2.75 id 7" Otis BWO packer 7,986' wI 4.00" 10 wI seal~ 2-7/8" Otis XN nipple ( 2.205 id 8,042' 2-7/8" RH Catcher sub 8,043' 2-7/8" Otis WLEG 8,044' ELMD 8,038' J} PBTD 8500' 7",26#, L-80 shoe 8597' DATE REV. BY COMMENTS 03/31/91 Initial completion Nabors 27-E 06/25/98 MOO RWO Tbg. change out 27E MILNE POINT UNIT WELL L-09 API NO: 50-029-22075 BP EXPLORATION (AK) ¡",I e ,q"ö.--lO) ( ~ WELL LOG TRANSMITTAL ProActive Diagnostic Services, Inc. To: State of Alaska AOGCC 333 W. 7th Street Suite 700 3001 Porcupine St. Anchorage, Alaska 99501 RE : Distribution - Final Print( s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of : Joey Burton / Jeni Thompson BP Exploration(Alaska), Inc. ProActive Diagnostic Services, Inc. Petro-Technical Data Center LR2-1 P. O. Box 1389 900 East Benson Blvd. Stafford, TX 77497 Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE REPORT WELL DATE TYPE OR SEPIA PRINT(S) OR CD-ROM FILM BLUELINE Open Hole 1 1 1 MPU L-09i 11-1 503 Res. Eva!. CH 0'\ 1) 1 1 I ('-Ý ,~~ --, Mech. CH 1 Caliper Survey ~..... ~... ...":'.~, Signed: ~~9J.j'A ~--Q ~,^({,-N\ Date: -REeEtVEÐ Print Name: !I~ ~.1 2 0 2004 \.,;. "\\. ' Ala.aka Oil & Gas Cons. Commiaian Anctøage PlIOAcrivE DiAGNosrÎc SERvicES, INC., PO Box 1 }b9 SfAHOIld 1)( 77477 Phone:(281) 565-9085 Fax:(281) 565-1369 E-mail: pds@memorylog.com Website: www.memorylog.com §(G¿~k~~El'. FER {v 2 2DOI~, ~~':DfX\~ P.T.D.I MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich I'"~' DATE: April 7, 2003 Commissioner k~~,~?~ d ""~%..~(~ SUBJECT: Mechanical Integrity Test THRU: Tom Maunder BP× P.I. Supervisor MPU L Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL Packer Depth Pretest Initial 15 Min. 30 Min. I 190-100 ITypetestl P ITestpsil 1765 I Casingl 0 I 25701 24801 24401 P/F I -,P I¢' Notes: Well P.T.D. Notes: Well P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: I L-Oe I Type,nj.Ia I T.V.D. I~ I T, bingl ,,~00 I ,~00 14~00I,~oo I,nte~all 4 I 190-101 ITypetestl P ITestpsil 1744 I CasingI 5O0 I 25001 24501 24501 P/F I ---P I Type 'nj.I I T.,,.~. I Type testII Test psi l I Casing II I I I P/F I Type Inj. Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU L Pad and witnessed the 4 year MIT on wells L-08 and L-09. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed for 30 minutes with both wells demonstrating good mechanical integrity. M.I.T.'s performed: 2 Number of Failures: O Attachments: Total Time during tests: 2 hour cc: MIT report form 5/12/00 L.G. MIT MPU L Pad 4-7-03 CS.xIs 4/18/2003 STATE OF ALASKA ALASKA U,-AND GAS CONSERVATION COMiv,'lSSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: E~]Operation Shutdown E~]Stimulate [] Pull Tubing ~]Alter Casing 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1752' SNL, 4764' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 1289' SNL, 603' WEL, SEC. 6, T13N, R10E, UM At effective depth 1488' SNL, 688' WEL, SEC. 6, T13N, R10E, UM At total depth 1540' SNL, 708' WEL, SEC. 6, T13N, R10E, UM E~] Plugging [~ Repair Well Type of well: ~--I Development E~ Exploratory I~ Stratigraphic [] Service Other Change Out ESP & Conver~ '~0. WAG' Injector 6. Datum Elevation (DF or KB) KBE - 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-09i 9. Permit Number / Approval No. 90-101 398-137 10. APl Number 50-029-22075 11. Field and Pool Milne Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured 8610 feet true vertical 7529 feet Effective depth: measured 8498 feet true vertical 7433 feet Casing Length Structural Conductor Surface Intermediate Production Liner Plugs (measured) Junk (measured) Wireline tool string and cutter bar lost in hole; 1-7/8" ball and catcher set lost in hole Size Cemented MD TVD 79' 13-3/8" 500 sx PF 'C' 115' 115' 4993' 9-5/8" 82 bbls Class 'G', 512 bbls PF 'E' 5029' 4619' 8561' 7" 97.7 bbls Class 'G' 8597' 7518' Perforation depth: measured true vertical 8107'-8128', 8135'-8150', 8218'-8248', 8263'-8276' 7107'-7124', 7130'-7142', 7197'-7222', 7234'-7244' Tubing (size, grade, and measured depth) 3-1/2", 9.3#, L-80 Mod, 8rd EUE tubing to 7986' with 2-7/8" tailpipe to 8044' Packers and SSSV (type and measured depth) 3-1/2" x 7" Baker SB-3 packer at 7944'; 7" Otis BWD packer at 7986'; 3-1/2", HES X-Nipple at 2214' 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 Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments I--] Copies of Logs and Surveys run [~ Daily Report of Well Operations 16. Status of well classifications as: F-~ Oil E~ Gas I~ Suspended Service Water & Gas Injector 17. I hereby certify that the fCegoing is true and correct to the best of my knowledge Signed Terrie Hobble Title Technical Assistant III Prepared By Name/Number: Date 0 ~' ~,J~'(~? rorrio Hobble, 564:4628 sUbmit In Du'Plicate Form 10-404 Rev. 06/15/88 Facility M Pt L Pad Progress Report Well MPL-09 Page 1 Rig (tfl~l~ ~JaOt~ ~.~/~' Date 10 February 99 Date/Time 14 Jun 98 15 Jun 98 16 Jun 98 17 Jun 98 18 Jun 98 19 Jun 98 20 Jun 98 11:00-13:00 13:00-14:00 14:00-14:30 14:30-18:00 18:00-06:00 06:00-09:30 09:30-13:00 13:00-16:30 16:30-20:00 20:00-02:00 02:00-03:00 03:00-04:00 04:00-06:00 06:00-08:00 08:00-11:00 11:00-16:30 16:30-21:30 21:30-22:30 22:30-06:00 06:00-09:00 09:00-12:00 12:00-13:00 13:00-17:30 17:30-21:00 21:00-22:30 22:30-23:30 23:30-00:00 00:00-06:00 06:00-07:30 07:30-08:30 08:30-14:00 14:00-14:30 14:30-17:00 17:00-18:00 18:00-19:00 19:00-21:30 21:30-01:00 01:00-03:30 03:30-04:30 04:30-06:00 06:00-07:30 07:30-10:30 10:30-11:30 11:30-18:00 18:00-22:00 22:00-01:00 01:00-03:00 03:00-04:30 04:30-06:00 06:00-08:00 08:00-12:00 12:00-16:00 16:00-18:00 Duration 2hr lhr 1/2 hr 3-1/2 hr 12hr 3-1/2 hr 3-1/2 hr 3-1/2 hr 3-1/2 hr 6hr lhr lhr 2 hr 2hr 3hr 5-1/2 hr 5hr lhr 7-1/2 hr 3hr 3hr lhr 4-1/2 hr 3-1/2 hr 1-1/2 hr lhr 1/2 hr 6hr 1~ 1/2 hr lhr 5-1/2 hr 1/2 hr 2-1/2 hr lhr lhr 2-1/2 hr 3-1/2 hr 2~1/2 hr lhr 1-1/2 hr 1-1/2 hr 3 hr 1 hr 6-1/2 hr 4hr 3hr 2 hr 1-1/2 hr 1-1/2 hr 2hr 4hr 4hr 2 hr Activity Rig moved 10.00 % Rig moved 20.00 % Rig moved 30.00 % Rig moved 40.00 % Rig moved 80.00 % Rig moved 100.00 % Rigged up Lubricator Removed Xmas tree Reverse circulated at 7979.0 ft Reverse circulated at 7979.0 ft Rigged up Lubricator Removed Xmas tree Rigged up BOP stack Rigged up BOP stack Tested BOP stack Pulled Tubing on retrieval string to 60.0 ft Tested BOP stack Installed Completion string handling equipment Laid down 7986.0 ft of Tubing Laid down 7986.0 ft of Tubing Tested BOP stack Made up BHA no. 1 R.I.H. to 7982.0 ft Pulled out of hole to 0.0 ft Pulled BHA Tested BOP stack Rigged up Tubing handling equipment Ran Tubing to 4780.0 ft (3-1/2in OD) Ran Tubing to 5116.0 ft (2-7/8in OD) Racked back drill pipe Pulled Tubing in stands to 5116.0 ft Serviced BOP test plug assembly Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conducted slickline operations on Slickline equipment - Retrival run Conduct braided cable operations - 3/16 size cable Conduct braided cable operations - 3/16 size cable Conduct braided cable operations - 3/16 size cable Made up BHA no. 2 R.I.H. to 3000.0 ft R.I.H. to 7982.0 ft Pulled out of hole to 0.0 ft Pulled BHA Ran Tubing to 7982.0 ft (3-1/2in OD) Space out tubulars Circulated at 7982.0 ft Rig waited · Equipment Circulated at 7982.0 ft Ran Tubing to 7982.0 ft (3-1/2in OD) Circulated at 7982.0 ft Set packer at 7944.0 ft with 2500.0 psi Rigged down BOP stack Installed Xmas tree ,x/98 07:39 FAX 907 564 5195 Dr' ~At'LUt(A'rlul~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Alter Casing [] Repair Well [] Pull Tubing [] Variance []Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 12. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1752' SNL, 4764' WEL, SEC. 8, T13N, R10E, UM At top of productive interval 1289' SNL, 603' WEL, SEC. 6, T13N, R10E, UM At effective depth 1488' SNL, 088' WEL, SEC. 6, T13N, R10E, UM At total depth 1540' SNL, 708' WEL, SEC. 0, T13N, R10E, UM [] Perforate [2~ Other C~ange to WAG Injector 5. Type of well: [] Development [] Exploratory [] Stratlgraphic [] Service 6. Datum Elevation (DF or KB) KBE = 56' 7. Unit or Property Name Milne Point Unit 8. Well Number MPL-09i 9. Permit Number 90-101 10. APl Number 50-029-22075 t 1. Field and Pool Milne Point Unit / Kuparuk Rlver Sands 12. Present welt condition summary Total depth: measured 8610 feet Plugs (measured) true vertical 7529 feet Effective depth: measured 8498 feet Junk (measured) true vertical 7433 feet Casing Length Size Cemented Structu roi Conductor 79' 13-3/8" 500 sx PF 'C' Surface 4993' 9-5/8" 82 bbls Class 'G', 512 bbls PF 'E' Intermediate Prqcl~lc~io~ j 8561' 7" 97.7 bbls Class 'G' L. MD TVD 115' 115' 5029' 4619' 8597' 7518' Perforation depth: measured 8107'-8128', 8135'-8150', 8218'-8248', 8263'-8276' true vertical 7107'-7124', 7130'-7142', 7197'-7222', 7234'-7244' Tubing (size, grade, and measured depth) 2-7/8" 6.5#/ft L-80 to 8044' Packers and SSSV (type and measured depth) MAY 22 1998 Otis TRSV SCSSV at 552'; Otis BWD Packer at 7986' ~0~08 13. Attachments [] Description summary of proposal [~ Detailed operations program [~] BOP sketch 14. Estimated date for commencing operation May 27, 1998 16. if proposal was verbally approved Name of approver Date approved Contact Engineer Name/Number: Lance Spencer, 564-5042 Ii 5, Status of well classifications as: [] Oil [] Gas [] Suspended Service _Water Injection Prepared By Name/Number: Kathy Campoarnor, 564-5122 17. I hereby certify that the foregpi~g is true and .C~rj~ect to the best of my knowledge Signed T Brant ne eves~7~--~~//~/. . itle Drilling Engineering . ? , ~..~~~--~tl t ....... Supervisor Commission Use Only Conditions of Approval: Notify Commission so representative may witness Plug integrity BOP Test.X. Location clearance Mechanical Integrity Test ~ SubseauenLf_orm required lo- ORIGINAL SIGNED'BY . ' -- Robert N. Chdstenson Approved by order of the Commission Commissioner Date I'Approval No.~.~-l.~31 Form 10-403 Rev. 06/15/88 Submit-(n Tril~icate 07:40 FAX 907 ~B4 ~1~3 D~ ~A~LUKA'I]tJ~ OBJECTIVE: The objective of the MP L-09i RWO is to replace the existing 2-718" tubing to a 3-1/2" 9.3# L-80 EUEMod tubing for a gas and water ~niector. SCOPE: Pre:Rig Wo.rk; To be conducted by MPU PEs · RU SL lubricator and test. Report surface pressure to determine the approximate BHP.RIH and Lock open the SCSSV (no control line ava[table). WL A Gauge ring thru the XN nipple at 8042" (2.2" ID). Use Xylene/acid wash or scraper run if required. · RIH and set a (2.2" PXX-plug with prong in the XN nipple. · Bleed off the surface pressure to test the plug for I hour. · WL open the Otis Sliding Sleeve 7979' or punch holes in the tubing at 7950'. Circulate the 12.0 ppg NaBr or Mud as required to balance BHP across the packer and plug. · Install BPV and RDMO. Rig · · · · · wor, ; j MIRU. ND Tree and NU BOPs and Test, Notify AOGCC 24 hfs prior to BOP Test witness.). Instal[ landing joint and circulate one BUs.. POOH and LD 2-7/8" tubing leaving original 7" Otis BWD Packer inpiace. PU new seal assembly and 3-1/2" 9,3# L-80 Tubing. RIH to packer at 7986'. Sting into the packer and test to 2000psi. PU and circulate out annulus fluid with inhibited brine. Spot diesel freeze protect. Slack off into packer and test annulus to 3000 psi. Set TWC, ND BOP, NU tree and test the same. RDMO, ~ Post Rig Wo~: · RU SL and Pull PXX plug. Prepare well for injection. MAY 22 ]998 .2/98 07:40 FAX 907 564 5193 SENT BY: BP'X-ISiPOC BP' I~]LPLURAT 1UI~ q~l -.. __ . , 4-20-98 ; 4:01PM ; BPX-MI~ PO11¥,'~ 9075644441;~14 COMPLETION S~TCH MI~E POINT UNIT (I). PERMIT No.: C~PLE~O: 4/4/91 LA~ ~KO~; N/A ~ I/~"-- HAN~ W~'H' ~V PR~{~ ~BING ~ 2 7/8'. 6,5~, L-60, 8rd EUE ~G (2,441" 1. AU. MEASUREMENTS ARE FROM KDB NABOR~ RIG 27E. KDB --GL = 31,4' 2. UAX. ANGLE .= .37' 0 6700' .... '~ K.O.P, --- 2000' 4. SLANT HOLE: YES "Ail 5. m~ ~PEi Mc ~. $o0o~_w/2 ,~-d 'tREeTOP CO..~CT~C~ -- ~ MIN. RES]RICPON I$ OTIS ×N NIPPLE (2,205" ID) 7. COMPLETION FLUID: 10.2 0, STIUULATION: 4/{/91 FRAC PUMPED 150,300 {'s 16-20 cARI~ouTE 25,710# 12-10 CARBOLITE 55Z' Z '7/B" OTIS FMX 1Esr' (2.52' iD). 7979' 2 ?/8" OTIS ×A SLIDING SLEEVE (2.313" lO) 7986' '7" 0TIS O~O PERM PACKER (4,00" ID) W/SEAL BORE EXlENSION ANO MILLOUI' t'XiENSION PERFORATIONS: '5 SPF 4.5' CSO GUN MX 8107'-8128' 7106'-7123' LZ 8135'--8150' '7128'-~7141' LK--1.2 8218'--8248' 71gT-7221' LK-3 8265'--8276' 7234'--72 ¢4' CONOCO INC. ANCJ-'tOR A DE DIVISION 8042' 2 7/8" 0TIS XN NIPPLE (2.205' lO) 804.3' 2 '//gl' OTIS RH CATCHER SUB (2.384," ID) 8044' TUBING TAIL W/OTIS W/L ENTRY GUIDE ~D) [vJA¥ 22 O~S RH CAT~ ~B ~AT ~D I 7/8" 8597' 7', 26~, L-~, APPRO~O ~Y: HDS DATE: 7/~/g2 DRAF~O BY: SJN CAD ~LE: WC~g ,.,onoco Inc. Anchorage Division To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed ..~cord of Shipment of Confidential Information Date From Steve Davies Conoco Inc. 3201 C Street, Suite 200 June 10, 1993 Anchorage, Alaska 99503 (907) 564-7640 Via Petroleum Couriers Subject Quantity Contents Core Analysis Report Sidewall Descriptions ~Ot'~'? .~.-2 Final Drilling Report ~)1.-_~ ,-~i-3 Final Drilling Report ~01-~¢~ ~FI-4 Final Drilling Report (~J01~~!-1 Final Drilling Report c~1~ I ~,rI-2 Final Drilling Report C~~ ~I-3 Final Drilling Report "- _~1-3 No Whole Core or Sidewall Cores taken as noted on completion report. ~) 1~:~.(~1-4 Final Drilling Report 1 ~._-4A Core Analysis Report 1 ,.arc-1 Final Drilling Report c~1~5;~-1 Core Analysis Report 1 .~-1 Core Description Report ~)~1.,~/,~J-2 Final Drilling Report R E C E IV E D n"l '~g~-2 Completion History ~01~"7 -.'-o~:3 Final Drilling Report JUN I 1 1993 O~1--<~*~-4 Final Drilling Report o. ~c7 Final Drilling & Completion Report ~-8 Final Drilling & Completion Report 1 ~I-E:9 Final Drilling & Completion Report (~ -~ ~/~1:~_9 Core Description Report 1 Core Analysis Report JUas~ OJJ & Gas Cons. Commission Anchorage Signed By Transmittal Approved By Date Instructions: ~~ te*~~Y bY ~r~ ~ ~ming~ease second copy. Received By~7~~~~ Date Remarks · June I Transmittal Copy Only To ~onoco Inc. Anchorage Division hecord of Shipment of Confidential Information To Larry Grant Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501-3192 (907) 279-1433 [] Under Separate Cover Enclosed Date From Steve Davies Conoco Inc. Me¥ 5, 1993 3201 C Street~ Suite 200 Anchorage, AlaSka 99503 (907) 564-7640 Via Petroleum Couriers Subject Milne Point Well Log Magnetic Tapes I-2, I-3, I-4~ I-4A~ J-l~ J-3~ J-4~ L-7~ L-8~ L~9 Quantity Contents 1 each I-2 Magnetic Tape. (~DIT, APl #50-029-22066,' Log Date: 03-NOV-90, Ref #74175. I-3 Magnetic Tape. O.H.EDIT, APl #50-029-22067, Log Date: 12-NOV-90, Ref #74203. I-4 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 19-Nov-90, Ref #74208. I-4~ Magnetic Tape. J-1 Magnetic Tape. J-3 Magnetic Tape. J-4 Magnetic Tape. L-7 Magnetic Tape. L-8 Magnetic Tape. L-9 Magnetic Tape. O.H.EDIT, APl #50-029-22068, Log Date: 29-Nov-90, Ref #74229. Open Hole,APl #50-029-22070, Log Date: .13-Dec-90, Atlas Wireline & LIS listing. O.H.EDIT, APl #50-029-22072, Log Date: 27-Dec-91, Ref #74271 & LIS listing. O.H.EDIT, APl #50-029-22073, Log Date: 03-Jan-91, Ref #74276 & LIS Iisting.¢~l~¢ O.H.EDIT, APl #50-029-22028, Log Date: 14-Feb-91, Ref #74350. Open Hole,APl #50-029-22074, Log Date: 17-Apr-91, Ref #74527 & LIS Iisting. C~Otll~ O.H.EDIT, APl #50-029-22075, Log Date: 28-Mar-91, Ref #74467~.~O_tO~ RECEIVED MAY 0 5 1993 ~aska 0il & Gas Cons, Commissl0n ~chorage **LIS listings not availabe for I-2, I-3, I-4, I-4A, L-7 & L-9. Verbal notification provided to H. Oakland. Waiver granted via phone conversation May 5, 1993. ,, Signed By Transmittal Approved By Date Instructions: please aCknov~el~ge ~z~omptly by signing and returning second copy. Received By Date May 5, 1993 Remarks Transmittal Copy Only To STATE OF ALASKA ALA~rJ~, OIL AND GAS CONSERVATION COMM~,~iON REPORT OF SUNDRY WELL OPERTIONS 1. Type of Request: Operation shutdown Pull Tubing __ Stimulate Alter casing Repair well Alter casing __ Repair well m Other X Begin Water Injection Name of Operator Conoco Inc. Address 3201 C Street, Suite 200 Anchorage, AK 99503 Location of well at surface 1752' FNL, 4769' FEL, Sec.8, T13N, R10E, U.M. At top of productive interval 1289' FNL, 603' FEL, Sec.6, T13N, R10E, U.M. At effective depth 1488' FNL, 688' FEL, Sec.6, T13N, R10E, U.M. At total depth 1540' FNL, 708' FEL, Sec.6, T13N, R10E, U.M. 5. Type of Well: Development Exploratory Stratigraphic Service Datum elevation (DF or KB) 56' KDB 7. Unit or Property name Milne Point Unit Well number L-9 9. Permit number 90-101 10. APl number 50-029-22075 11. Field/Pool Kuparuk River Field feet 12. Present well condition summary Total depth: measured true vertical 8610' feet Plugs (measured) 7529' feet Effective depth: measured 8498' feet Junk (measured) true vertical 7433' feet Casing Length Size Cemented Measured depth Structural Conductor 79' 13-3/8" 500 sx Permf C 115' Surface 4993' 9-5/8" 82 bbl Class G 5029' Intermediate 512 bbl Permf E Production 8561' 7" 97.7 bbls Class G 8597' Uner Perforation Depth: measured 8107-8128'; 8135-8150'; 8218-8248'; 8263-8276' True vertical depth 115' 4619' 7518' true vertical 7107-7124'; 7130-7142'; 7197-7222'; 7234-7244' Tubing (size, grade, and measured depth) 2-7/8"6.5#/ft, L-80, 8044' Packers and SSSV (type and measured depth) Otis TRSV SCSSV @552'; Otis BWD Pkr. @7986' D r-,. , .... 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure DEC 7 4 Alaska.oil.& Gas Cons. Commi&sk 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Averacje Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure N/A 3607 60 2520 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil~ Gas Suspended Service Waterfiood Injector 17. I hereb~rtify that~ t~,.~..~ is Signed ~ ~~ Form 10-404 I~ev 06/15/88 ~ true and correct to the best of my knowledge. Date [L~t-C[~. SUBMIT IN DUPLICATE CONOCO INC. DAILY WELL ACTIVITY REPORT' ALASKA ~ROJECT: t~/oe, AJ me'J.)'Ti3 j'"~/"'o~, J RIG: ~ J WEATHER: ~- tt'9~/~TEMP./WC:..,~S /3'_.4"°F AT REPORT TIME: ,-/-~ '7--~. r-~/ ~/,j /.,,j ~. [ CURRENT DEPTH: MD ACTIVITY -~J~as~;a Oil & Gas Co~m. Commissi~v ~.ch0rage SERVICE PERSONNEL- NO. JG' Pc FLUID TYPE/DENSITY: Io . l wo ! ;r~ ~o ~^~E ! ~O.~Em^, ~.aOEmS DAYS WITHOUT YEAR TO DATE -',ST DOPE TEST 8OPE TEST DUE /2, o BBLSIcuM. FLUIDCOST: ALL DAILY COSTS PILLS $ SCSSV OPEN/CLOSED BPV IN/OUT $ PLUG DESC. $ COST SUMMARY DAILY CUMULATIVE $ PREVIOUS TOTAL $ $ PPG LOSSES TODAY/CUM AOGCC VISIT? $ ENGINEER PLANNED TROUBLE TOTAL AFE COST $ EST. FINAL COST SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 77251-2175 PLEASE REPLY TO SEP :~ 0 lg92 sc..uMs~.GE, wm s~.v,c~s Pouch 340069 Prudhoe Bay, AK 99734-0069 Conoco, [nc. 3201 "C' Street, Suite 200 Anchorage, AK 99503 Attention:. Ltnda Start Gentlemen: Enclosed ore 3 BLprints of the Compony Conoco, Inc. Injection Profile Log, Run 1, 9/17/92 on: Well Field Milne Point Additional prints ore being sent to: I BL prints Conoco, Inc. 600 North Dairy Ashford - Houston, TX 77079 Attn: George Lamb, OF 2018 PT Milne Point Unit l.-q County North Slope ~o -/o/ Store Alaska I BL prints , ! RF Sepia Chevron U.S.A. 11111 South Wilcrest Houston, TX 77099 Attn: Larry Sydora 713/561-3674 I BL prints Conoco, Inc. ...!000 $opth...Pi_n~ Ponca City, OK 74603 Attn: Glenn Welch, 7391RW 1 BL prints , 1 RF Sepia OXY U.S.A., Inc. _6_ D e~ta _D. rt v_e+ _Suit~- 6002 Midland, TX 79705 Attn: John Carrol .915/685-5898 Ala~t~ 0il & Gas Conservatib~. /~001 Porcupine Drive // ~ch°rage, ~ '~0501 [Attn, prry Grant prints prints The film is returned to Conoco, Linda Starr We oppreciote the privilege of serving you. Received b,: ~R[C[!VED Date: or_r' 2 ~- ,nno Alaska 011 & Gas Cons. Commission Very truly yours. SCHLUMBERGER WELL SERVICES OH/CH (11 BL/3RF) _Ra~_aond N. Dickes STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon.. Suspend __ Operation shutdown __ Re-enter suspended well Alter casing __ Repair well .... Plugging __ Time extention __ Stimulate__ Change approved program Pull tubing __ Variance __ Perforate __ Other x Begin Water Injection 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development__ 56' KDB feet 3. Address Exploratory__ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic__ Milne Point Unit Service X I I 4. Location of well at surface 8. Well number 1752' FNL, 4769' FEL, Sec. 8, T13N, R10E, Umiat Meridian L-9 At top of productive interval 9. Permit number 1289' FSL, 603' FEL, Sec. 6, T13N, R10E, Umiat Meridian 90-101 At effective depth 10. APl number 1488' FSL, 688' FEL, Sec. 6, T13N, R10E, Umiat Meridian 50-029-22075 At total depth 11. Field/Pool 1540' FSL, 708' FEL, Sec. 6, T13N, R10E, Umiat Meridian Kuparuk River Field 1~. Present well condition summary Total depth: measured 8610' feet Plugs (measured) true vertical 7529' feet Effective depth: measured 8498' feet Junk (measured) true vertical 7433' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 79' 13-3/8" 500 sx Permf C 115' 115' Surface 4993' 9-5/8" 82 bbl Class G 5029' 4619' Intermediate 512 bbl Permf E Production 8561' 7" 97.7 bbl Class G 8597' 7518' Liner Perforation Depth: measured 8107-8128'; 8135-8150'; 8218-8248'; 8263-8276' true vertica17107-7124'; 7130-7142'; 7197-7222'; 7234-7244' Tubing (size, grade, and measured depth) 2-7/8" 6.5#/ff, L-80, 8044' A~asJ(a 0ii & Gas Cons. C0mmis, Anch0ra,.qe Packers and SSSV (type and measured depth) Otis TRSV SCSSV @ 552'; Otis BWD Pkr. @7986' 13, Attachments Description summary of proposal , Detailed operations program 14. Estimated date for commencing operation 15, Status of well classification as: October 24, 1991 16. If proposal was verbally approved Oil Gas Name of approver Date approved Service .._Waterflood Injector 17. I hereby certi~fythat t te foregoing is true and correct to the best of my knowledge. Signed ~,],~ /~ ~ J.H. Andrew Title Production Engineer Date October 14, 1991 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness /Approval N,~ / Plug integrity__ BOP Test Location clearance, ---- Mechanical Integrity Test Subsequent form required 10- ~ ~p~.~o\/~d Co~y ' Returned ORIGINAL SIGNED LONNIE C, SMITH Approved by order of the Commission Commissioner Date JO ° Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE AUG E1 ~B1 8:5~ FROM~_.CONOCO RNC ENG?EXPL PAGE.001 CONOCO iNC. DATE; REO. UEST FOR FACSIMILE\~k FROM: J i m Andrew CITY/STATE: Anchorage, Alaska ~o: t~. ~~~-~.- R£CEIVED DEPARTMENT: Alb ~ c c AUG 2 1 1991 CITY/STATE; ~1 & ~as ,,-~ons. Co · · ~ ** · **********************************----*******----***** *** · NO. OF PAGES- COVER SPECIAL INSTRUCTIONS: FAX REPLY NUMB'ER: (1907) 564-7605 or ETN 472-761I Please notit~y my secretar, y, Linda Start, at (907) 564-7611 or ETN 472-761t it~ complete transmission is not, received in good order. Thank you. · ' ~,,.-'~ , ' STATE OF ALASKA ,' /' ALASKA OIL AND GAS CONSERVATION COMMISSION "W LL COMPLETION OR RECONIPL T]ON REPORT AND LOG Classification pt Service Well 1. Status of Well OIL ~ GAS'El SUSPENDED E] ABANDONED 2o Name of Operator CONOCO, Inc. 3. Addr~s 3201 C Street, Suite 200 Anchorage, AK 99503 1.752r FNL, ~' FEL SEC 8 T13N RiOE U. At Top Producing Interval 1289 FSL, 60'3' FEL SEC 6 T13N R10E U At Total Oeoth 1540 FSL, 708". EEL SEC 6 T13N R10E U COMPLETION WATER INJECTION' 7. Permit Number 90-101 APl Number 50- 029-2207.~ 9. Unit or Lease Name Milne Point Unit 10. Well Number I 1. Field and Pool Kuparuk River Field Elevation in feet (indicate KB, OF, etc.) i 6. Lease Designation and Serial No. 56' KB ~ I ADL-25509 --------- -- -- -- -- -- - --band. ] 12~ 13. Date T.O. Reached~P-, Su~o. or A 15. Water Oeot,. if otfshoce 16. No. of Completions 3 / 18. / 91 3/~__---- ~ ~~ ~,,, MSt 1 . of Permairos~ { 500' ~ ~y~ti~a, Survey , 20. Depth where SSSV set ~ickness 86t0' (7529;'~)'-~'~' ~433'~YES~ NO~ ] 552 f,,,~O ~ 22. Type Elastic or Other Logs Run VS~ - DZ~ - ~D~ - CN~ - N6~ -O~0 - C~ 23. CASING. LINER A~D~EMENTING RECORD CASING SIZE!WT. PER FT. 36 24. Perforations open to Production (MO+TVD of Top and Bottom and interval, size and number} All 5$PFgBY GM charges- SETTING DEPTH MD GRADE ~ 8107-8128' MD 8135-8150' MD 8218-8248' MD 7107-7124-TVD 7130-7142' TVD 7197-7222' TVD 8263-8276' MD 7234-7244' TVD HOLE SIZE AMOUNT PULLED 8107-8276' CEMENTING RECORD ermf -~one 12:~ ' 82 BBL Class G = None 512 BBL Permf E ~ 97. BBL Class G-- None 25. TUBING m ECORO SIZE I DEPTH SET (MOl {PACKER SET {MOl 7" 8044 i 7986 26. ACID. FRACTURE. CEMENT SQUEEZE. ETC. DEPTH INTERVAL (MD) I AMOUNT & KIND OF ,,MATERIAL USED [ 17..8,000f~ 16-20 IPROP 27. PRODUCTION TEST Date First Production I Method of Operation {Flowing, gas lift; etc.) 5 / 24 / 91 ._._J Flowing Oat. of Tes, ~l~~ L 11-3 28. CORE DATA W~ GAS-OIL RATIO 0~~ 474 ' 0 I24 Brief descr~pt{on of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None taken. RII EEIVHD AUG 1 1991 .Ala$ 0Il & Sas Cons. Form 10407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE -49 - 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include inte,val ~ested, pressure da~a, all fluids recovered and gravit¥o MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. , · · , .... 31. LIST OF ATTACHMENTS , , . , ..... S~g.ed . ~._~t//~ ~ Ti,,, Prod. En_~ng. o,,, ~O ( 99I ., · , 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 multiole staee cement- lng and the location of the cementing tool. Item 27: Method of O0eratiOn: .Fl'qwincj, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shu[,in,..Other-exptain. Item 28: If no cores taken, indicate "none". Form 10-407 50 - CORE DESCRIPTION FOR CONOCO INC. L-9 MILNE POINT March 1992 FILE ?0090 MICROFILMED 4450 W. 50TH AVENUE · ANCHORAGE, ALASKA 99502 TELEPHONE (907) 243-2822 John Dillon Conoco Inc. Suite 200 3201 "C" St. Anchorage, AK 99503 Dear Mr. Dillon: March 4, 1992 Re: Milne Point L-9 Well Enclosed are copies of the descriptions for cores from your Milne Point L-9 Well. A legend of symbols is included at the back of the report. We appreciate this opportunity to be of service, and trust this report will help in developing this reservoir. If we can'assist you with further sampling of the L-9 core, or in any other way, please give us a call. Sincerely, PETROLEUM TESTING SERVICE, INC. Steve Keyes Geologist PTS:rf Encl. Facies Descriptions Conoco, AK Milne Point, L-9 FACIES A Sandstone; medium to dark brown; fine or very-fine to fine grained, well to moderately-well sorted. Moderately silica cemented with well-developed quartz overgrowths; locally heavy calcite cement (8169'). Rare burrows. Beds are generally grad- ed, becoming silty, very-fine sand near the top. Basal contacts sharp and frequently erosional; upper contacts sharp to grada- tional. Planar cross-lamination (commonly stacked sets) predomi- nates but with ripple cross-laminations, especially near bed tops. Subtle grain size and 'matrix content variations highlight intra-bed scoured contacts; few or no shaly interbeds. Medium to heavy oil stain. FACIES B Intercalated mudstone and argillaceous siltstone and silty, very- fine sandstone. Mudstones are medium to dark gray, slightly silty, and have common to abundant burrows of Types 1 and 2 (see legend). Sandstones and siltstones are light brown, moderately sorted, and usually less than one inch, but up to four inches in thickness. Bases are commonly erosional; tops are generally gradational. Ripple cross-lamination is predominant, but with occasional planar cross-laminations similar to those of Facies A sandstones. Moderately quartz cemented; trace to locally abun- dant Pyrite. Light to moderate oil stain. FACIES C Sandstone, medium brown, very-fine to coarse grained with scat- tered siliceous pebbles; sand grains subangular to subrounded; pebbles sub-rounded to well rounded. Moderately quartz cemented; glauconitic, particularly 8109.5 to 8112.0'. Basal contact erosional. Sideritic (?) matrix; amount increases upward, becom- ing sandy mudstone gradational into overlying Facies E. Massive to indistinctly mottled. Medium oil stain. FACIES D Sandstone, medium brown, very-fine to medium grained, well sorted at base, becoming fair to moderately sorted at the top. Grains are sub-angular with coarser grains being well-rounded, polished, and highly spherical. Moderately quartz cemented with well developed quartz overgrowths. Massive to extensively bioturbat- ed. Sharp basal contact, probably erosional, but largely ob- scured by vertical burrowing. Medium oil stain. FACIES E Mudstone, medium gray to light gray, silty, moderately lithified; scattered bivalve fragments; bivalve lag deposit at 8103.4'; common burrowing (Type 2); mottled to indistinctly laminated. Base transitional with underlying Facies C mudstone/sandstone. No oil stain. In addition to the above facies descriptions, several other features of this core merit mention: 1) Thin beds (one to four inches thick) of volcanic ash (?) are present; they are not facies-specific. One such layer (8226.4') contains a thin bed of ripple-laminated, very-fine grained sand- stone. The sandstone is oil-saturated, and has an erosional base and sharp top. Binocular examination reveals little incorpora- tion of ash into the sand, suggesting the depositional current passed as the ash was settling through the water column. 2) Rapid deposition of Facies A sandstones, possibly on a channel margin or similar sloping surface, is implied by the slumping and soft-sediment faulting present at 8245 - 49'. Here, a thick Facies A sandstone rests on laminated mudstones and siltstones of Facies B. 3) A channel lag deposit is present at 8126.5', where it high- lights an intra-unit scour surface in Facies A sandstone. Clasts in this lag are composed of mudstone and sandstone pebbles, with occasional echinoderm fragments; the matrix is medium to coarse sand. Pyrite is abundant, but occurs mainly in the pebbles. It also replaces some of the bioclasts. i · 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION 3OMPANY Conoco, ~c. . .WELL L-9 FIELD ~[ilne Point ,"ORMATION Ku~k DESCRIBED BY s. Keyes DATE 9/91 , , GRAIN SIZE AND % SAND SEDIMENTARY STRUCTURES CORE BASIC ~ O .- C3 ROCK 1:::: U) ::3 ~ REMARKS DEPTH Z (FEE3) ,/~ z/ \ 100 50 0 O > 0 ~ ~ > ~ 0 ---- 8095 , ,' ~~~ /' ~Cores 2, 3, 4 (7952.0- 8099.9), ~sl~~ 8100 8099.9 Top sl~~ ~~1 ' E _ / (1~ 4.1 feet C-4) _ ,, - - 8108 0 Gradational con~t _ ~md~t ~lauco~; scat- 8110- Top ~. o . C-5 _ ~ 8112.5 Scored con. ct - ~ biot~t~ D - 8117.7 S~ contact 8~20- ~ 8123.4 S~ contact - .. ,, 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION COMPANY conoco, :r. nc. , WELL_L-9 FIELD, _~ti. lne Point FORMATION DESCRIBED BY s. Keyes DATE 9/91 GRAIN SIZE AND 96 SAND SEDIMENTARY STRUCTURES CORE BASIC ....mQ..~ .~ ~._O .- r,,D ::3 '~ REMARKS C3 ROCK E o DEPTH Z (FEE'f) ~ TYPE "J O /x z/ \ >- 100 50 0 r,..3 > O · ,, > ~ O 8125 .I.,,,,I,.t,,I I I ! I I I I ! "~--~" _ :- ----- 8126.6 Pyritic pebble lag 8130_ .,~,?~.._.~__ = ~ 8130.0 Scoured contact 8135_ 7-:'~., i~ - sand, scoured base - - CO 8140 -- _ . 8143.2 Sharp contact - / ' ' · , ~ A 8144.8 Intra-unit scour '.- ' . . · 8147.4 Sharp contact, rubbl~ 8150 - -- ! -~. Exten$-ive Dioturbation; - ~ scattered M-C sand grains _ H 8155 _ " . ,,,, ,I , ,,, ~,, , 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION COMPANY Conoco, Inc. WELL ~,-9 FIELD m~ne Po~t FORMATION K~ DESCRIBED BY s. Keyes DATE 9/9Z , GRAIN SIZE AND 06 SAND SEDIMENTARY STRUCTURES CORE BASIC ~) O ~ ~ ¢x.~ :f.~ ::3 '~ REMARKS r~ ROCK E o DEPTH z ~ O .-= U- (FEE~ ~ ~PE ~ ~ O 100 50 0 O > O · ~ > ~ O 8155 !,,,,I,,,,I I I I I I ! I ,. ~ ,, Top C-~ B 8157 ~ ri~l~l~~~ 8160 _ J s~l~ne ~ s~ds~ne ~s 8165 _ _ I ~1 8168.8-70.4 ~eraeely to H well - ~ v~-fine s~s~ne; bivalve frames 8175 - 8177.9 ~11 8180- 8185 . 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION COMPANY conoco, Inc. WELL ~,-9 FIELD. ~lne Point FORMATION . K.,u~ DESCRIBED BY. s. Keyes DATF 9/91 GRAIN SIZE AND 96 SAND SEDIMENTARY STRUCTURES CORE BASIC C3 ROCK E ~ 03 ::3 '8 REMARKS DEPTH z -- ~ O .-= LL (FEE'D ~ TYPE 03 ...I0 z/ \ 100 50 0 0 > 0 ~ ,, > ~ 0 8185 J,,,,l,,,,I I I I I I I I ! ~--~ _ ,'.-' ' ¢ 8188.0 Bas,? of Core 6 _ , , 8190 ' / ~ 8188.0 - 8223.0 Drilled - 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION COMPANy_conoco, ~c. WELL T,-9 FIELD Mi]ne Po±nt FORMATION :Kuparuk DESCRIBED BY s. :Keyes DATE 9/9l GRAIN SIZE AND 96 SAND SEDIMENTARY STRUCTURES BASIC CORE ¢3 ROCK (/) ~ '~ REMARKS DEPTH z ~ 0 .-~ LL. (FEE~) ~ TYPE 100 50 0 0 > 0 :~ u. > ~ O 8220 !,,,,!,,,,I ! I I I I I I I . ~--'~ i i ii i i ~-------~ ~ ~ -- ~- 8188.0 - 8223.0 Drilled 8223 Top ~ · ' ' ' ~ Stacked cross-bed sets; C-7 . o · . A internal amalgamation 8225 - · ' . · _, ~ 2____~ , ~ 8226.8 Hunm~cky (?) cross- 'i ~ i laminations _ 8230 _ - 8235_ ~ i B - -- 8238.3 Sharp, conformable - ~ contact 8240- A - ~. V~-F sand, very well sort- -i~ ed; megar'ipple cross- -i' ~ laminations with thin _ ~ ~ intercalationS of silt- 8245- ~ stone and silty shale - Small-scale soft-sediment - t - ~ ~ faulting ~-~ ~.~ "- B 8248.6 Con'~:~.¢t obscu.red J-n ~ rubble; probably sharp 8250 - 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION COMPANY Conoco, znc. WELL L-9 FIELD Milne Point FORMATION Kuparuk DESCRIBED BY s. Keyes DATE 9/91 iii i GRAIN SIZE AND % SAND SEDIMENTARY STRUCTURES BASIC CORE DEPTH = ~ ~ i03 '--O REMARKS Z ROCK ~ O (FEET) "~ ~0 ~'T'I ~ TYPE 03 ...J O z/ \ 100 50 0 (.:3 > O ~ - > ~ O ---- 8250 i,,,ll,,,,I I I I ! I I ! I, - -- g " ' Thin sandstone hods; i~ -- ~ ~n to ab~d~t ~E _ ~ burr~ing 8255 ,,, ,, Top ' ._.- ,, C-8 . ~ ~'""-' -'"- 8259 ~~ ~ 8257.0 - 59.0 No recovery 8260 [ "- .~ ~ B 8265 _ , _ = ~] 8266.2 Sharp contact ' ~ A 8269.1 Scour6d contact 8270 _ ~. ~~~ B 8274.1 Intra-unit scour - 8280 _ '__ , 12051 RIVERA ROAD SANTA FE SPRINGS, CA 90670-2289 CORE DESCRIPTION COMPANY Conoco, ~c. , WELL L-9 FIELD ~.ttlne Point FORMATION Kuparuk DESCRIBED BY s. Keyes DATE 9/91 GRAIN SIZE AND 96 SAND SEDIMENTARY STRUCTURES BASIC CORE c3 ROCK E f.D ~: '~ REMARKS DEPTH z (FEET) ~ ~ 0 .-: Lb, Lb, ~ TYPE _.1 0 100 50 0 O > O ·" > ~30 8280 I,,,,I,,,,I I I ! I ! I,, ,I ! , ~ · - ~ -- ' -- B Moderately calcite-cemented 8285 _ 8284.5 Scoured contact 8286 - Top . -. 8290 _ - I I contact: 8295 _ _ -r 8300 - ~ ~' . .,'~ - . , ~, 8303.3 Pyr±te nodules 8305 - - . 8306.7 Bottcan of Core 8 _ 8310 - ~ -~ ~. Legend of Sedimentary Characteristics Conoco Alaska L-9 Core Milne Point, Alaska Ripple/hummocky cross laminations Mega-ripple, tabular-planar cross laminations ~j Shaly, wispy, irregular laminations Burrows, Type 1, >1/4" diameter, predominantly horizontal Burrows, Type 2, <1/8" diameter, sub-horizontal Calcite cement, locally developed, sandstone moderate to well lithified Pyrite, as intergranular cement, grain replacement, or as concretions, up to two inches diameter Grain Size: Granule to pebble Sand Slightly argillaceous I Mudstone/shale Unit Contact: -- ---- Gradational Sharp Erosional CORE ANALYSIS REPORT FOR CONOCO AK L-9 MILNE POINT September 1991 FILE 70091 ICROFiLMED Reports submitted by Petroleum Testing Service are based on the analysis of materials and information supplied by the client, and cannot be guaranteed. These opinions and interpretations expressed represent our best judgement; however, PetroLeum Testing Service assumes no responsibility nor makes any warranty regarding profits or performance resulting from the use of such reports. 4450 W. 50TH AVENUE · ANCHORAGE, ALASKA 99502 TELEPHONE (907) 243-2822 September 11,1991 Mr. Dave Uldrich Conoco Inc. 3201 "C" Street Suite 200 Anchorage, Alaska 99503 Dear Mr. Uldrich: Re: Core Analysis, L-9 Well File No. 70090 Enclosed are copies of the final core analysis report for tests performed on core material recovered from the L-9 Well, Milne Point Field, Alaska. Laboratory procedures have been included for your reference. We appreciate the opportunity to be of service and trust these data will prove beneficial in the development of this reservoir. Sincerely, PETROLEUM TESTING SERVICE, INC. ~%~.. ~ ~'~.~,--.~tpeter T '~; ~.~' President PTS:sk Encl. Company: Conoco Inc. Well: L-9 Field: Milne Point Date: September 11, 1991 File # 70091 ROUTINE CORE ANALYSIS PROCEDURES 1. Drill 1" diameter plugs and trim to a right cylinder 1.5" long using synthetic potassium chloride brine as the cutting fluid. 2. Extract water and hydrocarbons from sample using Dean-Stark toluene method. Record produced water volume. 3. Vacuum dry samples at 150'F until weight is stable (typically 24 hours). Allow sample to cool and weigh the nearest 0.01 gram. 4. Measure bulk volume using mercury displacement method. 5. Measure sand grain volume using a Boyle's Law matrix cup. Calculate porosity, saturations, and grain density. 6. Mount samples in hydrostatic Hassler-type sleeve using a confining stress of 300 psi. 7. Measure permeability to nitrogen gas using a calibrated flow-tube permeameter. COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE .' WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-g FIELD : MILNE POINT COUNTY.' NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE .' I ~ FILE NO.: 70091 DATE .' SEPTEMBER 10, 1991 RESULTS [ I [ I I I l I I I I I S^~URATZO, I I I I I I I GRAZN I SAMPLE I DEPTH IPERMEABILITYIPOROSITY I O/W I OIL WATER TOTAL I DENSITY I NUMBER I ft I mci I x I RATIO I(PERCENT PORE VOLUME)I g/cc I I I I I I I ICORE NO, 4 : 8080,00 - 8110,00 CUT 30,00' I COMMENTS REC 32.00' LITHOLOGICAL DESCRIPTION 1 8108.50 0.6* 12.6 0.0 0.0 81.7 81.7 2.69 *Fractured Ka 2 8109.45 <0.1 9.3 0.5 33.3 66.7 99.9 3.07 Mdst, gry, sdy, wl cmt, glauc, n odr, n stn, n fluor Mdst, gry, sdy, wl cmt, glauc, sl calc, n odr, ev tt stn, fnt dl yet fluor PETROLEUM TESTING SERVICE, INC. COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE .' WATER BASE FORMATION: N/A WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 2 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I I SAMPLE I DEPTH IPERMEABILITYI NUMBER I ft I m~ I I I I 1 I I I I I sATUrATION I I I I GRAIN PorosITY ] O/w I OIL wATER TOTAL I DENSITY % I RATIO i (PERCENT POre VOLUME)I g/cc ICORE NO. 5 : 8110,00 - 8157,00 COMMENTS CUT 47.00' REC 47.00' LITHOLOGICAL DESCRIPTION 3 8110.50 0.3 16.7 0.4 25.6 71.2 96.8 2.78 Sst, gry, fsd-msd, shly, wL cml, gLauc, fnt odr, ev It stn, fnt dl yel fluor 4 8111.50 6.5 17.1 1.0 45.0 43.0 88.0 2.65 Sst, gry, msd-crssd, shly, mod-wl cmt, glauc, fnt cdr, ev med stn, dl yel fluor 5 8112.50 32 21.6 1.0 42.5 44.5 87.0 2.66 Sst, gry, fsd-msd, shly, mod-wl cmt, gLauc, fr odr, ev med stn, d[ yel fluor 6 8113.50 25 7 8114.50 123 21.5 1.2 46.1 39.0 85.1 2.76 22.9 0.7 34.4 49.4 83.8 2.64 Sst, gry, fsd-msd, shly, mod-wl cmt, glauc, fr cdr, ev med stn, dl yel fluor Sst, gry, fsd-msd, st shly, mod cml, glauc, fr odr, ev med stn, d[ yet fluor 8 8115.50 1.8 17.7 2.1 59.2 28.7 87.9 2.84 Sst, gry, lsd, v sh[y w/mdst pbls, wt cml, glauc, fr odr, ev med stn, dl ye[ fluor 9 ' 8116.50 349 24.1 0.6 30.5 51.8 82.3 2.64 Sst, gry, msd, mod cmt, glauc, fr odr, strk med stn, dk yel fluor 10 8117,40 41 21.0 0.8 38.0 48.0 86.1 2.64 Sst, gry, fsd-msd, mod-wl cml, glauc, fr cdr, ev med stn, dl yet fluor 11 8118.50 1.6' 15.5 1.6 53.2 33.3 86.5 2.64 *Fractured Ka Sst, tan, vfsd, sh lam, wl cml, glauc, fr (>dr, ev n~d stn, dl yet fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE .. WATER BASE FORMATION: N/A I I I I SAMPLEI INUMBER I I I I I DEPTH IPERMEABILITYI ft I m~ I ~ I PETROLEUM TESTING SERVICE, INC. WELL .' L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 3 , FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS 1 POROSITY J O/W % J RATIO I I I SATURATION I I I GRAIN I OIL WATER TOTAL J DENSITY J (PERCENT PORE VOLUME)J g/cc J I COMMENTS CORE NO. 5 : 8110.00 - 8157.00 CUT 47.00' REC 47.00' LITHOLOGICAL DESCRIPTION 12 163 13 14 15 16 164 17 18 8119.50 3.8 12.3 0.8 8120.20 8.6 12.3 1.4 8120.50 16 12.4 0.4 8121.50 3.7* 16.7 1.4 8122.50 0.7* 11.1 0.6 8123.50 10 19.9 2.4 ' 8123.80 6.8 20.3 5.6 8124.50 12 8125.50 1050 21.4 4.5 21.8 1.2 39.9 49.8 89.7 2.60 57.2 41.5 98.6 2.65 29.4 67.7 97.0 2.70 52.3 37.2 89.5 2.70 37.5 59.5 97.0 2.61 63.4 26.0 89.4 2.62 71.0 12.8 83.8 2.65 67.8 15.1 82.9 2.65 44.4 37.3 81.6 2.63 *Fractured Ka *Fractured Ka Sst, gry, msd, shly w/sh lam, wl cmt, 9lauc, fr edr, strk med stn, d[ yel fluor Sst, gry, msd-crssd, stty, sh/lam, mod cml, fr edr, strk dk stn, yel-gld fluor Sst, gry, crssd, shly w/sh lam, med-wl cml, bur, fr odr, strk It stn, dl yel fluor Sst, tan, vfsd, shly w/sh Lam, wl cmt, sl pyr, fnt edr, strk [t stn, fnt dl yet fluor Sh, dk gry, slty w/sttst lam, wl cml, bur, fr odr, sptd It stn, dl yel fluor Sst, tan, vfsd, sh tam, wt cml, sl pyr, fr odr, ev med stn, dl yel fluor Sst, tan, vfsd-crssd, lam, wl cml, fr odr, ev dk stn, yel-gld fluor Sst, tan, fsd-msd, shly, wl cml, sl pyr, fr odr, ev med stn, dl yel fluor Sst, tan, msd-crssd, shly lam, mod-wL cml, fr odr, ev n~d stn, dl yel fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE .' WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I i I i I I I I I I I I I SAMPLE I DEPT, IPERMEABILItYI I NUMBERI ft I m~ I I I I I I I I I I SATURATION I I I I GRAIN POROSITY I O/W I OIL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME)I g/cc I ICORE NO, 5 : 8110,00 - 8157,00 I 19 8126.50 537 23.2 20 8127.50 1.3 13.5 21 8128.50 92* 23.6 22 8129.50 58 23.5 165 8129.90 7.7 21.0 23 8130.50 1.7 21.7 24 8131.60 0.8* 14.1 25 8132.50 1.0 11.0 166 8133.00 2.6 17.5 COMMENTS CUT 47.00' REC 47.00' LITHOLOGICAL DESCRIPTION 1.6 50.6 32.4 82.9 2.71 Cong, tan, msd-crssd, clstn pbls, mod-wl cml, sl pyr, fr odr, ev med stn, dl yel fluor 1.1 47.9 42.8 90.7 2.62 Sst, tan, vfsd, shly w/lam, wl cml, bur, fr odr, strk med stn, dl yel fluor 2.7 66.6 24.4 91.0 2.64 *Fractured Ka Sst, tan, vfsdw slty, wl cml, carb lam, fr edr, ev med stn, d[ yel-gld fluor 2.1 61.4 29.3 90.8 2.64 Sst, tan, vfsd, w[ cmt, fr odr, ev med stn, dl ye[-gld fluor 4.8 62.7 13.2 75.9 2.65 Sst, tan, vfsd, slty, wl cmt, fnt odr, ev med stn, yel-gld fluor 3.3 65.1 19.4 84.5 2.63 Sst, tan, vfsd, shly, wl cmt, fr odr, ev med stn, dl yel-gld fluor 0.5 33.5 61.7 95.1 2.65 *Fractured Ka Sst, tan, vfsd, shty, sh lam, wl cmt, fnt odr, strk med stn, dl yel-gld fluor 0.2 19.5 78.7 98.2 2.61 Sh, gry, sdy/lam, wl cmt, bur, fnt (>dr, strk tt stn, dl yel-gld fluor 2.8 60.4 21.3 81.7 2.63 Sst, gry, vfsd, shly w/lam, wl cmt, fnt odr, ev med stn, fnt yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-g FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE .' 5 ' FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I i I I I I SAMPLEI DEPTH IPERME^~ILITYI I NU"BER I ft t md I 26 8133.50 <0.1 27 8134.40 3.3 28 8135.50 2.1 29 8136.50 0.2* 30 8137.60 0.7 31 8138.50 5.3* 32 ' 8139.50 11 33 8140.50 3.7 34 8141.50 0.6 I I I I I SATURATION I I I GRAIN POROSITY I O/N I OIL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME) I ICORE NO. 5 : 8110.00 - 8157.00 I COMMENTS LITHOLOGICAL DESCRIPTION CUT 47.00' REC 47.00' 10.0 0.4 28.8 71.0 99.8 2.59 Sh, gry, sdy lam, wl cmt, bur, fnt odr, strk It stn, dl yel-gtd fluor 19.4 4.2 67.6 16.1 83.8 2.63 Sst, tan, vfsd, shty, wt cmt, fnt odr, ev med stn, dl yel-gld fluor 12.7 0.4 28.9 70.9 99.8 2.61' Sst, tan, vfsd, shty w/sh tam, wl cmt, bur, fnt odr, strk med stn, dl yet-gld fluor 4.0 0.4 24.7 68.2 92.8 2.97 12.6 0.5 32.1 64.5 96.6 2.61 *Fractured Ka Sst, tan, vfsd, shly w/sh lam, v wt cml, pyr, sid, fnt odr, strk It stn, yet fluor Sst, gry, vfsd, crssd, shly w/lam, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor 12.4 0.5 33.5 62.8 96.3 2.58 *Fractured Ka Sst, gry, vfsd-crssd, shly w/lam, w[ cml, bur, fnt odr, strk med stn, dl yel-gld fluor 13.7 0.4 28.7 70.9 99.6 2.56 13.8 0.6 37.8 58.9 96.7 2.58 12.5 0.9 45.7 49.5 95.2 2.61 Sst, gry, vfsd-fsd, shty w/lam, wl cml, bur, fnt odr, strk It stn, d[ ye[-gtd fluor Sst, gry, vfsd-fsd, shly w/tam, wl cml, bur, fnt odr, strk It stn, dl yel-gld fluor Sst, gry, vfsd-fsd, shty w/lam, w[ cml, st pyr, fnt odr, strk [t stn, dl yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : HATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY.' NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 6 , FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I I I I I I I I I t I SATURATION I I SAMPLE I DEPTH IPERMEABILITYI POROSITY I o/u IOIL gATER TOTAL I DENSITY I NUMBER I ft I md I % J RATIO I (PERCENT PORE VOLUME)I g/cc I ICORE NO. 5 : 8110.00 - 8157.00 167 8141.90 3.7 11.2 0.5 34.5 63.0 97.5 2.59 35 8142.50 8.9 13.1 0.2 18.5 80.7 99.2 2.95 36 8143.50 54 20.7 1.2 47.9 40.4 88.3 2.65 37 8144.50 1.6 15.9 2.3 62.2 26.7 89.0 2.63 38 8145.80 0.3 12.8 0.6 34.7 63.1 97.8 2.65 39 8146.50 13 17.7 1.1 45.5 41.3 86.8 2.60 40 ' 8147.50 0.5 12.2 0.7 41.5 57.7 99.2 2.68 41 8148.50 2.7 12.0 0.4 25.1 68.8 93.9 2.69 COMMENTS CUT 47.00' 42 8149.50 0.3 12.4 0.8 42.6 52.7 95.4 2.57 LITHOLOGICAL DESCRIPTION REC 47.00' Sltst, gry, sdy/lam, shly/lam, wl cmt, bur, no odr, strk [t stn, fnt yel-gld fluor Mdst, tan~ clay-fsd, lam, v wl cml, sid, st pyr, fnt odr, strk med stn, dl yel-gld fluor Sst, tan, lsd, w/shty [am, wl cmt, fnt odr, ev med stn, dl yel-gld fluor Sst, tan, vfsd-msd, shly w/lam, wl cml, fnt odr, ev med stn, dl yel-gld fluor Sh, gry, sdy lam, wl cml, s[ pyr, bur, fnt odr, strk med stn, dl yel-gld fluor Sst, tan, vfsd, shly w/lam, wl cml, fnt odr, ev med stn, d[ yel-gld fluor Sltst, gry, sdy, shly w/lam, w[ cml, st pyr, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cml, sl pyr, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 7 ' FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I I I I I I I I I I I I SANPLE I DEPTH IPERHEABILITYI I I I I 43 8150.50 7.9* 44 8151.80 <0.1 45 8152.50 0.2 46 8153.50 0.7 47 8154.50 0.6 48 8155.50 1.7' 49 ' 8156.40 0.7 1 I I I I SATURATION I I I I GRAIN POROSITY I o/w I OZL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME)I g/cc I COMMENTS ICORE NO. 5 : 8110.00 - 8157.00 CUT 47.00' I REC 47.00' 13.6 0.6 37.4 60.2 97.6 2.57 *Fractured Ka 13.1 1.3 50.9 39.3 90.2 2.59 11.8 0.3 22.9 73.4 96.3 2.74 10.4 0.4 27.1 71.4 98.6 2.62 11.6 0.3 21.0 79.0 100.0 2.62 11.9 0.5 32.8 ~.0 98.8 2.62 *Fractured Ka 11.2 0.4 27.4 70.2 97.6 2.57 LITHOLOGICAL DESCRIPTION Sltst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sst, gry, vfsd, shly w/lam, wl cml, bur, fnt odr, ev med stn, fnt yel-gtd fluor Sltst, gry, sdy, v shly, wl cmt, pyr, bur, no odr, strk It stn, fnt yel-g[d fluor Sltst, gry, sdy, shly w/lam, wl cmt, st pyr, bur, no odr, strk It stn, fnt yel-gld fluor ) S[tst, gry, sdy, shly w/lam, wl cml, pyr, bur, no cxJr, strk [t stn, fnt yel-gld fluor Sltst, gry, sdy, shly w/lam, w[ cmt, s[ pyr, bur, no odr, strk [t stn, fnt yel-gld fluor Sltst, gry, sdy, sh[y w/lam, wl cml, fnt odr, strk It stn, fnt yel fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 8 FILE NO..' 70091 DATE .' SEPTEMBER 10, 1991 RESULTS I I I i I J SAMPLE I DEPT, JPERMEABILITYJ I NUMBER J ft J md I I I I i 1 I J J SATURATION I I I I aRAZN POROSITY J O/W I OIL WATER TOTAL J DENSITY % J RATIO I (PERCENT PORE VOLUME)I g/cc I ICORE NO. 6 : 8157.00 - 8188.00 I COMMENTS CUT 31.00' REC 30.70' '168 8157.20 1.0' 12.7 0.7 37.8 58.1 95.9 2.62 *Fractured Ka 50 8157.70 3.4* 11.8 0.5 32.1 64.3 96.4 2.56 *Fractured Ka 51 8158.50 6.1' 12.2 0.3 21.5 77.5 99.0 2.56 *Fractured Ka 52 8159.40 0.2* 11.0 0.5 33.1 65.9 99.0 2.56 *Fractured Ka 53 8160.70 3.2 15.0 0.8 39.5 51.1 90.5 2.62 169 8161.20 0.6 13.5 0.7 37.2 53.7 90.9 2.65 54 ' 8161.70 0.6 13.0 0.9 42.9 49.8 92.6 2.61 55 8162.50 0.3* 10.4 0.1 6.8 88.7 95.5 2.61 *Fractured Ka 56 8163.50 2.8 12.4 0.4 28.1 71.0 99.1 2.61 LITHOLOGICAL DESCRIPTION Sst, gry, vfsd, shly w/lam, wl cmt, bur, no odr, strk It stn, fnt yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cml, bur, fnt odr, strk It stn, fnt yel fluor Sltst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, spt It stn, fnt yel fluor Sltst, gry, shly w/lam, wl cmt, bur, fnt odr, strk It stn, fnt yel fluor Sst, gry, vfsd-fsd, shly lam, wl cml, fnt (>dr, strk med stn, dl yel-gld fluor Sst, gry, vfsd, shly w/lam, wl cml, bur, no odr, strk It stn, fnt yel-gld fluor Sst, gry, vfsd, shly lam, wl cmt, bur, fnt odr, strk med stn~ dl yel-gld fluor Sltst, gry, shly lam, wl cml, pyr, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, shly lam, wl cml, bur, fnt odr, strk n~d stn, dl yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-g FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 9 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I I 1 I I I ISAMPLE I DEPTH IPERMEABILITYI I NUMBER I ft J md I l i i i i I I I SATURATION I I I I GRAIN POROSITY I O/g I OIL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 6 : 8157.00 - 8188.00 I COMMENTS CUT 31.00' REC 30.70' 57 8164.50 3.2 12.2 0.5 31.4 67.4 98.8 2.59 170 8164.90 4.0 13.9 0.9 43.5 47.2 90.7 2.59 58 8165.50 5.6 13.1 0.4 27.0 72.7 99.7 2.58 59 8166.60 2.7 12.8 0.5 30.8 67.0 97.9 2.60 60 8167.50 0.3 12.0 0.4 26.0 71.3 97.3 2.69 61 8168.50 1.2 13.0 0.4 28.6 67.0 95.5 2.83 62 ' 8169.40 1.9 13.1 2.1 61.1 28.6 89.7 2.60 171 8170.10 0.6 9.1 1.2 41.6 35.5 77.0 2.66 63 8170.50 2.8 13.8 1.2 49.5 42.9 92.5 2.61 LITHOLOGICAL DESCRIPTION Sst, gry, vfsd, shly lam, wl cmt, bur, fnt (xJr, strk med stn, dl yet-gld fluor Sst, gry, vfsd, shly w/Lam, wl cml, bur, no odr, strk It stn, fnt yel-gld fluor Sltst, gry, sdy, shly lam, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly lam, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly lam, wl cmt, pyr, fnt (>dr, strk med stn, dl yel-gtd fluor Sst, gry, vfsd, st shly w/lam, wl cml, pyr, bur, fnt (>dr, strk med stn, dl yel-gtd fluor Sst, gry, vfsd-msd, st shty w/lam, wl cml, bur, fr odr, strk med stn, dl yel-gld fluor Sst, gry, vfsd-fsd, tam, wl cml, calc, no (>dr, strk It sin, fnt yel-gld fluor Sst, gry, vfsd, st shly w/lam, wt cmt, sl pyr, bur, fnt odr, strk med stn, dl yel-gld fluor PETROLEUM TESTING SERVICE, INC. COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATIO'N: N/A WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA PAGE : 10 FILE NO.: 70091 DATE .' SEPTEMBER 10, 1991 CONVENTIONAL CORE ANALYSIS RESULTS [ i I i I I I I I SA"PLE I DEPTH IPER.EABILITYI INUMBER I ft I md I 1 i i i I I SATURATION I I I { GRAIN POROSITY I O/W I OIL WATER TOTAL I DENSITY % [ RATIO [ (PERCENT PORE VOLUME)I g/cc ICORE NO. 6 : 8157.00 - 8188.00 I COMMENTS CUT 31.00' REC 30.70" LITHOLOGICAL DESCRIPTION 64 8171.50 5.5 10.0 0.5 33.4 66.0 99.5 2.63 Sltst, gry, sdy tam, shly W/lam, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor 65 8172.50 56* 12.9 0.3 24.3 74.6 98.9 2.61 *Fractured Ka Sltst, gry, shty w/lam, wl cml, fnt edr, strk med stn, dl ye[-g[d fluor 172 8172.70 0.9 15.0 0.6 35.8 57.5 93.3 2.60 Sttst, gry, sdy, shty/lam, wl cml, bur, no odr, strk tt stn, fnt yel-gld fluor 66 8173.50 19' 11.5 0.6 34.7 62.9 97.6 2.60 *Fractured Ka Sltst, gry, shly w/lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor 67 8174.60 3.6 13.0 0.6 35.1 63.7 98.8 2.67 Sltst, gry, shly w/lam, wl cmt, st pyr, bur, fnt odr, strk med stn, dl yel-gld fluor 68 8175.70 1.2 12.7 0.4 29.8 69.0 98.8 2.63 Sst, tan, slty, sh Lam, wl cml, pyr, bur, fnt odr, strk med stn, dl yel-gld fluor 69 8176.60 8.1 11.9 0.9 46.7 53.2 99.9 2.64 Sltst, gry, sdy, shty w/lam, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor 70 8177.30 8.5 12.6 0.4 29.6 69.6 99.2 2.64 Sltst, gry, sdy, shty w/lam, wt cml, st pyr, bur, fnt odr, strk med stn, dl yel-gld fluor 71 8178.60 3.3 13.3 0.4 26.2 73.0 99.2 2.63 Sltst, gry, sdy, shty w/lam, wl cml, st pyr, bur, fnt odr, strk med stn, dl yel-gld fluor . PETROLEUM TESTING SERVICE, INC. COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A WELL : L-9 FIELD : MILNE POINT COUNTY.' NORTH SLOPE STATE : ALASKA PAGE : 11 FI LE NO.: 70091 DATE : SEPTEMBER 10, 1991 CONVENTIONAL CORE ANALYSIS RESULTS I I I I I I I I I I I I I SAMPLE IDEPTH IPERMEABILITYI INUMBER I ft I m~ I I I I I I I 1 I I SATURATION I I I I GRAIN POROSITY I O/W I OIL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 6 : 8157.00 - 8188.00 COMMENTS CUT 31.00' REC 30.70' LITHOLOGICAL DESCRIPTION 72 8179.60 0.8 11.9 0.4 27.0 72.4 99.4 2.61 Sttst, gry, sdy, shty w/lam, wt cmt, st pyr, fnt odr, strk med stn, dl yet-gtd fluor 73 8180.55 6.1 12.1 0.5 32.6 67.4 100.0 2.67 Sttst, gry, sdy, shty w/lam, wt cmt, st pyr, bur, fnt odr, strk med stn, dt yel-gtd fluor 74 8181.50 0.6 11.2 0.5 32.3 67.4 99.7 2.64 SLtst, gry, sdy, shty w/Lam, wt cmt, bur, fnt odr, strk med stn, dt yet-gLd fluor 173 8182.30 <0.1 75 8182.60 16 14.0 3.4 62.9 18.7 81.6 2.67 7.3 0.7 41.1 58.6 99.6 2.62 Sst, gry, vfsd, wt cmt, pyr, fnt odr, ev med stn, yel-gld fluor Sttst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, strk med stn, dl yet-gld fluor 76 8183.50 <0.1 10.7 0.5 33.6 64.5 98.1 2.63 Sltst, gry, sdy, shty w/lam, w[ cml, bur, fnt odr, strk med stn, dl yet-gld fluor 77 ' 8184.50 0.6 13.5 0.9 44.1 48.8 92.9 2.59 Sltst, gry, sdy, shly w/tam, wl cml, bur, fnt odr, strk med stn, dl yet-gtd fluor 78 8185.40 0.3 11.1 0.4 30.6 68.9 99.6 2.60 Sltst, gry, sdy, shty w/lam, wl cml, bur, fnt odr, strk med stn, dl yet-gld fluor 79 8186.40 5.8 13.2 0.7 40.9 58.0 98.9 2.65 Sst, gry, vfsd, slty, shly w/tam, wl cml, bur, fnt odr, strk med stn, d[ yet-gtd fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA PAGE .' 12 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 CONVENTIONAL CORE ANALYSIS RESULTS I I I I ' SAMPLE I DEPTH IPERMEABILITYI POROSITY I O/W NUMBER I ft I md I % I RATIO l' SATURATION I I GRAIN OIL WATER TOTAL I DENSITY (PERCENT PORE VOLUME)I g/cc CORE NO. 6 : 8157.00 - 8188.00 CUT 31.00' COMMENTS REC 30.70' LITHOLOGICAL DESCRIPTION 80 8187.60 0.8 10.7 0.6 37.7 62.3 100.0 2.~ Sltst, gry, shly w/lam, wl cmt, bur~ fnt odr, ev med stn, d[ yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A I ~ I I I I I I I I I I I I I I SAMPLE I DEPT~ I~ERMEABILI~¥1 POROSZT~ I I NUMBER I ft I mci I 81 8223.35 19 24.4 82 8224.50 116 25.0 83 8225.50 184 25.0 84 8226.50 0.4 16.2 85 8227.50 115 24.5 86 8228.50 87 24.5 174 ' 8229.50 81 23.1 87 8229.50 94 25.1 175 8230.50 112 24.8 PETROLEUM TESTING SERVICE, WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE '. ALASKA INC. PAGE : 13 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 CONVENTIONAL CORE ANALYSIS RESULTS I t I I I I SATURATION I I I I I GRAIN I I O/W I O~L WATER TOTAL I DENSITY I COMMENTS I I RATIO I CPERCENT PORE VOLUME)I ./CC I I ICORE NO. 7 : 8223.00 - 8259.00 CUT 36.00' REC 34.00' I LITHOLOGICAL DESCRIPTION 0.8 37.2 48.8 86.0 2.68 Sst, [t gry, vfsd-fsd, wl cmt, s[ pyr, fr odr, ev med stn, d[ ye[-gld fluor 0.8 38.0 49.8 87.8 2.65 Sst, tan, vfsd-fsd, wl cml, fr odr, ev med stn, dl yel-gld fluor 1.4 51.0 37.3 88.3 2.63 Sst, tan, vfsd-fsd, w[ cmt, fr odr, ev med stn, d[ ye[-gld fluor 0.2 19.5 78.1 97.6 3.12 3.9 70.7 18.3 89.0 2.63 Mdst, tan, sdy lam, w[ cmt, sl calc, bur, n odr, sptd med stn, dl yel-gld fluor Sst, tan, vfsd-fsd, w[ cmt, fr odr, ev med stn, dt ye[-gld fluor 2.2 59.8 27.3 87.1 2.63 Sst, tan, vfsd-fsd, wl cmt, fr odr, ev med stn, dl yel-gld fluor 5.9 75.1 12,8 87.9 2.64 Sst, tan, vfsd-fsd, lam, wl cml, fnt odr, ev med stn, yel-gld fluor 3.0 66.8 22.5 89.3 2.63 Sst, tan, vfsd-fsd, wl cml, fr (>dr, ev med stn, dl ye[-g[d fluor 2.2 58.2 26.3 84.5 2.66 Sst, tan, vfsd-fsd, w[ cmt, fr odr, ev med stn, dl yel-g[d fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-g FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE '. ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 14 FILE NO.: 70091 DATE : SEPTEMBER 10, RESULTS 1991 I I I I I I DEPTH IPERMEABILITYI I 88 8230.50 74 I I I I I SATURATION I I I I GRAIN POROSITY I O/W I OIL WATER TOTAL I DENSITY % I RATIO I(PERCENT PORE VOLUME)I g/cc ICORE NO. 7 : 8223.00 - 8259.00 t COMMENTS CUT 36.00' REC 34.00' LITHOLOGICAL DESCRIPTION 23.6 3.9 73.2 18.8 92.0 2.63 Sst, tan, vfsd-fsd, sl s[ty, wl cml, fr odr, ev med stn, d[ ye[-gld fluor 89 8231.50 31 19.5 1.7 56.3 33.7 89.9 2.63 Sst, tan, vfsd-fsd, shly [am, w[ cml, fr odr, ev med stn, dl yel-gld fluor 176 8231.90 71 24.8 4.2 64.2 15.4 79.6 2.70 Sst, tan, vfsd-fsd, wl cmt, fr odr, ev med stn, dl yel-gld fluor 90 8232.50 83 91 8233.50 14 '13.9 1.2 51.7 42.1 93.8 2.63 18.0 3.3 70.3 21.0 91.3 2.63 Sst, gry, vfsd, st shty w/lam, wl cml, fr odr, strk med stn, d[ yel-gld fluor Sst, gry, vfsd, s[ shly w/lam, wl cml, fr odr, ev med stn, dl yel-gld fluor 92 8234.50 9.4 17.3 1.8 57.0 32.4 89.3 2.65 Sst, tan, vfsd-fsd, s[ slty w/lam, wl cml, sl pyr, fr odr, ev med stn, dl yel-gld fluor 93 ' 8235.50 2.2 12.7 0.7 40.4 54.3 94.7 2.61 Sst, tt gry, vfsd, st slty, shty tam, wl cml, bur, fnt odr, strk med stn, dl yet-gtd fluor 94 8236.50 6.3 13.4 0.7 39.5 57.4 96.9 2.63 Sst, It gry, vfsd-fsd, s[ty, shty lam, wl cmt, sl pyr, bur, fnt odr, strk med stn, dl yet-gtd fluor 95 8237.50 5.5 10.7 0.5 32.6 66.9 99.5 2.65 Sltst, gry, sdy, shly tam, wt cml, bur, fnt odr, strk med stn, dl yel-gld fluor ;OMPANY : CONOCO AK ;ORE TYPE: 4 INCH tUD TYPE : WATER BASE :ORMATION: N/A r~T~T T I I I SAMPLE I DEPTH iPERMEABILITYJ J NUMBER J ft I mci J I 96 8238.50 95 97 8239.50 8.7 98 8240.80 2.7 177 8241.40 238 99 8241.50 352 100 8242.45 390 178 8242.60 328 101 8243.50 358 102 8244.45 231 PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 15 FILE NO.: 70091 DATE : SEPTEMBER 10, RESULTS 1991 T T J SATURATION J i i J GRAINJ POROSITY Jo/wi OIL WATER TOTAL J DENSlTYJ RATIO J (PERCENT PORE VOLUME)I g/cc J I I JCORE NO. ? : 8223.00 - 8259.00 COMMENTS CUT 36.00' 21.9 1.1 44.3 40.3 84.6 2.63 9.7 0.5 31.4 67.8 99.2 2.65 14.6 1.2 51.6 44.0 95.5 2.65 26.3 2.8 63.0 22.6 85.6 2.69 25.6 4.9 74.6 15.4 90.0 2.62 24.7 1.9 58.2 31.4 89.5 2.62 27.2 5.4 62.0 11.4 73.4 2.70 25.7 2.8 64.7 23.4 88.1 2.62 22.7 2.2 61.7 27.6 89.4 2.63 LITHOLOGICAL DESCRIPTION REC 34.00' Sst, tan, vfsd-fsd, shLy Lam, wL cml, fnt odr, strk med stn, dl yeL-gLd fluor Sst, gry, vfsd, sLty, shLy Lam, wL cml, fnt odr, strk Lt stn, dL yeL-gld fluor Sst, gry, vfsd, shLy w/Lam, wL cml, fnt odr, strk med stn, dL yeL-gld fluor Sst, Lt gry, vfsd-fsd, wL cml, fr odr, ev med stn, dl yel-gld fluor Sst, It gry, fsd, wL cml, fr odr, ev med stn, dl yet-gLd fluor Sst, Lt gry, fsd, wL cmt, fr odr, ev med stn, dl yeL-gld fluor Sst, It gry, vfsd-fsd, wL cml, fr odr, ev med stn, fnt yel-gld fluor Sst, It gry, fsd, wL cmt, fr odr, ev med stn, dL yel-gLd fluor Sst, It gry, fsd, wL cmt, fr odr, ev med stn, dl yel-gld fluor 1 COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A i I I I SA.PLE I I NU""ER I I I I I DEPTH I PERMEABILITYI ft I ~ I I I I I POROSITY I % 103 8245.40 24 19.7 104 8246.60 27 21.5 105 8247.50 76 24.3 106 8248.60 3.5 20.3 107 8249.50 18' 12.1 108 8250.50 3.7 12.0 179 8250.80 1.8 12.0 109 8251.50 7.2 12.2 180 8251.70 1.5 13.6 PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE .' ALASKA CONVENTIONAL CORE ANALYSIS i i I SATURATION I I I GRAIN O/W I OIL WATER TOTAL I DENSITY RATIO I(PERCENT PORE VOLUME)I g/cc I ICORE NO. 7 : 8223.00 - 8259.00 I COMMENTS CUT 36.00' REC 34.00' 4.2 69.1 16.3 85.5 2.63 3.9 70.0 18.0 88.0 2.64 4.1 71.0 17.3 88.3 2.64 3.0 65.9 22.2 88.1 2.63 0.3 19.3 74.2 93.4 2.60 *Fractured Ka 0.5 31.9 62.5 94.4 2.64 0.4 29.4 66.3 95.7 2.61 0.6 35.8 63.9 99.7 2.64 0.6 30.5 52.7 83.2 2.67 PAGE : 16 FILE NO.: 70091 DATE : SEPTEMBER 10, ~1991 RESULTS LITHOLOGICAL DESCRIPTION Sst, It gry, vfsd, sl shly Lam, wl cml, fr odr, ev med stn, dl yel-gld fluor Sst, tt gry, vfsd, sl shly lam, wl cml, fr odr, ev med stn, dl yel-gld fluor Sst, tt gry, vfsd-fsd st slty, wl cmt, fr (>dr, ev med stn, dl yel-gld fluor Sst, [t gry, vfsd, s[ slty, shly [am, wl cml, bur, fr cdr, ev med stn, dl yel-gld fluor SLtst, gry, shly w/lam, wl cmt, bur, fnt odr, strk It stn, dl yel-gld fluor Sltst, gry, shly w/lam, w[ cml, fnt cdr, strk It stn, dl yel-gld fluor Sltst, gry, sdy, sh[y/lam, wl cml, fnt odr, strk [t stn, yel-gld fluor Sst, gry, vfsd, slty, shly lam, w[ cmt, fnt cdr, strk mod stn, dl yel-gld fluor Sst, gry, vfsd, shly/lam, w[ cmt, bur, fnt cdr, stn, dl yel-gld fluor dl ;OMPANY : CONOCO AK :ORE TYPE: 4 INCH iUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE '. ALASKA CONVENTIONAL CORE ANALYSIS PAGE '. 17 FILE NO.: 70091 DATE : SEPTEMBER 10, RESULTS 1991 I I I SAMPLE I DEPTH [PERMEABILITYI I NUMBERI ft I md I I i I I I SATURATION I I I GRAIN POROSITY I 0/~ I OIL ~ATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 7 : 8223.00 - 8259.00 [ COMMENTS CUT 36.00' REC 34.00' LITHOLOGICAL DESCRIPTION 110 8252.50 0.6 111 8253.50 0.2 112 8254.00 113 8255.60 0.6* 114 8256.50 2.9* 14.8 1.3 50.3 39.1 89.4 2.65 10.4 0.6 38.0 61.9 99.9 2.66 11.9 0.3 22.2 77.3 99.5 2.66 11.8 0.3 22.1 77.1 99.2 2.63 No Sample *Fractured Ka *Fractured Ka Sst, gry, vfsd, stty, shty tam, wt cml, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/tam, w{ cml, bur, fnt (>dr, strk stnv dl yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, strk stn, dl yel-gld fluor COMPANY .' CONOCO AK CORE TYPE: 4 INCH MUD TYPE .' WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE .' 18 FILE NO.: 70091 DATE .' SEPTEMBER 10, RESULTS 1991 I I I I SAMPLE I DEPTH I NUMBER I ft I I I I I I SATURAT]ON I I IGRAIN POROSITY I o/w I OIL WATER TOTAL I DENSITY % I RATIO [ (PERCENT PORE VOLUME)I g/cc [CORE NO. 8 : 8259.00 - 8307.00 COMMENTS CUT 48.00' REC 47.70' LITHOLOGICAL DESCRIPTION 115 8259.60 0.5 10.3 0.4 29.0 65.6 94.6 2.69 Sltst, gry, sdy, shly w/lam, wl cml, sl pyr, b~r, fnt odr, spt It stn, dl yel-gld fluor 116 8260.60 0.2 10.7 0.6 34.9 60.2 95.1 2.68 Sh, dk gry, sdy lam, slty, wl cml, bur, fnt odr, spt It stn, dl yel-gld fluor 117 8261.50 2.0 11.3 0.3 23.6 76.0 99.6 2.64 Sltst, gry, sdy lam, shly lam, wl cml, bur, fnt odr, strk It stn, dl yel-gld fluor 118 8262.50 0.9 119 8263.50 34 13.1 0.9 43.9 51.0 94.9 2.62 19.1 1.2 47.9 38.6 86.5 2.63 Sst, gry, slty, shly lam, w[ cml, bur, fr odr, ev med stn, dl yel-gld fluor } Sst, gry, slty, sl shly lam, wl cml, fr odr, ev med stn, dl ye[-gld fluor 120 8264.50 3.8 11.5 0.2 18.0 73.6 91.6 2.70 Sh, gry, sdy tam, s[ty, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor 121 8265.50 5.8* 12.6 0.4 28.0 71.7 99.6 2.67 *Fractured Ka Sst, gry, vfsd-fsd, shly lam, wt cml, s[ pyr, bur, fnr odr, strk [t stn, dl ye[-gld fluor 122 8266.50 110 22.2 0.9 41.6 46.6 88.2 2.63 Sst, tan, vfsd-fsd, wl cmt, fnt odr, ev med stn, d[ yel-gld fluor 123 8267.50 160 22.7 1.0 43.2 45.0 88.2 2.62 Sst, tan, vfsd-fsd, wl cml, fnt odr, ev med sun, d[ yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE .' WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY'. NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 19 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I i I I I I I I I I I I SAMPLEI DEPTH IPERMEABILITYI I NUMBER I ft I md I t I I 124 8268.50 163 125 8269.50 3.5 126 8270.50 2.2 127 8271.50 2.8 181 8272.10 16 128 8272.50 6.7 129 8273.50 51 130 8274.50 17 131 8275.50 6.6 i I i I I SATURATION I I I GRAIN POROSITY I O/W I OIL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME) ICORE NO. 8 : 8259.00 - 8307.00 I COMMENTS CUT 48.00' REC 47.70' 22.6 0.9 39.2 45.3 84.5 2.63 15.9 1.1 50.0 44.9 94.9 2.64 13.8 1.0 48.9 50.7 99.6 2.62 11.0 0.7 37.7 56.9 94.6 2.62 15.7 0.8 39.8 51.3 91.0 2.64 12.5 0.8 40.6 53.9 94.5 2.63 20.6 1.0 42.0 42.4 84.4 2.63 15.8 0.5 34.0 63.1 97.1 2.63 15.1 0.9 44.0 50.6 94.7 2.66 LITHOLOGICAL DESCRIPTION Sst, tan, vfsd-fsd, wL cmt, fnt odr, ev med stn, dl yel-gld fluor Sst, tan, slty, shLy lam, wL cml, bur, fnt odr, strk med stn, dl yel-gld fluor Sst, gry, vfsd, shLy w/lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sst, gry, vfsd, shly w/Lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sst, gry, vfsd, shly/Lam, wl cml, bur, fnt odr, strk med stn, dl yel-gld fluor Sh, dk gry, sdy Lam, slty Lam, wl cmt, st pyr, bur, fnt odr, strk med stn, dL yet-gtd fluor Sst, Lt gry, vfsd-fsd, st shly Lam, wl cml, calc, fnt odr, ev med stn, dl yeL-gld fluor Sst, gry, vfsd shly Lam, wl cml, bur, fnt odr, strk med stn, dl yet-gld fluor Sst, gry, vfsd shLy lam, wt cml, pyr, bur, fnt odr, strk med stn, dl yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENT I ONAL CORE ANAL Y S I S PAGE : 20 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I 1 I I I SAMPLE I DEPTH )PERMEABILITYI NUMBER I ft I md I I I I ] i I I I SATURATION I I I I GRAIN POROSITY J O/W I OIL WATER TOTAL I DENSITY % I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 8 : 8259.00 - 8307.00 [ COMMENTS CUT 48.00' REC 47.70' LITHOLOGICAL DESCRIPTION 132 8276,50 12 133 8277.50 134 8278.50 135 8279.50 136 8280.50 137 8281.50 138 8282.50 13 139 8283.50 182 8283.90 17 14.6 0.7 39.8 59,7 99.6 2.63 6.0 13.1 0.4 24.2 69.2 93.4 2.61 1.5 13.6 0.5 34.1 64.3 98.4 2.61 4.7 20.1 0.8 29.8 35.8 65.6 2.61 0.3 14.7 0.8 43.5 52.9 96,4 2.66 9.7 12.1 0.4 27.1 67.9 95.1 2.62 13.4 1.6 58.3 35.4 93.7 2.64 2.6 10.5 2.5 62.3 24.9 87.1 2.67 21,7 3.3 59.6 17.9 77.5 2.72 Sst, gry, vfsd, shly lam, wl cml, bur, fnt odr, strk med stn, d[ yel-g[d fluor Sst~ gry, vfsd, sh[y [am, w[ cml, bur, fnt odr, strk lt-med stn, dl ye[-gld fluor Sltst, gry, sdy, shly tam, wl cml, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sst, gry, vfsd, slty, shly lam, w[ cml, bur, fnt odr, strk [t-med stn, dl yel-gld fluor Sst, gry, vfsd, s[ty, shly lam, wl cml, bur, fnt odr, strk lt-med stn, dl yet-gld fluor Sltst, dk gry, sdy, sh[y lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sst, gry, vfsd, shly w/tam, wl cmt, bur, fnt odr, strk med stn, d[ yel-gld fluor Sst, tan, vfsd, s[ slty w/Lam, wl cml, ca[c, fnt odr, ev It med stn, dl yel-gld fluor Sst, gry, vfsd, wl cmt, fnt odr, ev It stn, fnt yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A I I I I I SAMPLEI DEPTH IPERMEASILITYI INUMBER I ft I md I PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 21 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I I' I I I sATuRATION I POROsltYIO/uIOIL ~/ATEr total I~eNsItYI % I RATIO ] (PERCENT Pore VOLUME)I g/cc COMMENTS LITHOLOGICAL DESCRIPTION 140 8284.50 4.4 141 8285.50 1,8 142 8286.50 2,1 143 8287.50 9.1' 144 8288.50 8,1 145 8289.50 12 146 8290.50 15' 147 8291.50 1.8 148 8292.50 2.7 ICORE NO. 8 : 8259.00 - 8307.00 CUT 48.00' 14.1 0.5 33.9 63.8 97,7 2.~ 15,1 1.0 45.0 44.3 89,3 2.62 14.2 0.9 44.6 47.6 92.2 2.63 13,9 0.4 26,5 71.1 97.6 2,62 *Fractured Ka 14.6 0,8 40.6 52.5 93.1 2.63 14.9 0,3 24.6 70.4 94.9 2,64 13.6 0.2 18,0 77.1 95.1 2.60 *Fractured Ka 13,6 0.8 43.3 53.1 96.4 2,67 13.5 0.6 38.3 61.6 99,9 2,61 rEC 47.70' Sst, gry, vfsd, slty, shly lam, wl cmt, sl calc, bur, fnt odr, strk med stn, dl yel-gtd fluor Sst, gry, vfsd, slty, shly lam, wl cml, bur, fnt odr, strk med stn, dt yel-gtd fluor Sltst, gry, sdy, shly w/ lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/ lam, w[ cml, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/ lam, wl cmt, bur, fnt odr, strk med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/ lam, w[ cml, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sst, gry, vfsd, v shty w/ lam, w[ cmt, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst, gry, sdy, sh[y w/lam, wl cmt, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cmt, bur, fnt odr, strk [t-med stn, dl yel-gld fluor :OMPANY .' CONOCO AK CORE TYPE: 4 INCH ~IUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL .' L-g FIELD .' MILNE POINT COUNTY: NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 22 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS i I I I I I SAMPLE I DEPTH IPERMEABILITYI NUMBER I ft I md I I I I 149 8293.40 4.9 150 8294.50 0.6 151 8295.40 6.5* 152 8296.50 4.5 153 8297.40 7.9 154 8298.60 5.8 155 8299.60 5.8 156 8300.60 4.2 157 8301.50 1.2 I i i I I sATURATION I I I I GraIN PorosItY I o/w I OIL water totAL I DeNsltY % I RATIO I (PERCENT POre VOLUME)I g/cc I COMMENTS ICORE NO. 8 : 8259.00 - 8307.00 CUT 48.00' I REC 47.70' 13.0 0.4 29.7 66.0 95.7 2.60 14.3 1.4 54.9 38.6 93.5' 2.62 13.3 0.6 35.5 63.6 99.0 2.63 *Fractured Ka 14.5 0.6 37.9 59.6 97.4 2.66 13.3 0.5 31.9 67.8 99.6 2.61 15.1 0.9 45.0 49.4 94.4 2.61 12.2 0.5 32.0 67.9 99.9 2.60 12.1 0.4 26.1 73.3 99.4 2.60 11.4 0.4 28.3 71.2 99.5 2.62 L[THOLOGICAL DESCRIPTION Sltst, gry, sdy, shty w/Lam, wl cmt, bur, fnt odr, strk tt-med stn, dl yel-gld fluor Sttst, gry, stt-vfsd, shty w/lam, wt cmt, bur, fnt odr, strk tt-med stn, dt yet-gld fluor Sltst, gry, shly w/lam, wt cmt, bur, fnt odr, strk tt-med stn, dl yel-gld fluor Sst, gry, vfsd, shty w/lam, wt cml, bur, fnt odr, strk tt-med stn, dl yel-gld fluor Sst, gry, vfsd, shty w/lam, wl cml, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sst, gry, vfsd, sh Lam, wl cmt, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst, gry, sdy w/Lam, shly w/lam, wl cml, bur, fnt odr, strk [t-med stn, dl yel-gld fluor Sltst, gry, sdy w/lam, shly w/lam, wl cml, bur, fnt odr, strk lt-med stn, dl yet-gld fluor Sltst, gry, sdy, shty w/lam, wl cml, bur, fnt odr, strk lt-med stn, dl ye[-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, INC. WELL : L-9 FIELD : MILNE POINT COUNTY.' NORTH SLOPE STATE : ALASKA CONVENTIONAL CORE ANALYSIS PAGE : 23 FILE NO.: 70091 DATE : SEPTEMBER 10, 1991 RESULTS I I I I I I I I I I I SATURATION I I I I I I I ~R^I~ I SAMPLEI DEPTH IPERMEABILITYI POROSITYI o/w I OIL WATER TOTAL I DENSlTYI NUMBER I ft I md I % I RATIO I (PERCENT PORE VOLUME)I g/cc ICORE NO. 8 : 8259.00 COMMENTS 8307.00 CUT 48.00' REC 47.70' 158 8302.60 3.6 12.8 0.4 28.6 69.6 98.1 2.62 159 8303.60 1.8 12.7 0.6 38.1 58.9 97.0 2.61 160 8304.60 3.1 13.7 0.4 27.6 71.8 99.4 2.72 161 8305.50 6.0 12.5 0.6 36.0 62.3 98.3 2.61 162 8306.60 3.0 13.8 0.2 15.7 83.9 99.6 2.65 LITHOLOGICAL DESCRIPTION Sltst, gry, sdy, shly w/lam, wl cml, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst~ gry, sdy, shly w/lam, wl cml, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst, gry, sdy, shly w/lam, wl cml, sid lam, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst, gry, v sdy, shly w/lam, wl cmt, bur, fnt odr, strk lt-med stn, dl yel-gld fluor Sltst, gry, shly w/lam, wl cml, fnt odr, sptd [t-med stn, dl yel-gld fluor COMPANY : CONOCO AK CORE TYPE: 4 INCH MUD TYPE : WATER BASE FORMATION: N/A PETROLEUM TESTING SERVICE, WELL : L-9 FIELD : MILNE POINT COUNTY : NORTH SLOPE STATE : ALASKA INC. FILE NO.: 70091 ' DATE : SEPTEMBER 10, 1991 SUMMARY OF CORE ANALYSIS DATA FORMATION AND RANGE DATA Formation Top Depth 8108.50 ft Bottom Depth 8306.60 ft Number Of Samples 182 Range: Porosity (Minimum) 0.0 % Porosity (Maximum) 100.0 % Permeability (Minimum) 0.1 md Permeability (Maximum) 10000.0 md Saturation (Minimum) 0.0 % Saturation (Maximum) 100.0 % Grain Density (Minimum) 2.0 g/cc Grain Density (Maximum) 3.0 g/cc Permeabil ity Rounding Criterion: > 10000 md - Reported As > 10000 md 1000 '- 9999.99 md - Rounded To Nearest 10 md 10 - 999.99 md - Rounded To Nearest 1 md 0.1 - 9.99 md - Rounded To Nearest 0.1 md < 0.1 md - Reported As < 0.1 md STATISTICS FOR SAMPLES REMAINING AFTER APPLYING EXCLUSION CRITERION Format i on: Poros i ty: Permeab i 1 i ty: Number Of Samples 181 Minimum 4.0 % Minimum Thickness Represented 198.10 ft Maximum 27.2 % Maximum Arithmetic Mean 15.3 % Arithmetic Mean Median 13.5 % Geometric Mean Median Grain Density: Average Saturations: Minimum 2.56 g/cc Oil 41.2 % P.V Maximum 3.12 g/cc Water 52.1 % P.V Arithmetic Mean 2,65 g/cc Median 2,63 g/cc Exclusion Criterion Samples Excluded 1 Vertical Samples Side Wall Samples Samples With Permeabilities < 0.1 Samples With Permeabilities > 10000 Mi scel 1 aneous Data Type Of Extraction Dean-Stark Confining Stress 300 psi Oil Gravity 22.0 'APl 0.2 md 1050 md 38 md 5.6 md 4.5 md PETROLEUM TESTING SERVICE, INC. FILE NO.: DATE: 7O091 SEPTEMBER 19, 1991 CLIENT: CONOCO AK WELL: L-9 FIELD: MILNE POINT STATE: ALASKA DEPTH INTERVAL: 8108.50-8506.60 POROSITY HISTOGRN~ (lee'l:) 100 Cumulative Frequency Arithmetic Mean 15.5 Median Value 15.5 100 9O 80 7O I50 30 20 10 10 12 14 16 18 20 22 24 26 28 9O 8O 70i 30 i~ 2O 10 0 30 PETROLEUM TESTING SERVICE. INC. FILE NO.* DATE: 70091 SEPTEMBER 19, 1991 CLIENT: CONOCO AK WELL: L-9 FIELD: MILNE POINT STATE: ALASKA DEPTH INTERVAL: 8108.50-8506,60 PERMEABILITY HISTOGRAM (feet) lO0 Cumulative Frequency Geometric Mean 5.6 Median Value 4.5 100 9O 8O 7O i6O 50 2O 10 0 0 .005 .01 .02 .Ok .08 .16 .32 .64 1.25 2.5 5 10 20 40 80 160 320 640 1280 2560 5120 10240 9O 8O 7oI 2O 10 PETROLEUM TESTING SERVICE. INC. FILE NO.' DATE: 70091 SEPTEMBER 19, 1991 CLIENT: CONOCO AK WELL: L-9 FIELD: MILNE POINT STATE: ALASKA DEPTH INTERVAL: 8108.50-8506.60 POROSITY- PERMEABILITY CROSSPLOT (feet) 1 0000 IOO0 100 10 -0.1 O.01 . 0 - 10 20 POROSITY. pement , , PETROLEUM TESTING SERVICE, INC. FILE NO.' DATE: 70091 SEPTEMBER 19, 1991 CLIENT: CONOCO AK WELL: L-9 FIELD: MILNE POINT STATE: ALASKA DEPTH INTERVAL: 8108.50-8506.60 G~N DENSITY- POROSITY CROSSPLOT (feet) 3.50 3.00 2.50 i 2.00 1.50 0 10 2O POROSITY. percent 30 Milne Point L No. 9 - Drill & Equip. API No.: 50-029-22075 Location: Milne Point Field - Kuparuk River Pool AFE Number: 10-61-1300 Approved: 07/20/90, NOC 01/18/91 AFE Amount: $2,712,000 gross Cost to Date: $2,382,733 gross Operator: Conoco 0.7214934 Chevron 0.1737352 OXY 0.1047714 Objectives: Kuparuk Reservoir Spud Date: Rig-. 03/15/91 Nabors 27E Rig Release Date: 04/04/91 @ 2130 hrs Drilling Days: Completion Days: Planned Actual 22 21 Planned Actual Depth: 8,609' MD 8,610' MD DRILLING HISTORY 03/15/91: PU rig f/ L-10. Move in and rig up. PU Rig at 2030 hrs, 03-14-91. Take on drilling fluid. NU Diverter. MU 12 1/4" bit and BHA. 03/16/91: Mix spud mud. Drill f/ 115' to 1100'. Short trip. Drill to 1982'. 03/17/91: POOH for BHA change. MU Steerable BHA and RIH. Drill f/ 1982' to 3006'. Run WL survey. Short trip 10 stds. Drill to 4050'. Short trip 10 stds. 03/18/91: Drill f/ 4050' to 5050'. C & C. Short trip. C & C. POOH to log. 03/19/91: Fin POOH. Run 4 arm caliper on EL. Run 9 5/8" casing. Ran 117 jts, 4982' 36 PPF K-55 Butt csg Circ and recip Cement first stage w/ 205 BBL Permafrost E cmt at 12.3 PPG and 72 BBL G cmt at 15.8 PPG. Bump plug. Land csg. FS at 5029'. ' FC at 4948'. Open HOS stage collar at 1806'. Circ for second stage cement job. 03/20/91: Cement second stage w/ 307 BBL Permafrost E at 12.3 PPG and 10 BBL G at 15.8 PPG. Disp same. Bump plug and shear HOS stage collar closed. Test to 2000 psi. ND Diverter. MU Speed Head. NU BOP's. Test same. MU Steerable BHA. Drill out HOS cementer at 1806'. RIH to 4910'. Test csg to 1500 psi. Drill out float equip and cement to 5050'. Drill 10' new hole to 5060'. 03/21/91: Circ. Run leakoff test to 13.5 PPG EMW. Drill f/ 5060' to 6100'. Short trip 12 stds. Drill to 6224' Motor stalling. POOH. Change out motor and bit. RIH. Drill to 6391'. 03/22/91: Drill f/ 6391' to 7177'. Short trip 11 stds. Drill to 7952' (Core Point). C & C. 03/23/91: Circ. Displace hole w/ KCL coring fluid. POOH. LD BHA. MU Core Barrel. RIH. Ream 56' to 7952'. Attempt to core. No progress. POOH. Made 2'. No recovery. RIH. Core f/ 7954' to 7956'. DRILLING HISTORY - MILNE POINT UNIT Page 2 WELL NO. L-9 (Continued) 03/24/91: Core f/ 7956' to 7967'. POOH. Cut 13'. Recover 12'· RIH w/ bit. Drill f/ 7967' to 8076'. Circ. POOH. RIH w/ Core Barrel. 03/25/91: Core f/ 8076' to 8080' Barrel jammed. POOH. Recover 2'. RIH w/ 60' Core Barrel] Core 8080' to 8110' (Drlg break at 8110'). POOH. Recover 32'. 03/26/91: Wash and ream 17' fill, circulate, drop ball. Cored from 8,110' to 8,157'. POOH lay down core, recovered 46' core RIH ream 12', circulate, drop ball, core from 8157' to 8188'~ 03/27/91: POOH from 8188' with core. Recovered 31' RIH and washed 15' Drilled from 8188' - 8223'. Circulate ~ottoms up, pump dr~ job, blowdown kelly and POOH. Lay down BHA and pick up core barrel. RIH and cored from 8223' - 8259', barrel jammed, POOH and layed down core. Recovered 34'. Dressed core barrel, changed bit and RIH. Wash and ream 8' of fill. Coring 8259' - 8262'. 03/28/91: Cored from 8262' - 8307'_ POOH, Layed down core #8, recovered 45' Layed down core barrel · and cleared the floor. Pulled wear ring, tested BOPs and manifold. Make up BHA, RIH and washed 10' of fill. Drilled from 8307' - 8475'. 03/29/91: DRLG from 8475' - 8610'. Circulate and short trip to 8200'. Circulate, pump dry job and POOH. RU loggers and run DIL/NGT/CNL/LDT FROM 8610' - 5026'. Run RFT in each sand. POOH and rigged down loggers. 03/30/91: RIH to 8610', circulate and condition, POOH and LD drill pipe and BHA. Pull wear ring and change to 7" rams. RU and run 199 joints of 7" casing. Circulate and reciprocate. Pump 50 bbls 11 ppg sepiolite followed by 50 bbls of water. Drop bottom plug and pump 93.7 bbls of class G cement. Displaced with 325 bbls 10.2 NaCl-NaBr brine and bumped plug to 1,800 psig. Checked floats and pressured tested casing to 1,500 psig for 30 minutes. 03/31/91: Clean pits and inject mud. Packoff would not test. Nipple down between tubing and casing spool. Redress packoff and tested OK. RIH with bit and casing scrapers to 8503'. Reverse circulated 25 bbls. HEC pill, 50 bbls dirt magnet, 25 bbls HEC pill. Circulate and filter brine until clean. POOH and LD drill pipe. 04/01/91: Rig up Schlumberger and run VSP from 8500' to surface. Run CBT from 8500' to 6700' (TOC @ 6850'). Run GCT from 8490' - surface. Rigging up to perforate. COMPLETION HISTORY - MILNE POINT UNIT WELL NO. L-9 Page 3 04/02/91: Perforate 4 zones f/ 8263 - 8276, f/ 8218 to 8248, f/ 8135 to 8150, & f/ 8107 to 8128. RD EL. RIH to 500' w/ PKR on 4 1/2" TBG. PU annulus to 2000 psi. Frac well w/ 2142 BBL Gel, 150,300 LBS 16/20 sand, and 25,710 LBS 12/18 sand. Flush w/ 296 BBL Brine at 40 BPM. Max pressure 3186 psi. Avg pressure 2500 psi. Wait on gels to break. 04/03/91: Wait on gels to break. Release PKR. POOH, LD TBG. RIH w/ Bailer. Tag sand at 8227'. Bail sand f/ 8227' to 8232'. Bailer quit. POOH. Recover 1/2 BBL sand and rubber seal f/ surface lines. RIH w/ bailer. Bail sand f/ 8232' to 8409'. POOH. Recover 6.9 BBL sand. 04/04/91: RIH w/ Bailer. Bail f/ 8398' to 8500'. POOH. RU EL. Run and set Packer at 7980'. RD EL. RU to run tubing. 04/05/91: RIH w/ 2-7/8" tubing. MU SCSSV and pressure tested control line to 5,000 psig. Space out and land 2-7/8" tubing hanger and slackoff 10,000 lbs. Filled backside and pressure tested packer to 3,500 psig. Sting out of packer and pumped 15 bbls diesel down tubing to freeze protect. Sting back into packer, drop ball and pressure test tubing to 3,000 psig for 5 minutes. Install BPV. Nipple down BOPs, nipple up tree and test to 5,000 psig. Tested annulus to 1,750 psig for 30 minutes with AOGCC representative present. Freeze protect 7" x 9-5/8" annulus and released rig at 2130 on 04/04/91. Operations suspended pending hookup. AUG 2 1 1991 Alas~.Oil .& Gas Cons. Commissien Anchorage OPERATOR: CONOCO, INC. MILNE POINT UNIT FINAL DRILLING & COMPLETION REPORT '"c~ 6"~s , /"~'.~,.¢ WELL: MPU L-g FIELD: KUPARUK PTD: 8609' CASING: 13 3/8" @ 115' 9 5/8" @ 5O29' 7" @ 8597' CURRENT TD: 8610' PROGRESS: 0 DATE: 04/05/91: 04/04/91: 04/03/91: 04/02/91: 04/01/91: 03/31/91: 03/30/91: Description of Operations: COMPLETING RIH w/2-7/8" tubing. MU SCSSV and pressure tested control line to 5,000 psig. Space out and land 2-7/8" tubing hanger and slackoff 10,000 lbs. Filled backside and pressure tested packer to 3,500 psig. Sting out of packer and pumped 15 bbls diesel down tubing to freeze protect. Sting back into packer, drop ball and pressure test tubing to 3,000 psig for 5 minutes. Install BPV. Nipple down BOPs nipple up tree and test to 5,000 psig. Tested annulus to 1,750 psig for 30 minutes with AOGCC representative present. Freeze protect 7" x 9-5/8" annulus and released rig at 2130. RIH w/Bailer. Bail f/8398' to 8500'. POOH. RU EL. Run and set Packer at 7980'. RD EL. RU to run tubing. Wait on gels to break. Release PKR. POOH, LD TBG. RIH w/Bailer. Tag sand at 8227'. Bail sand f/8227' to 8232'. Bailer quit. POOH. Recover 1/2 BBL sand and rubber seal f/surface lines. RIH w/bailer. Bail sand f/8232' to 8409'. POOH. Recover 6.9 BBL sand. Perforate 4 zones f/8263 - 8276, f/8218 to 8248, f/8135 to 8150, & f/8107 to 8128. RD EL. RIH to 500' w/PKR on 4 1/2" TBG. PU annulus to 2000 psi. Frac well w/2142 BBL Gel, 150,300 LBS 16/20 sand, and 25,710 LBS 12/18 sand. Flush w/ 296 BBL Brine at 40 BPM. Max pressure 3186 psi. Avg pressure 2500 psi. Wait on gels to break. Rig up Schlumberger and run VSP from 8500' to surface. Run CBT from 8500' to 6700' (TOC @ 6850'). Run GCT from 8490' - surface. Rigging up to perforate. Clean pits and inject mud. Packoff would not test. Nipple down between tubing and casing spool. Redress packoff and tested OK. RIH with bit and casing scrapers to 8503'. Reverse circulated 25 bbls. HEC pill, 50 bbls. dirt magnet, 25 bbls. HEC pill. Circulate and filter brine until clean. POOH and LD drill pipe. RIH to 8610', circulate and condition, POOH and LD drill pipe and BHA. Pull wear ring and change to 7" rams. RU and run 199 joints of 7" casing. Circulate and reciprocate. Pump 50 bbls 11 ppg sepiolite followed by 50 bbls of water. Drop bottom plug and pump 93.7 bbls of class G cement. Displaced with 325 bbls 10.2 NaCI-NaBr brine and 03/29/91: 03/28/91: 03/27/91: 03/26/91: 03/25/91: 03/24/91: 03/23/91: 03/22/91: 03/21/91: 03/20/91: 03/19/91: 03/18/91: 03/17/91: 03/15/91: bumped plug To 1,800 psig. Checked floats and pressurud tested casing to 1,500 psig for 30 minutes. DRLG from 8475' - 8610'. Circulate and short trip to 8200'. Circulate, pump dry job and POOH. RU loggers and run DIL/NGT/CNL/LDT FROM 8610' - 5026'. Run RFT in each sand. POOH and rigged down loggers. Cored from 8262' - 8307'. POOH, Layed down core #8, recovered 45'. Layed down core barrel and cleared the floor. Pulled wear ring, tested BOPs and manifold. Make up BHA, RIH and washed 10' of fill. Drilled from 8307' - 8475'. POOH from 8188' with core. Recovered 31 '. RIH and washed 15'. Drilled from 8188' - 8223'. Circulate bottoms up, pump dry job, blowdown kelly and POOH. Lay down BHA and pick up core barrel. RIH and cored from 8223' - 8259', barrel jammed, POOH and layed down core. Recovered 34'. Dressed core barrel, changed bit and RIH. Wash and ream 8' of fill. Coring 8259' - 8262'. Wash and ream 17' fill, circulate, drop ball. Cored from 8,110' to 8,157'. POOH lay down core, recovered 46' core. RIH ream 12', circulate, drop ball, core from 8157' to 8188'. Core f/8076' to 8080'. Barrel jammed. POOH. Recover 2'. RIH w/60' Core Barrel. Core 8080' to 8110' (Drlg break at 8110'). POOH. Recover 32'. Core f/7956' to 7967'. POOH. Cut 13'. Recover 12'. RIH w/bit. Drill f/7967' to 8076'. Circ. POOH. RIH w/Core Barrel. Circ. Displace hole w/KCL coring fluid. POOH. LD BHA. MU Core Barrel. RIH. Ream 56' to 7952'. Attempt to core. No progress. POOH. Made 2'. No recovery. RIH. Core f/7954' to 7956'. Drill f/6391' to 7177'. Short trip 11 stds. Drill to 7952'(Core Point). C & C. Circ. Run leakoff test to 13.5 PPG EMW. Drill f/5060' to 6100'. Short trip 12 stds. Drill to 6224'. Motor stalling. POOH. Change out motor and bit. RIH. Drill to 6391'. Cement second stage w/307 BBL Permafrost E at 12.3 PPG and 10 BBL G at 15.8 PPG. Disp same. Bump plug and shear HOS stage collar closed. Test to 2000 psi. ND Diverter. MU Speed Head. NU BOP's. Test same. MU Steerable BHA. Drill out HOS cementer at 1806'. RIH to 4910'. Test csg to 1500 psi. Drill out float equip and cement to 5050'. Drill 10' new hole to 5060'. Fin POOH. Run 4 arm caliper on EL. Run 9 5/8" casing. Ran 117 jts, 4982', 36 PPF, K-55, Butt csg. Circ and recip. Cement first stage w/205 BBL Permafrost E cmt at 12.3 PPG and 72 BBL G cmt at 15.8 PPG. Bump plug. Land csg. FS at 5029'. FC at 4948'. Open HOS stage collar at 1806'. Circ for second stage cement job. Drill f/4050' to 5050'. C & C. Short trip. C & C. POOH to log. POOH for BHA change. MU Steerable BHA and RIH. Drill f/1982' to 3006'. Run WL survey. Short trip 10 stds. Drill to 4050'. Short trip 10 stds. PU rig f/L-10. Move in and rig up. PU Rig at 2030 hrs, 03-14-91. Take on drilling fluid. NU Diverter. MU 12 1/4" bit and BHA. RIG RECEIVED: 3/14/91 SPUD DATE: 3/15/91 RIG: NABORS 27E DAYS: 21/22 SUB- SURFACE DIRECTIONAL ~ UIDANCE ]-~ ONTINUOUS ~ OOL SURVEY - lsk i Ga Cons ~ncnorag-~ Company CONOCO INC. Well Name MILNE POINT UNIT L-9 .(1750' F. NL., 4764' FEL, SEC 8,T13N,R10E) Field/Location MILNE POINT, NORTH SLOPE, ALASKA Job Reference No. 74477 Loqqed By: BARNARD II Date Computed By: DEES * SCHLUMBERGER , GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA SURVEY DATE: 31-MAR-91 ENGINEER: K.BARNARD METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROJECTED ONTO A TARGET AZIMUTH OF NORTH 20 DEG 18 MIN WEST COMPUTATION DATE: 4-APR-91 PAGE 1 CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 0 O0 100 O0 200 O0 300 O0 400 500 60o 700 800 900 0 O0 100 O0 200 O0 300 O0 oo 400 02 O0 500 O0 oo 600 O0 O0 700 O0 O0 800 01 O0 900 O0 DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K.BARNARD ., INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH 0 0 N 0 0 E 0 12 S 35 20 E 0 14 S 76 10 E 0 13 S 84 44 E 0 14 S 71 46 E 0 16 S 82 38 E 0 22 S 79 3 E 0 21 S 76 3 E 0 15 S 76 38 E 0 11 S 85 50 E FEET FEET FEET FEET DEG 1000 O0 1100 1200 1300 1400 1500 1600 1700 1800 1900 999 99 O0 1099 O0 1199 O0 1300 O0 1399 O0 1499 O0 1599 O0 1699 O0 1800 O0 1899 -56 O0 44 O0 144 O0 244 O0 344 02 444 O0 544 O0 644 O0 744 01 844 O0 97 98 98 97 O0 98 0 11 S 87 8 E 0 5 N 82 23 E 0 4 N 83 8 E 0 6 S 72 33 E 0 4 S 75 1 E 0 4 S 83 50 E 0 3 S 82 5 E 0 6 S 63 58 E 0 11 S 57 14 E 0 7 S 55 22 E 0 O0 -0 39 -0 63 -0 84 -1 07 -1 35 -1 61 -~ 95 -2 29 -2 45 943 99 97 1043 97 97 1143 97 O0 1244 O0 97 1343 98 1443 98 1543 97 1643 O0 1744 98 1843 1 34 O0 2099 O0 2198 O0 2297 O0 2394 O0 2491 O0 2587 O0 2682 O0 2774 O0 2864 57 2043.57 6 48 59 2142.59 8 52 05 2241.05 11 21 78 2338.78 13 38 66 2435.66 15 17 57 2531.57 17 9 06 2626.06 20 46 44 2718.44 24 44 ll 2808.11 27 43 N 8 7 W N 14 13 W N 16 30 W N 18 4 W N 19 29 W N 19 52 W N 20 30 W N 22 7 W N 21 40 W N 21 31 W -2 57 -2 65 -2 67 -2 74 -2 83 -2 88 -2 93 -3 O0 -3 23 -3 45 2000 O0 1999 97 1943.97 2100 220O 2300 24O0 2500 26OO 2700 2800 2900 3000 O0 2951 77 2895.77 29 48 O0 3037 O0 3122 O0 3205 O0 3287 O0 3369 O0 3451 O0 3535 O0 3617 O0 3698 53 2981 53 31 48 03 3066 52 3149 99 3231 67 3313 99 3395 19 3479 52 3561 75 3642 -3 11 5 37 19 23 36 66 57 86 82 55 110 87 143 54 181 71 225 94 274 06 46 89 85 39 17 94 33 06 43 3100 3200 33OO 340O 3500 3600 37O0 3800 390O N 21 40 W N 22 24 W 325 03 32 51 N 21 58 W 378 52 33 53 N 21 14 W 433 99 34 58 N 20 56 W 490 67 35 27 N 20 37 W 548 99 33 34 N 21 41 W 604 19 34 2 N 21 55 W 660 52 35 9 N 21 44 W 717 75 36 12 N 21 21 W 775 DEG/IO0 0.00 0.00 0.12 0.02 0.00 0..01 0.00 0.14 0,23 0.00 0.01 0.00 0.03 0.48 0 O0 0 O0 0 05 0 05 0 04 0 22 7.30 1.65 1.79 1-.43 2.41 3.40 1.29 1.91 4.44 3.09 2 96 1 04 1 11 1 20 0 90 1 O0 1 63 1 02 1 19 0 56 0 O0 N 0 36 S 0 49 S 0 57 S 0 66 S 0 78 S 0 86 S 1 O0 S 1 15 S 1 20 S 0 O0 E 0 17 E 0 47 E 0 88 E 1 32 E 1 78 E 2 32 E 2 92 E 3 50 E 3 83 E 0 O0 N 0 0 E 39 S 25 24 E 68 S 43 41 E 05 S 57 6 E 47 S 63 29 E 94 S 66 12 E 47 S 69 37 E 09 S 71 8 E 68 S 71 50 E 01 S 72 38E 1 21 S 1 22 S 1 20 S 1 21 S 1 25 S 1 27 S 1 28 S 1 32 S 1 47 S 1 61 S 4 13 E 4 34 E 4 46 E 4 62 E 4 76 E 4 87 E 4 97 E 5 08 E 5 33 E 5 59 E 4 30 S 73 37 E 51 S 74 20 E 62 S 74 55 E 78 S 75 21 E 92 S 75 14 E 03 S 75 22 E 13 S 75 33 E 25 S 75 26 E 53 S 74 34 E 82 S 73 58 E 1 23 S 7 09 N 20 48 N 37 15 N 57 25 N 80 50 N 107 07 N 137 50 N 172 91 N 214 05 N 5 64 E 3 0 5 12 20 30 42 56 72 5 77 S 77 40 E 69 E 7 07 W 20 23 W 37 01W 58 31W 83 12 W 111 04 W 143 33 W 181 61W 226 99 N 27 28 E 48 N 0 12 W 52 N 8 1W 50 N 11 51W 02 N 14 10 W 23 N 15 43 W 78 N 17 0 W 85 N 18 3 W 03 N 18 44 W 258.85 N 306.49 N 109 355.97 N 129 407.10 N 150 459.86 N 170 513.90 N 190 566.88 N 211 618.32 N 231 670.99 N 252 725.30 N 274 90 19 W 274 11 N 19 13 W 57 W 325 79 W 378 O0 W 433 31W 490 78 W 548 17 W 604 79 W 660 90 W 717 33 W 775 48 N 19 40 W 89 N 20 2 W 85 N 20 14 W 39 N 20 19 W 17 N 20 22 W 94 N 20 26 W 34 N 20 33 W 07 N 20 39 W 45 N 20 43 W CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA COMPUTATION DATE: 4-APR-91 PAGE 2 DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K,BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUT~ EAST/WES7 DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3780 15 3724.15 34 25 4100 4200 4300 4400 4500 4600 4700 4800 4900 O0 3862 O0 3945 O0 4028 O0 4110 O0 4192 O0 4273 O0 4353 O0 4433 O0 4514 95 3806.95 34 5 62 3889 62 34 20 07 3972 07 34 41 16 4054 16 34 51 06 4136 06 35 19 24 4217 24 36 8 58 42~7 58 36 56 71 4377 71 36 1 92 4458 92 35 47 N 21 9 W 833 48 N 20 45 W 889 N 20 4 W 945 N 19 19 W 1002 N 18 45 W 1059 N 18 13 W 1116 N 17 46 W 1175 N 17 23 W 1234 N 16 29 W 1294 N 15 21W 1352 55 75 42 47 82 15 67 38 51 1 76 0 42 0 60 041 0 56 0 8O 0 92 0 76 2 53 0 75 779 42 N 295 35 W 833.51 N 20 45 W 831 884 937 991 1046 1101 1158 1215 1271 77 N 315 44 N 335 80 N 354 74 N 372 18 N 390 72 N 408 52 N 426 71 N 444 82 N 460 44 W 889 58 N 20 46 W 06 W 945 13 W 1002 75 W 1059 91W 1116 9t W 1175 89 W 1234 42 W 1294 27 W 1352 78 N 20 45 W 44 N 20 41 W 48 N 20 36 W 82 N 20 29 W 15 N 20 22 W 67 N 20 14 W 39 N 20 5 W 55 N 19 54 W 5000 O0 4595 82 4539 82 36 8 5100 5200 5300 5400 5500 5600 5700 5800 5900 O0 4676 O0 4757 O0 4837 O0 4917 O0 4997 O0 5077 O0 5158 O0 5239 O0 5320 59 4620 05 4701 27 4781 20 4861 01 4941 35 5021 58 5102 89 5183 98 5264 59 36 14 05 36 36 27 36 45 20 36 55 01 37 8 35 35 50 58 35 35 89 35 39 98 35 58 N 15 2 W 1411 11 N 15 23 W 1469 84 N 15 24 W 1528 97 N 15 35 W 1588 52 N 15 49 W 1648 35 N 16 16 W 1708 44 N 17 20 W 1767 94 N 18 8 W 1826.08 N 18 38 W 1884.31 N 19 4 W 1942.82 0.32 0.35 0 55 0 54 0 18 0 65 1 42 0 34 0 33 0 43 1328 60 N 475 69 W 1411 19 N 19 42 W 1385 1442 1500 1558 1616 1673 1728 1783 1839 51N 491 73 N 506 33 N 522 12 N 539 03 N 555 12 N 572 54 N 590 84 N 608 23 N 627 11W t469 86 W 1529 79 W 1588 03 W 1648 69 W 1708 82 W 1768 59 ~ 1826 95 W 1884 84 W 1943 97 N 19 31 W 18 N 19 21 W 81 N 19 13 W 72 N 19 5 W 90 N 18 59 W 46 N 18 54 W 65 N 18 52 W 91 N 18 51 W 44 N 18 51 W 6000 O0 5401 89 5345 89 36 0 6100 62O0 6300 64OO 6500 6600 670O 6800 6900 O0 5482 O0 5563 O0 5643 O0 5723 O0 5803 O0 5883 O0 5962 O0 6042 O0 6122 73 5426 33 5507 65 5587 85 5667 89 5747 44 5827 50 5906 59 5986 81 6066 73 36 9 33 36 25 65 36 38 85 36 42 89 37 3 44 37 39 5O 37 28 59 36 32 81 36 45 N 19 31W 2001 52 N 20 2 W 2060 N 20 30 W 2119 N 20 50 W 2179 N 21 0 W 2238 N 21 8 ~ 2298 N 21 17 W 2359 N 21 15 W 2420 N 21 39 W 2480 N 21 55 W 2540 49 61 14 86 84 52 69 54 21 031 0 43 0 34 0 28 0 27 0 43 0 54 2 O0 0 33 0 23 1894 64 N 647 26 W 2002 15 N 18 52 W 1950 2005 2061 2117 2173 2229 2286 2342 2397 16 N 667 61 N 687 31 N 708 09 N 730 08 N 751 64 N 773 68 N 795 39 N 817 82 N 839 16 W 2061 65 W 2120 67 W 2179 O0 W 2239 55 W 2299 50 W 2360 64 W 2421 55 W 2480 68 W 2540 12 N 18 53 W 22 N 18 55 W 72 N 18 58 W 41 N 19 1 W 36 N 19 5 W O0 N 19 8 W 15 N 19 11W 97 N 19 14 W 60 N 19 lB W 7000 O0 6202 99 6146 99 36 30 7100 7200 7300 7400 75OO 7600 7700 7800 7900 O0 6284 O0 6365 O0 6447 O0 6528 O0 6610 O0 6692 O0 6774 O0 6856 O0 6938 09 6228 63 6309 23 6391 83 6472 58 6554 56 6636 47 6718 37 6800 35 6882 O9 35 19 63 35 24 23 35 18 83 35 16 58 34 57 56 34 51 47 34 59 37 34 58 35 35 3 N 22 12 W 2599 91 N 22 20 W 2658 N 22 25 W 2716 N 22 25 W 2774 N 22 47 W 2831 N 23 14 W 2889 N 23 29 W 2946 N 23 42 W 3003 N 23 44 W 3060 N 23 51W 3118 42 24 07 82 33 50 75 99 20 1 .07 0.31 0.06 0.33 0.45 0.46 0.69 0.12 0.38 0.59 2453 18 N 862 11 W 2600.25 N 19 22 W 2507 2560 2614 2667 2720 2773 2825 2878 2930 36 N 884 86 N 906 36 N 928 74 N 950 72 N 973 29 N 995 85 N 1018 33 N 1041 80 N 1064 30 W 2658.73 N 19 26 W 33 W 2716.51 N 19 29 W 38 W 2774.31 N 19 33 W 55 W 2832.03 N 19 37 W 08 W 2889.50 N 19 41 W 73 W 2946.63 N 19 45 W 68 W 3003.85 N 19 49 W 78 W 3061.06 N 19 54 W 85 W 3118.26 N 19 58 W CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA COMPUTATION DATE: 4-APR-91 PAGE 3 DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K,BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DISl. AZIMUT~ DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 8000.00 7019.91 6963.91 35 43 N 24 20 W 3175 92 8100,00 7100.83 7044.83 36 0 N 23 40 W 3234 57 8200.00 7182.14 7126.14 35 4 N 23 46 W 3292 68 8300.00 7264.45 7208.45 34 11 N 23 30 W 3349 33 8400,00 7348,23 7292.21 31 44 N 22 15 W 3403 87 8500.00 7434.23 7378.23 30 29 N 21 35 W 3454 57 8597.00 7517.82 7461.82 30 29 N 21 35 W 3503 77 1.21 2983.56 N 1088 60 W 3175 95 N 20 3 W 0.49 3037.29 N 1112 38 W 3234 58 N 20 7 W 1.41 3090.58 N 1135 83 W 3292 69 N 20 11 W 0.,78 3142.56 N 1158 58 W 3349 33 N 20 14 W 2.40 3192.82 N 1179 95 W 3403 87 N 20 17 W 0.00 3239,93 N 1198 71 W 3454 57 N 20 18 W 0.00 3285.69 N 1216 81 W 3503 77 N 20 19 W CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA COMPUTATION DATE: 4-APR-91 PAGE 4 DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K.BARNARD . INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 8597 0 O0 -56 O0 0 0 N 0 0 E O0 999 99 943 O0 1999 97 1943 O0 2951 77 2895 O0 3780 15 3724 O0 4595 82 4539 O0 5401 89 5345 O0 6202 99 6146 O0 7019 91 6963 O0 7517 82 7461 0 O0 99 0 11 S 87 8 E -2 97 1 34 N 8 7 W -3 77 29 48 N 21 40 W 274 15 34 25 N 21 9 W 833 82 36 8 N 15 2 W 1411 89 36 0 N 19 31 W 2001 99 36 30 N 22 12 W 2599 91 35 43 N 24 20 W 3175 82 30 29 N 21 35 W 3503 0.00 57 0.01 1 11 7.30 1 06 2.96 258 48 1.76 779 11 0.32 1328 52 0.31 1894 91 1.07 2453 92 1.21 2983 77 0.00 3285 21 S 4 23 S 5 85 N 90 42 N 295 60 N 475 64 N 6~7 18 N 862 56 N 1088 69 N 1216 0 O0 N 0 O0 E 0 O0 N 0 0 E 13 E 4 30 S 73 37 E 64 E 5 77 S 77 40 E 19 W 274 11 N 19 13 W 35 W 833 51 N 20 45 ~ 69 W 1411 19 N 19 42 W 26 W 2002 15 N 18 52 W 11 W 2600 25 N 19 22 W 60 W 3175 95 N 20 3 W 81 W 3503 77 N 20 19 ~ COMPUTATION DATE: 4-APR-91 PAGE 5 CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECT}ON SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTh FEET DEG/IO0 FEET FEET FEET DEG 0 O0 55 99 156 O0 255 97 356 02 456 O0 556 O0 656 O0 756 O0 856 O0 0 O0 56 O0 156 O0 256 O0 356 O0 456 O0 556 O0 656 O0 756 O0 856 O0 -56 O0 0 O0 100 O0 2OO O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 21 S 22 23 E 0 12 S 73 47 E 0 15 S 80 42 E 0 17 S 76 21 E 0 17 S 73 7 E 0 19 S 82 7 E 0 21 S 76 53 E 0 22 S 75 13 E 0 tl S 82 3 E 0 O0 -0 20 -0 53 -0 75 -0 96 -1 24 -1 48 -1 80 -2 16 -2 39 0.00 0.54 0.00 0.00 0.37 0.00 0.18 0.01 0.18 0.00 0 O0 N 0 18 S 0 45 S 0 55 S 0 60 S 0 74 S 081 S 0 93 S 1 09 S 1 18 S 0 O0 E 0 OB E 031 E 0 70 E 1 14 E 1 56 E 2 05 E 2 66 E 3 27 E 3 69 E 0 O0 N 0 0 E 0 20 S 25 1 E 0 55 S 34 46 E 0 89 S 52 5 E 1 29 S 62 0 E 1 73 S 64 41 E 2 21 S 68 21 5 2 82 S 7O 38 E 3 45 S 71 36 E 3.'87 S 72 13 E 956.01 956 O0 1056.00 1056 O0 1000 1156.00 1156 O0 1100 1256.01 1256 O0 1200 1356.01 1356 O0 1300 1456.00 1456 O0 1400 1556.03 155600 1500 1656.00 1656 O0 1600 1756.00 1756 O0 1700 1856.02 1856 O0 1800 900 O0 O0 O0 O0 O0 O0 O0 O0 O0 O0 0 10 S 87 10 E 0 6 N 89 45 E 0 4 N 84 24 E 0 6 N 89 58 E 0 5 S 71 11 E 0 4 S 83 33 E 0 4 S 83 38 E 0 4 S 71 53 E 0 12 S 58 5 E 0 10 S 69 0 E -2 52 -2 63 -2 66 -2 70 -2 79 -2 86 -2 91 -2 96 -3 11 -3 36 0 08 0 03 0 O0 0 11 0 O0 011 0 O0 0 O0 0 02 0 25 1 21 S 1 22 S 1 21 S 1 20 S 1 24 S 1 27 S 1 28 S 1 30 S 1 39 S 1 56 S 3 99 E 4 27 E 441 E 4 54 E 471 E 4 82 E 4 93 E 5 02 E 5 20 E 549 E 4.17 S 73 11 E 4.44 S 74 3 E 4.57 S 74 42 E 4.70 S 75 14 E 4.87 S 75 15 E 4,98 S 75 17 E 5.09 S 75 28 E 5. 19 S 75 32 E 5.38 S 75 2 E 5.70 S 74 9 E 1956.00 1956 O0 1900 O0 2056.16 2056 2156.90 2156 2258.22 2256 2360.21 2356 2463.11 2456 2566.99 2556 2672.19 2656 2779.75 2756 2890.85 2856 O0 2000 O0 2100 O0 2200 O0 2300 O0 2400 O0 2500 O0 2600 O0 2700 O0 2800 0 5 S 82 32 E O0 5 40 N 13 22 W O0 8 19 N 16 5 W O0 10 15 N 17 13 W O0 12 19 N 18 37 W O0 14 19 N 19 40 W O0 16 50 N 20 21 W O0 20 5 N 21 52 W O0 23 45 N 21 48 W O0 27 26 N 21 33 W -3 51 0 59 12 83 28 80 4890 73 16 101 23 133 83 173 36 221 70 0 67 4 05 1 60 3 61 3 27 1 44 1 06 3 22 5 54 3 24 1.65 S 2.42 N 14.32 N 29 o 66 N 48.79 N 71.66 N 98.03 N 128.48 N 165. 15 N 210. 10 N 5.66 E 4.84 E 5 1.73 E 14 2 85 W 29 9 07 W 49 17 14 W 73 26 77 W 101 38 40 W 134 53 24 W 173 71 05 W 221 5 89 S 73 42 E 41 N 63 24 E 42 N 6 53 E 79 N 5 30 W 62 N 10 32 W 68 N 13 27 W 62 N 15 16 W 10 N 16 38 w 52 N 17 52 W 79 N 18 41W 3004 88 2956 O0 2900 O0 29 56 3121 3240 3361 3483 3604 3725 3847 3970 4091 78 3056 51 3156 07 3256 22 3356 81 3456 15 3556 21 3656 59 3756 62 3856 O0 3000 O0 3100 O0 3200 O0 33O0 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 N 21 43 W O0 32 1 N 22 22 W 336 O0 33 15 N 21 38 W 400 O0 34 34 N 21 2 W 468 O0 35 30 N 20 37 W 538 O0 33 32 N 21 44 W 607 O0 34 18 N 21 55 W 674 O0 35 43 N 21 34 W 744 O0 35 6 N 21 12 W 816 O0 34 4 N 20 48 W 884 276 48 98 98 19 42 60 44 44 71 85 3 08 1 O0 1 06 1 11 0 58 1 42 1 04 1 19 2 95 0 42 261.09 N 317.14 N 113 376.49 N 138 439.14 N 162 504.77 N 187 569.36 N 212 631.41 N 237 696.46 N 263 763.78 N 289 827.38 N 313 91 09 W 276.53 N 19 14 W 95 W 336.99 N 19 46 W O0 W 400.98 N 20 8 W 37 W 468.19 N 20 17 W 35 W 538.42 N 20 22 W 16 W 607.60 N 20 26 W 06 W 674.45 N 20 35 W 01 W 744.46 N 20 41 W 30 W B16.73 N 20 45 W 77 W 884.88 N 20 46 W COMPUTATION DATE: 4-APR-91 PAGE 6 CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH ' TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4212 60 3956.00 3900 O0 34 23 4334 4455 4578 4703 4827 4950 5074 5198 5323 03 4056.00 4000 90 4156.00 4100 69 4256 O0 4200 03 4356 O0 4300 54 4456 O0 4400 72 4556 O0 4500 50 4656 O0 4600 69 4756 O0 4700 45 4856 O0 4800 O0 34 46 O0 35 2 O0 35 57 O0 36 57 O0 35 38 O0 36 4 O0 36 9 O0 36 35 O0 36 52 N 19 58 W N 19 10 W 1021 N 18 22 W 1091 N 17 51W 1162 N 17 22 W 1236 N 16 2 W 1310 N 15 12 W 1382 N 15 17 W 1454 N 15 24 W 1528 N 15 38 W 1602 952 86 80 45 62 49 4O 13 85 20 53 0 58 0 33 0 61 0 90 0 74 1 42 041 0 56 0 56 0 50 891 12 N 337 49 W 952 89 N 20 45 W 956 1022 1089 1160 1231 1300 1371 1441 1513 11 N 360 07 N 382 77 N 405 26 N 427 13 N 448 50 N 468 O0 N 487 98 N 506 87 N 526 51W 1021 94 W 1091 08 W 1162 43 W 1236 91W 1310 11 w 1382 14 W t454 66 W 1528 58 W 1602 82 N 20 40 W 46 N 20 32 W 62 N 20 23 W 49 N 20 13 W 42 N 20 2 W 18 N 19 48 W 97 N 19 34 W 40 N 19 22 W 83 N 19 11W 5448 61 4956 O0 4900.00 37 2 5573 5696 5819 5943 6066 6190 6315 6440 6565 63 5056 83 5156 86 5256 26 5356 95 5456 88 5556 34 5656 14 5756 46 5856 O0 5000.00 36 15 O0 5100.00 35 35 O0 5200 O0 35 43 O0 5300 O0 35 59 O0 5400 O0 36 8 O0 5500 O0 36 23 O0 5600 O0 36 40 O0 5700 O0 36 49 O0 5800 O0 37 25 N 16 4 W 1677.51 N 16 57 W 1752.42 N 18 6 W 1824.24 N 18 43 W 1895 88 N 19 18 W 1968 22 N 19 48 W 2040 99 N 20 28 W 2114 21 N 20 52 W 2188 29 N 21 2 W 2262 89 N 21 17 W 2338 48 0 57 2 09 0 35 041 0 32 0 44 0 37 0 27 0 35 0 76 1586.24 N 547.06 W 1677,92 N 19 2 W 1658.27 N 568.24 W 1752.93 N 18 55 W 1726.79 N 590,02 W 1824,81 N 18 52 W 1794.80 N 612.66 W 1896,49 N 18 51 W 1863.23 N 636.19 W 1968.85 N 18 51 W 1931.82 N 660,51 W 2041.62 N 18 53 W 2000.55 N 685.77 W 2114.82 N 18 55 W 2069.86 N 711.93 W 2188.87 N 18 59 W 2139.52 N 738.61 W 2263.43 N 19 3 W 2210.04 N 765.87 W 2338.98 N 19 7 W 6691 80 5956.00 5900 O0 37 35 6816 6941 7065 7188 7310 7433 7555 7677 7799 69 6056.00 6000 42 6156.00 6100 52 6256.00 6200 18 6356.00 6300 75 6456.00 6400 29 6556.00 6500 43 6656.00 6600 44 6756.00 6700 55 6856.00 6800 O0 36 35 O0 36 45 O0 35 33 O0 35 24 O0 35 19 O0 35 14 O0 34 56 O0 35 1 O0 34 58 N 21 13 W 2415 69 N 21 41W 2490 N 22 2 W 2564 N 22 19 W 2638 N 22 25 W 2709 N 22 26 W 2780 N 23 0 W 2851 N 23 18 W 2921 N 23 40 W 2990 N 23 44 W 3060 48 98 46 4O 29 O0 O4 81 73 1 67 0 27 0 23 1 29 0 O9 0 42 0 42 0 64 0 29 0 38 2282 02 N 793,84 W 2416.16 N 19 11 W 2351 2420 2488 2554 2620 2685 2749 2813 2878 64 N 821.22 W 2490.90 N 19 15 W 81 N 848,96 W 2565.35 N 19 20 W 89 N 876.72 W 2638 79 N 19 24 W 53 N 903.72 W 2709 68 N 19 29 W 11 N 930.75 W 2780 52 N 19 33 W 42 N 958.02 W 2851 19 N 19 38 W 89 N 985.62 W 2921 19 N 19 43 W 98 N 1013.48 W 2990 92 N t9 48 W 10 N 1041.68 W 3060 81 N 19 54 W 7921.59 6956.00 6900 O0 35 9 8044.59 7056.00 7000 O0 36 5 8168.02 7156.00 7100 O0 35 28 8289.77 7256.00 7200 O0 34 15 8409.15 7356.00 7300 O0 31 32 8525.26 7456.00 7400 O0 30 29 8597.00 7517.82 7461 82 30 29 N 24 2 W 3130 59 N 23 51 W 3201 98 N 23 47 W 3274 25 N 23 32 W 3343 57 N 22 5 W 3408 68 N 21 35 W 3467 38 N 21 35 W 3503 77 0 88 0 64 1 12 0 73 2 64 0 O0 0 O0 2942 15 N 1069.88 W 3130 64 N 19 59 W 3007 40 N 1099.27 W 3202 O0 N 20 5 W 3073 68 N 1128.38 W 3274 26 N 20 10 W 3137 27 N 1156,28 W 3343 57 N 20 14 W 3197 27 N 1181.76 W 3408 68 N 20 17 W 3251 85 N 1203.42 W 3467 38 N 20 18 W 3285 69 N 1216.81 W 3503 77 N 20 19 W CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA MARKER TOP 7" CASING BOTTOM 9 5/8" CASING GCT LAST READING PBTD TD COMPUTATION DATE: 4-APR-91 PAGE 7 DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K.BARNARD INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1750' FNL & 476~' FEL, SEC8 T13N RIOE MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 0.00 0.00 -56.00 0,00 N 0o00 E 5028.00 4618.43 4562.43 1344.56 N 479.97 W 8442.49 7384.58 7328.58 3213.22 N 1188.16 W 8503,00 7436.81 7380.81 3241,34 N 1199.27 W 8597.00 7517.82 7461.82 3285.69 N 1216.81 W CONOCO INC. MILNE POINT UNIT L-9 MILNE POINT NORTH SLOPE, ALASKA COMPUTATION DATE: 4-APR-91 PAGE 8 DATE OF SURVEY: 31-MAR-91 KELLY BUSHING ELEVATION: 56.00 FT ENGINEER: K.BARNARD ************ STRATIGRAPHIC SUMMARY PBTD TD MARKER SURFACE LOCATION = 1750' FNL & 4764' FEL, SEC8 T13N RIOE MEASURED DEPTH TVD RECTANGULAR COORDINATES BELOW KB FROM KB SUB-SEA NORTH/SOUTH EAST/WEST 8503.00 7436.81 7380.81 3241.34 N 1199.27 W 8597.00 7517.82 7461.82 3285.69 N 1216.81 W FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH 8597.00 7517.82 7461.82 HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG 3503.77 N 20 19 W SCHLUMBERGER O ii REC T I ONAL SURV E Y COMPANY CONOCO INC. WELL MILNE POINT UNIT L-9 FIELD MILNE POINT COUNTRY USA RUN ONE DATE LOGGED 31 - MAR - 91 REFERENCE 94499 WELL: MPU L-9 (1¥50' FNL, 4764' FEL. 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N4-~....-.~44-~.- -4-4-4..~.-~..~-4-%-.-.~4-+-~...~-+-++..~-...++~-++-~..+-+-.~-.--.~--+.+--~.--f.+-+.-~---~ ....... ~--+-.~--+-.~-++..f.-~ ...... ~...f..i...f..~.-4.++.4 .... ~...~..4..4.~..~-4..4-4..4-- .4-.4..4-~- -~.4-~4..* ..4-4-.~.-~-~--~--~-~..-...4-4~4..4-~--4...~.-4...~......4..~..4...~..4...~.4...~..4 ....... ~.--~--4---~--4..4.--~--.%.--~ ....... ~.--~-.4-4-~...~....~.-?--.~ ....... f--+--~..-~ ...... +-+'+"~-- ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~-~ ~- 4 : ~ : ~ 4 4-~ .4 4 ~ ~.~ ~-~ ~-.~- 4-.~. ~: ~ 4...L4..4...~ ....... ~.4....L..~ ...... ~...~.4....~ ....... ~...~...~...~ ...... :...~..4...~ ....... ~...~...~....~...~...~....~...~...~ .... 6000 940. PROJECTION ON VERTICAL PLANE 940. - ]BO. SCALEO IN VERTICAL OEPTHS HORIZ SCALE = 1/IO00 IN/FT AOGCC GEOLOGICAL MATERIALS INVENTORY LIST PEIlMIT # ~D - )0 [ WELL NAME ('Y] p~J~ COMPLETION DATE ~ I.~ /,'~ . CO. CONTACT i .... Clmck off or list dal[~ as' i1~' i'~"received.*li'st received date for 407. if not required' Ii'st as Nil ' 40i I:* ~l;'i Iq ~ d.~,,~. :. 9 ',,"to, '¢ .... .. ""--.9'! '"~'! well, tests" ~ .... 1 Core d~scrir'ti°' ~ cored intc~al[ core analysis ~ ~ d~ ditch in~e~als diu,it,a,I data - . ............ '"' ,,,' ...... , ......... ' ..... , s~qa, o'~" 6~ LOG TYPE ' , II. UN INTEFI, V.~I_S SCALE '" NO. (to, the nearest foot) linch/100'1 ~ , I ~ J J .J . * i , ii I , ,,c~ .................. ~ ,o~o, x~q~ ,, 3!C~L,I,L~ ,, C p~-o) .1 , ~~- ~i-7~, .... q, ,¢,~-r, , a, ,,~a,,,~>~,~ ~~~,, -- iiii ii i i ~ ilI i ii i i i I i .... ~, _ . , , ii i i i ,i Ii I I II I .. 171 · .... ,,, L i ii ] i i1 i i i I i111 ill il i , i , i i ...................... $ A M ? L E T. 12051 RIVERA ROAD SANTA F~ SPRINGS,, CA 90670-2289 PT S ~ REQUEST DATE: ORIGINATOR: S. CORP: ~0N~C~ ~K TRANSACTION DATE: SAMPLE DESCRIPTION: CURRENT LOCATION: ADD SHIP ~ ' (circle one) J.O. $ : GEO/ENG: FI A N TRANSFER TO: ATTN (LAB/PERSON) -:~ QTYLBOXES/P~L TS : SHIP TO: T . -, ! C K E T SHIPPING CO. SERVICE TYPE AIR: Rush TRUCK: Express SHIPPING BILL NO.. COST: P! N, :t Day 2nd Day Standard Refrigerated (circle one) DATE: Economy Castiac PREPAID: WEIGHT: COLLECT: WELLs DATE CORE L~ · · I INTERVAL CUT NET FEET · RECOVERY FEET BOX NO, CORE' S I ZE // L/// STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPL]:CATI'ON FOR SUNDRY APPROVALS 1. Type of Request: Abandon Suspend Operation shutdown Re-enter suspended well Alter casing Repair well __ Plugging __ Time extention Stimulate Change approved program X Pull tubing __ Variance __ Perforate __ Other 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Conoco Inc. Development ~ 56' KDB feet 3. Address Exploratory __ 7. Unit or Property name 3201 C Street, Suite 200 Anchorage, AK 99503 Stratigraphic __ Milne Point Unit service x , , 4. Location of well at surface 8. Well number 1752' FNL, 4769' FEL, Sec. 8, T13N, RIOE, Umiat Meridian L-9 At top of productive interval 9. Permit number 1289' FSL, 603' FEL, Sec. 6, T13N, RIOE, Umiat Meridian 90-101 At effective depth 10. APl number 1488' FSL, 688' FEL, Sec. 6, T13N, RIOE, Umiat Meridian 50-029-22075 At total depth 11. Field/Pool 1540' FSL, 708' FEL, Sec. 6, T13N, RIOE, Umiat Meridian Kuparuk River Field 12. Present well condition summary Total depth: measured 861 O' feet Plugs (measured) true vertical 7529' feet Effective depth: measured 8498' feet Junk (measured) true vertical 7433' feet Casing Length Size Cemented Measured depth True vertical depth Structural Conductor 79' 13-3/8" 500 SX Permf C 115' 115' Surface 4993' 9-5/8" 82 bbl Class G 5029' 4619' Intermediate 512 bbl Permf E Production 8561' 7" 97.7 bbl Class G 8597' 7518' Uner Perforation Depth: measured 8107-8128'; 8135-8150'; 8218-8248'; 8263-8276' R E ~ E JV E D true vertica17107-7124'; 71a0-7142'; 7197-7222'; 7234-7244'APR 2 9 Tubing (size, grade, and measured depth) 2-7/8", L-80, 9100' Alaska Oil & Gas Cons. (;0mmis~ Anchorage Packers and SSSV (type and measured depth) Otis FMX SCSSV @ 552'; Otis BWD Pkr. @7986' 13. Attachments Description summary of proposal X Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: May 15, 1991 16. If proposal was verbally approved Oil . Gas __ Suspended X Name of approver Date approved Service 17. I hereby c~rtify tha1 the foregoing is true and correct to the best of my knowledge. Signed{ ~",..,/'~/'~jl/ J.H. Andrew Title Production Engineer Date April 23, 1991 Conditions of approval: Notify Commission so representative may witness IApproval No. Plug integrity __ BOP Test __ Location clearanceI Q/! ' Mechanical Integrity Test ~ Subsequent form required 10---~'0~ :.~,porr~v9d Copy/ ' ~tu(ned ORIGiNaL $!GNED BY Approved by order of the Commission LONN1E C, SMITH Commissioner Date "-~- ~" Form 10-403 Rev 06/15/88 On SUBMIT IN TRIPLICATE MILNE POINT UNIT L-8 AND L-9 FLOWBACK PROPOSAL SUMMARY The Milne Point Unit L-8 and L-9 wells are currently being completed as waterflood injectors. Conoco, as Operator of the Milne Point Unit and in agreement with the Unit Non-operators, proposes and requests approval to place these wells on short-term production prior to placing them in injection service. Reservoir modeling has shown that short term deferral of injection at these two locations will not result in a loss of reserves. Net reserves may actually increase slightly because incremental oil produced in the L-$ or L-9 may not otherwise be completely swept to an offset take-point. None of the producers offset to either the L- $ or L-9 well have shown signs of reservoir depletion in the ±4 months they have been producing. The MPU L-10 well is also being completed as an L-Pad injector. Fluctuating GOR from the offset L-1 well indicates early reservoir pressure support may be needed in that fault block, therefore the L-10 is not being considered for production. Neither the L-8 or L-9 are in communication with the L- 1 fault block. Flowing the wells back has several operational benefits. First, it will allow debris in the completion and wellbore to be cleaned out prior to injection. Second, pressure and production data from these wells will be helpful in optimizing evaluating fracture stimulation treatments. Changes have been made in the later L-Pad completion fracture stimulation treatments which were not available early in the program. Finally, this will allow the wells to contribute to field production while they are awaiting hook-up to injection facilities. Both wells will be placed on injection service if they quit flowing naturally or by December 31, 1991, whichever comes first. There will be no changes to the subsurface equipment, wellhead equipment, or completion program. RECEIVED & Gas Cons. Anchorage SCHLUMBERGER WELL :SERVICES A DIVISION OF SCHLUMBERGER TECHNOI. O~Y CORPORATION HOUSTON. TI:'XA$ 77251-21 ?S I~.~E REPLY TO SCHLUMBERGER WELL SERVICES APR 0 8 1991 Pouch 340069 Prudhoe Bay, AY, 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99.503 Attention: Van Ltneberlier Gentlemen: Enclosed are 2 BLprintsof the. Company CONOCO, Inc. Packer Set Rec, Run 2, 4/03/91 on: ! Well Milne Point Unit L-9 Field Mtlne Point Additional prints ore being sent to: G1.BL nrints ONOCG, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County North Slope State Alaska 1BL prints, I RF Sepia CONOCO, Inc. 1000 South Pine Ponca City, OK 74603 iAttn: Glenn Welch 736ORDW I BL nrints, I RF Sepia OXY U'S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) 1 BL prints, 1 RF Sepia Chevron U.S.A. 11111 South Wllcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) I BL p~ ~A!.as.~Oil & Gas ConserVation 2mmission ~ · 001 Porcupine Drive chora~e.-AK 99501 / ~'~ is returned to CONOCO, Ponca City. We appreciate the privilege of serving you. prints prints prints Received by: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dlckes DISTRICT MANAGER Sws-. 1327-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOL(X~Y CORPOF~ATION HOUSTON. TEXAS 77251-2175 PLEAJE REPLY TO SCHLUMBERGER WELL, ~ERVICE8 APJ~ 0 $ 1§§1 Pouch 3~0069 Prudhoe Bay, AX( 99734-0069 Attn: Bernie/Shelley CONOCO, Inc. 320[ "C" Street, Suite 200 Anchorage., AK 99503 Attention: Van Lineberl~er Gentlemen: Enclosed ore 2 BLprints of the VSP/GCT/CBT/Perforating Record, Run 1, 3/31/91on: Company CONOCO, Inc. , Well Milne Point Unit ..L-9 Field. Mllne Point Additional prints ore being sent to: 1 BL prints CONOCO, Inc. 600 North Dairy Ashford Houston., TX 77079 Attn: Georie Lamb - OF 2018 PER County North Slope State_ Alaska 1BL prints, 1 RE Sepia GONOCO, Inc. 1000 South Pine Ponca City, OK 74603 Att~: Glenn Welch 736ORDW 1BL prints, 1RF Sepia OXY U.S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) I BL prints, I RF Sepia Chevron U.S.A. 11111 South Wilcrest Hosuton, TX 77099 Art. n: Priscilla MacLeroy *(713/561-3652) ~tion Commission / · The film is ,returned to CONOGO, Ponca City. We appreciate the privilege of serving you. prints prints Received by: Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SWS-- 1327-F FILE: COMPANY: WZLL: FIELD: PETRO~EU}{ TESTING SERVICE, AdC. PKS SAMPLING LIST Page [/of DATE: FILE COFfPANY W~LL FIELD PETROI2EU~ TESTING SERVICE, INC. PKS SAMPLING LIST Page DATE: S) fz~? ., ~1), ~Zg~ 77) . ,~~ . 6) ~z~g .... 42) ~z,z3 , 78) ,, 7) $2~ _ 43) gZgg ...... 79) 15 zo) ~zsz, · .... ~6) ~z?9' 82) z~)..~2~c ' ~o)gz~ ,,_ a~) . , , '22 . 29) ~ z&,Z' 55) ~.~$ , , 92) 22) gl&5 , 58). ~:%~/ .... 9~)/ ~30) 26~,~ 27) ~2V ' 63) t30~ , . 99) ,,. I &35). - 32) '~ZTS ~8). ,.. . 1043 . .,.3s~. ~t~ ,_ . .... ~2~ ..... to~) .' ,., b~) .. CONOC0, Inc. 3201 'C" Street, Sulte 200 SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORPORATION HOUSTON. TEXAS 7725 I-2175 UAR 3 0 1991 ~ m~v TO SCHLUMBERGER WELL UlWlCE$ Pouch 340069 ?tudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Anchorase, AK 99503 Attention: Van Lineberser Gentlemen: DITE, NGT, CNL(RAW), CNL(PORO), RFT, £nc[osed ore 2 BLprints of the .... Cyberlook, Run 2, 3/28/91 ompony CONOCO, Inc. /ell Milne Point Unit L-9 :eld Mtlne Point Additional prints ore being sent to: I BL nrints CONOCO, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County North Slope State. Alaska I BL prints, I RF Sepla CONOCO, Inc. 1000 South Pine Ponca City,. OK 74603 Attn: Glenn Welch 736ORDW I BL nrints, 1RF Sepia OXY U:S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) I BL prints, I ~,F Sepia Chevron U.S.A. 11111 South Wllcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-3652) .... '~ S ~ 0~ i~ G ~ 0 ConserVation Commission .3001 Porc,uoine Drive ~ch°ra~e.- ~ 99501 Attn: ~o~n Boyle lhe film i~ returned Ponca We appreciate the privilege of serving you. prints prints prints nCC U Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SWS--132?-F SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMBERGER TECHNOLOGY CORF~RATION HOUSTON. TEXAS 77251-2175 MAR 2 2 1991 CONOCO, Inc. 3201 "C" Street, Suite 200 Anchorage, AK 99503 Attention: Van Lineberser I~.F.A~E REPLY ~0 8CHLUIdBEROER WELL SERVICES Pouch 340069 Prudhoe Bay, AK 99734-0069 Attn: Bernie/Shelley Gentlemen: Enclosed are 2 BLprints of the Company CON0CO, ·Inc. Well M±lne point Unit L-g BGT, Run 1, 3/18/91 Field Milne Point/Kuparuk Additional prints ore being sent to: I BI, nrints CONOCG, Inc. 600 North Dairy Ashford Houston, TX 77079 Attn: George Lamb - OF 2018 PER County,Nor~h.$1ooe State Alaska I BL prints, 1RF Sepia CONOCO, Inc. 1000 Sough Pine Ponca City, OK 74603 Attn: Glenn Welch 736ORDW 1BL mrints, I RF Sepia OXY U[S.A., Inc. 6 Desta Drive Midland, TX 79710 Attn: John Carrol *(915/685-5898) ! BL prints, I RF Sepla Chevron U.S.A, 11111 South Wilcrest Hosuton, TX 77099 Attn: Priscilla MacLeroy *(713/561-36521,,, ,___ 1~ 1 RF Sepia~ /~lask; Oil & Ges Conservation . 3001 POrCupine Drive ~nchorage~ AK 99501 x~ttn: John Bovle ~ The film is returned to CONOCO, Ponca City. We oppreciate the privilege of serving you. prints ~prints prints RECEIVED MAR 2'7 1.q91 .... ~l~ska 0!! & Oas Cor~s_ 6ommissic, n Anchorage Received iby: ,,. f, · ~~ ~, ~j~, · Date: Very truly yours, SCHLUMBERGER WELL SERVICES Raymond N. Dickes DISTRICT MANAGER SW$--I32?-F August 1, 1990 Telacopy~ (907)276-7542 David L. Mountjoy Sr. Drilling Foreman Conoco Inc. 3201 C Street, Suite 200 Anchorage, Alask~ 99503 Re: Mllne Point Unit No. L-9 Conoco Ina. Permit No. 90-101 Sur. Loc. !750'F~tL, 4764'FEL, Sec. 8, T13N, R10E, UM. Btmhole Loc. 3700'FNL, 600'FEL, Sec. 6, T13N, R10E, UM. Dear Mr. MountJ oy: 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. The mechanical integrity of the injection wells must be demonstrated under 20 AAC 25.412 before operation. Please contact the commission at least 24 hours before pressure testing so that a representative of the commission may witness the test. Ver~ trul~0u~p, Co~ts sioner of Alaska Oil mhd Gas Conservation Co~Ission BY ORDER OF THE COMMISSION dlf Enclosure cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ,,... STATE OF ALASKA ALASKA C' AND GAS CONSERVATION CO'-"/IISSION PERMIT TO DRILL 20 AAC 25.005 DrillX% Redrill--I lb. Type of well. Exploratory ~ Development Oil L2 Re-Entry - Deepen la. Type of work Stratigraphic Test~ ~ ServiceXZ Developement Gas - Single Zone 2. Name of Operator CONOCO INC. 3. Address Pouch 340045. Prudhoe Bay, AK 99734 4. Location of well at surface 1750'FNL, 4764'FEL, SEC.8, T13N, R10E At top of productive interval 3960'FNL, 513'R~![, SEC.6, T13N, RIOE At total depth 3700'FNL, 600'~:"-SEC.6, T13N, RIOE 12. Distance to nearest 13. Distance to nearest well property line 3700'FNL feet 60' @ 900 F/L-8 feet 16. To be completed for deviated wells Kickoff depth 2000 18. Casing program size Hole Casing 30 8'5 IR R/R · 9 5/8 ARC'T STA feet Maximum hole angle 36 o Specifications Weight ] Grade I CouplingI Len.gth RAI E 1 I .~E 2 +,16 SI~S PERMA~ROS,T [ 26~ -L-80 l BTRS ~574 19. To be completed for Redrill, Re-entry, and Deepen O! Present well condition summary Total depth: Effective depth: 5. Datum Elevation (DF or KB) KB RR HRI feet 6. Property Designation ADI..-~RRog 7. Unit or property Name M~INE PO!MT UN!T 8. Well number L-9 9. Approximate spud date 3ANUARY 1: ]ggl 14. Number of acres in property 2533 ACRES 10. Field and Pool KUPARUK RIVER F!ELB 11. Type Bond ~soe 20 ^AC 25.025~ BLANKET Number 8086-15-54 Amount $ nn 000 15. Proposed depth IM~ an~ 'rVU~ t60_q' MD7503' Tv_r1* feet 17. Anticipated pressure (see 20 AAC 25.035 Maximum surface _3200 , Setting Depth Top Bottom AND +~0 SK$ ~¢LASS 16 }erations. psig At total depth fTVD) ."~R~r) psi§ ,, Quantity of cement (nclude stage data) I:AA eve nt'nuRr'nne-r : vvv vn,., r br~l'lAI ~.AKA CVC D~DMACDACT il i vv Viler · iiiitl ii 11 .588 $K$ CLASS 310 SKS CLASS G measured trUe vertical measured true vertical feet Plugs (measured) DOI~NSQUEEZE feet -!- 264 SKS PERMAFROST C + 60 BBLS DEAD CRUDE feet Junk (measured) -- feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length Size Cemented Measured depth True Vertical depth PIT SKETCH x 20. Attachments Filing fee X} Property plat ~ BOP Sketch :1~ Diverter Sketch X.; Drilling program X' Drilling fluid program ~ Time vs depth plot ~ Refraction analysis ~ Seabed report ~,-5 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ad/J~J~ ~ Title SR. DRILLTNG FOREMAN ..... /' /'"'Commission Use Only Permit Number I APl number I Approval date J 50-o:z7-2_ o I, 08/0Z/90 Conditions of approval Samples required ~; Yes ~ No Mud log required L~ Yes ~ No Hydrogen sulfide measures ~ Yes ~ No Directi~,survey required ~Yes * No Required working pressure for BOPE ~2M; ~~ .¢~ 5M; ~ 10M; ~ 15M Other' // " ?' ' ' ~ ~~" ~ / ' ') by order of A,,rove,,, comm r , ecomm, s,o. JSee cover letter for other roouirements Form 10-401 Rev. 12-1-85 L._ Submit in triplicate SUPPLEMENTAL DATA SHEET APPLICATION FOR PERMIT TO DRILL CONOCO MILNE POINT UNIT L-9 Conoco Inc. P.O. Box 340045 Prudhoe Bay, AK 99734 I · Casing and Cementing Program A· The 13-3/8" conductor will be set at 80' below the surface then cemented to the surface with ±500 sacks Permafrost type "C". Be The 9-5/8" surface casing will be cemented in 2 stages with the first stage using ±450 sacks of Permafrost "E" cement followed by ±558 sacks of Class "G" cement. A DV tool will be placed at ±1900 MD. The second stage will contain +416 sacks of Permafrost "E" cement followed by ±90 sacks of Class "G" cement. A top job will be done if cement is not circulated to the surface. Ce The 7" production casing will be cemented in two stages. The first stage will consist of ±310 sacks of Class "G" cement pumped around the casing shoe. The secondary cement job will consist of ±264 sacks of Permafrost type "C" cement followed by ±60 barrels of Dead Crude and/or Diesel pumped down the 7" x 9-5/8" annulus. II. Drilling Fluid Program A® Be Co D, 0-500' 9.0 ppg freshwater spud mud. 500'-5030' 9.0 ppg-9.4 ppg freshwater spud mud. 5030'-7500' 9.4 ppg-10.2 ppg dispersed. 7500'-TD 10.2 ppg-10.4 ppg dispersed. III. Drilling Program Conoco Inc. proposes drilling the subject well as an injection well in the Kuparuk River Field. The mud system will be low solids, non-dispersed with a minimum mud weight in surface hole of 9.0 ppg to a maximum of 9.5 ppg. Mud weight at TD will be 10.4 ppg. A 20", 2000 psi diverter will be installed on the 13-3/8" conductor for drilling surface hole. A 13-3/8" 5000 psi RSRRA BOPE stack will be used on the surface casing. Pressure tests will be performed as per State Regulations. Maximum downhole pressure is based on initial reservoir pressure. Maximum surface pressure is based on an unexpanded gas bubble, temperature taken into account. The closest wellbore is L-8 with 60' of closure at 900'. Dead Crude and/or Diesel will be placed in the 7" x 9-5/8" annulus after disposing of excess drilling fluids. The well will be perforated and completed with the drilling rig. The State will be notified for the "MIT" prior to injection. A® Drill a 30" conductor hole to ±80' and set 13-3/8" conductor. Bo Drill a 12-1/4" surface hole to +4625' TVD (5030' MD) and set 9-5/8" casing. Ce Drill an 8-1/2" production hole to +7503' TVD (8609' MD) and set 7" casing. TVD MD FORMATION BIT MUD WT YP PV YIS FL 0' 0' Gravel 1-1-4 9.0 32 20 90 15 500' 500' Sand/Clay 1-1-4 9.0 25 20 65 15 3625' 3786' "K" Sands 1-1-4 9.2 25 15 65 14 3725' 3910' "M" Sands 1-1-4 9.4 25 15 65 13 3975' 4221' "N" Sands 1-1-4 9.4 25 15 65 12 4150' 4439' "O" Sands 1-1-4 9.4 25 15 65 12 6625' 7518' Sea Bee 1-1-4 9.4 8 12 40 10 6850' 7798' Kup Top 1-1-6 10.4 8 12 35 5 7133' 8149' LK1 1-1-6 10.4 8 12 35 5 7503' 8609' TD 1-1-6 10.4 6 12 35 5 * The proposed depth is an estimate only. If the actual depth exceeds the permit depth by over 300' TVD a Sundry Notice will be submitted. T13NRgE ~RON T 13 N R 10 E T 13 N R 11 E MILNE PeIN i ,. '"'~'"'"" ~ co.oco ET ^L CO..O~) ~T AL ...... . -'- ~ o..o,.. ® ~/. \ ® co oco-T^~ ~ To,., ^... ,. u .' "~ . , / ~. !1 ---u,,,t .o..,,.,, I .... CHt~V~Oll CHEVRON ~/'-.~( -- t / \\ I , · . 2;l 24 19 ~Ot' ; .21 22 J : ~) - "'&~) (~ CHEVRON ~ ''T 30 2g :~8 ~:1' 26 · 2S 30 2g ! ' -f- -t- -F -t- I ' 3 3~ =3 ,34 __ ~ Booed on Umfe ' ~ - a~ 30 31 32 I .... o AD4.-25517 ~ X / Mille _2235 AC ~20 AO%ADL-250C~ 25eO AC AOL-25518 2.~0 AC AOL-28231 2555 AC ~ I ........ · III III I I I II I Ii I II + 23 =4 ADL-25514 2560 AC UNIT humbert 35,744 Acre- u :XHIBIT A CHE¥. ARCO IP eOHlO 6/84 UNIT AREA Metldlln.Alaelll I 2 SClIo · --I I I I '~ I ii , II - -- III I ~ - I I NOTE,S: O [ 8~TE PLANE COORDINATES ARE ZONE 4. 2. ALL GEODETIC POSITIONS ARE BASED ON N.A.D, 19:27, OI:I:SET8 1'O SECTION LINE8 ARE COMPUTED BASED ON PROTRACTED VALUES OF THE SECTION CORNER POSTIONS. 6~O' L PAD i °/ iMILN~ PT. VIOINITY MAP LOCATION IN ~EC, 8, T13N, R1OE, UMIAT MERIDIAN , , (.:,~' i~.oar ...... L-6 12056' L-.7 I 18 ~3 'FA/I. i& ?? ' F~/L. / 0 o o'FA/L- ,STATE PLANE COORDINATES-ZONE 4 : w~L-Fi ---¥I - -g-4' i~,o~a~.r" ia~'~o~, "-- g-~ e,o~c~z.e le~,O~' tmc~ .w.'r L~' 420' · / '700 '/='EL. (~ TYPICAL SECTION NO SCALE - GEODETIC POSITION8 NAD 1927 W~I.,,. .c~'r. ,...T,'ru~ I .w-G.'~"r 'L-4 ~" 29'47,782" 1149" a7°56.147° L-5 70* 29'48'O96° I 149* 87'54.651° L-7 70* 29'48.410° 149' AS-BUILT PAD L SECTION 8, TI3N, RIOE, UI~IAT I~ERIDIAN VICINITY MAP : RECEIVED WELL ~ LATITUDE ,: LONGITUDE DEC~61~9 ............ , ................................ ;'" -- I ~ 70° 29' 49" : 149° 38' 0~" ~ 011 & ~as ~. ~mml~;: , ~c~mge I LOCATION IN SECTION ' 1 WELL ~ FROM NORTH LINE : FROM WEST LINE · I ,. 1970' ." ! 58' i ..' .1~o / '3 : ~o,~1 / : ; ,.,;.//? / ,I 3/~/ STATE PLANE COORDINATES WELL j NORTHING$ .I EASTING$ I ~ 6,051, 459. Z .: .. '1 L ~ FIELD BOOK II. eIill ,. ,III 3340,4,cdc Boulevard, Su,'re 201, Anchorage, A/asks ~503 S~LE I" : 200' ]JJOO ~. 84002 CERTIFICATE OF SURVEYOR: , -E'~EeY CERT,r-'Y T-~T, A~ P"OPERLY REGISTERED AND LICENSED TO PRACTICE LAND THIS PLAT REPRESENTS A LOCATION SURVEY ~ .~ ~ o...~. ~ ~.v,~,o., ~o ~ ...""'A".. °~'q~ /I THaT ALL DIMENSIONS AND OTHER DETAILS ~ a' ~~ *.~ ~/! ARE CORRECT. SURVEYED FOR: CONOCO DATE 7-Z4-84 DR~'.VN JTH CONOCO INC,--NABOBS BIG 27E 13-5/8" 58888 BOP SYSTBM Aa 13-5/~ 5~ x lr ~[ AI:'I 11' 51.1 TI're.ed ComecHon Flow Line Annular Preventor Ram R~m Ram Tubing Spool w/ 2"-5000~t Slde Outlets Caslng Spoo! w/ 3"-5000~ Stde Outlets 9-5/8" Suni:ace Castng Choke Line: 3" 5000~ Manual Ga're Valve & 3" HCR VALVE Kill Line: Two 3" 5000~ Hanuat Oate Valves 13-3/8" Conductor Castng 1, BOP STACK SIZE RATINO MEETS API RP53 & SPEC 6A FOR CLASS 5H 2, BOPE TO BE OPERATED EACH TRZP AND TESTED WEEKLY, 3, BOP HYDRAULIC CONTROL SYSTEH TO INCLUDE (5) STATION CONTROL HANIFOLD LOCATED REHOTE WITH 168 GALLON ACCUHULATOR, RESERVOIR UN]T, & AUX]L]AR'f ENERGY SOURCE FOR SYSTEH ACT]VATZON, q-, H]N]HUH ONE SET BLIND RAHS & TWO SETS APPROPRZATE PIPE RAHS, 5, CHOKE & KZLL HAN]FOLDS SHOWN SEPARATELY TO HEET API BP 53 CLASS 5H REQU]REHENTS, .... [ F~CI, I ~ PUqP KILL MANIFOLD FROM REMOTE HIGN ~ ~ ~ REMOTE P~SSU~E G~E SENS~ NOTE: '~~~ HTC~5~LIC CONTROLLED REMOTE OPERATED MAh~P TO I~LU~[ (5) STAT~ CC~TR~ MAklF~ L~:T~D R[V~T[LY ~JTN 3~0 PSI ACCUMULATOR I 5~ S~S. ~DR~ULIC CONTROLLED ROTE OPIATED ~ ~REMOTE PRESSURE GaGE SENSOR 8L~D LINE TO ATMOSPHERIC TO HT MUD/GAS SEPARATOR . , . - CHOKE 8 KILL UANIFOLDS FOR qS/8" 8 7" OD CASING BOP STACK BOP MANIFOLD LAYOUT- CONO , INC. , , - . ' ~ . . ' . . '~_ . ... " , CONOCO, INC. MILNE POINT UNIT DIVER'[ER STACK FOR 13 3/8' CONDUCTOR tO' till, 'SUB S T ~tRT II, lO I~[AD . ·, ,,,;. . . · . I,'e .,, ~h'.',.'./t.: 1. The hydraulic contr`ol syste~ will be in acc. or'dance wi'th ~Pl specifications and ~ r~quir`ements. 2. The HCR valve will open ~hen the prevente~ closes, fl single ' ~0" ~elief line ~ill run off of the d~illing spool HCR valve and ~ill have a ta~-geted do~rnstr`eaa tee fo~ downwind dive~sion. Valves on ~th sides of the t~ .ill h full opening a~ linked to~ethe~ to enable one to alsys be o~n a~ the othe~ to ~ closed. ilUO TIIOUGI4 Id~OCL[&#[~ i~JUPS W&TL~Pq,ndP HC, L[ FlU, T&NII I . I 'S4Jc TK)N VA4. vlr. AX F..LSEN iNDUSTRIES LTD. iDMO~ION. A4JUtY& NABOBS DIAILLL'~ L~/JTE~ TIME ESTIMATE a. Be Co D· E , F· He I · J. Ke Description Rig Up Drill Surface Hole Run Surface Casing and Cement Drill Out and Test Drill Production Hole Log Open Hole Condition, POOH, L.D. Run Production Casing Cement Production Casing Clean Pits, N/D BOP, N/U Tree Move Rig Hours 80 36 101 36 20 16 10 12 24 Cum Days 0.33 3.66 5.16 5.49 9.69 11.19 12.02 12.69 13.11 13.61 14.61 TOTAL 14.61 MILNE POINT~'-']NIT WELL - z.- ? -1 -2 -3 -4 -5 -6 -7 -8 -9 10 11 Rate vs. Depth. m , 0.00 2.00 4.00 6.00 8.00 10.00 12.00 14.00 16.00 18.00 RIG DAYS CONOCO, Ine, Pad L, Nell No, g Pr'o.oeed HI Ine Poln'l: Unl'l:, Nor"l:h Slope, Alaeke 0 _ RI(B ELEV AT ! ON ~ 1000 _ 2000 _ 3000 4000 5000 KOP TVD=2000 TMD=2000 DEP=O 5 I0 15 BU [ LD 2.5 DEO 20 PER I O0 FT 3O 35 EOB TVD=3363 TMD=3460 DEP=449 9 5/8' CS9 PT TVD-4625 TMD=5030 DEP=1383 AVERAGE ANGLE 36 DEl3 30 MI N 60OO 7000 TARGT / LKI TVD=7133 TMD=8149 DEP=3238 LK2 TVD=7153 TMD=8174 DEP-3253 LK3 TVD=7178 TMD=8205 DEP=3272 / 7" LNR TVD=7503 TMD=8609 DEP=3512 8000 0 I I I 1 000 2000 3000 VERT I CAL SF'CT I tin I 4000 HOR ~ 3NTAL SCALE I IN. PROJECTION = 1000 FEET CONOCO. Pad L. Well No' 9 I'111ne Point Unl~, Pno~oeed Nont Slope. Aleeke 4000 3000 2000' 1000 1000 2000 1000 WEST-EAST 0 I TD / 7'" LINER TVD-Z503 THD=8609 DEP=3512 NORTH 3330 WEST 1116 1000 I TD LOCATION' 3700' FNL, 600' FEL SEC- 6, TI3N, RI OE TARGET /.L~t TVD=7133 THD=814g DEP=3238 NORTH 307'0 WEST 1029 TARGET LOCATION' 3960' FNL, 513' FEL SEC. 6, TI3N, RI OE -. SURFACE SURFACE LOCATION, 1750' FNL, 4764' FEL SEC. 8. T13N, RIOE N 18 DEO 32 HI N W 3238' (TO TAROET) 100 0 100 200 300 400 500 600 700 800 900 1400 _ 1500 1600 1700 1800 1900 2000 21 O0 22OO ~ ~ ~°° \ , ~,oo. ,~oo \"°° '~Io ~,~°° /~°° - ~ .~ ,,: zoo ' ~ ~ ~ "~ soo ~ ~oo ' ~ /' . ~,~oo /~,oo '~ ~ ' ' % 500 ~. ~ ~... /'i~oo ,/! oo '~ 1 $00 17'00 ouu / ' \ \ .,,,~oo · ... \ \ ~ ~oo \ ,,,,, , oo \ /, $~00 900 ' .... I I 1 I I ! I / / 700 I I I 2300 J. ! ! 100 0 100 200 300 '400 500 600 700 800 900 _1400 1500 1600 1700 1800 1900 2OOO _ 2100 2200 C~ECK LIST FOR NEW WELL PER,fITS Company ~~~o . Lease & Well No. /~P~ -- (2) Loc ¢,Z~. -8~ 2 r. hru (8) II ~'~ :h~ 13) 10. (lo ~d I3) 12.' 13. (],4 thru 2,2) (2..3 thru 28) (6) or]azR ' (,,9- th rev: 01/30/89 6.011. 14. 15. 16. 17. 18. !9. 20. 21. 22. 23. 24. 25. 26. 27. 28. 2. Is well to' be located in a defined pool ............................. 3. Is well located proper distance from proper=y line .................. 4. is well located proper distance' from other wells ........ ~ ........... 5. Is sufficient undedicated acreage available in this pool ............ 6 Is well to be deviated and is we!Ibore plat included ................ 7 Is operator the only affected par=y ......... i ....................... 8. Can permit be approved before fifteen-day wait ...................... For 2~. 30. 31. 32. Does operator have a bond in force .................................. is a conservation order needed ...................................... ,, Is administrative approval needed ................................... is the lease number appropriate ..................................... Does the well have a unique name and number IS cdnducuor string provided ........................................ Will surface casing protect aL1 zones reasonably exyected to serve as an underground source of drinking water ..................... Is enough cement used to circulate on conductor and surface ......... Will cement tie in surface and intermediate or produc=ion strings ... Will cement cover ~ known productive horizons ..................... Will al! casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an ezisting wellbore ............. Is old wel!bore abandonment procedure included on 10-403 ............ Is adequate weilbore separation proposed ..................... ' ...... Is a diveruer system required ....................................... ~ , Is the drilling fluid program schematic and list of equipment adequate ~,~ Are necessary diagrmm~ and descriptions of diverter and BOPE at=ached. Does BOPE have sufficien~ pressure rating - Test to ~'O~ psig .. Does the choke manifold comply w/API RP-53 (May 84) .................. Is the presence of HzS gas probable ............................. ~... ,,, , explorator7 and Stratigraphic wells: Are da=a presented on potential overpressure zones? ................. Are seismic analysis data presented on shallow gas zones ............ If an offshore loc., are survey results of seabed conditions presented Additional requirements ............................................. ~ Additional R~rks:' ,, , INITIAL GEO. UNIT {ON/OFF POOL CLASS STATUS AREA NO. SNORE ?
