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203-124
RECEIVED STATE OF ALASKA DEC 0 5 2014 ALASKA OIL AND GAS CONSERVATION COMMISSION - WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑Oil ❑Gas ❑SPLUG ❑Other Z Abandoned 0 Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic El GINJ 0 WINJ 0 WAG El WDSPL ❑Other No.of Completions One • ® Development 0 Service ---4, 2. Operator Name: 5. Date Comp., Susp.,or¢band): 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/10/2014 . 203-124 - 314-508 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 8/22/2003 50-029-22247-01-00 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 8/25/2003 PBU 15-28A 207' FNL, 34'FWL, Sec. 22,T11N, R14E, UM • Top of Productive Horizon: 8. KB(ft above MSL): 67' , 15. Field/Pool(s) 335' FSL, 598' FEL, Sec. 09, T11N, R14E, UM GL(ft above MSL): 32.3' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) Oil Pool 141' FSL,653' FWL, Sec. 10,T11N, R14E, UM 10794' - 8727' ' 4b. Location of Well(State Base Plane Coordinates, NAD 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 675940 • y- 5961274. Zone- ASP4 •12267'• 8761' . ADL 028306&028303 TPI: x- 675160 y- 5967079 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 676416 y- 5966915 Zone- ASP4 None 18. Directional Surve Y ❑Yes ® No 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: MWD, GR, ROP, MEMORY CNL, CCL 10693' . 8649' • 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 39' 119' 39' _ 119' 30" 298 cu ft Coldset 9-5/8" 36# J-55 39' 4052' 39' , 3485' 12-1/2" 2235 cu ft AS III, 343 cu ft Class'G' _ I 7" 26# L-80 34' 10306' 34' 8318' 8-1/2" 725 cu ft Class'G' 5" 15# 13Cr80 9993' 10693' 8072' _ 8649' 6" 129 cu ft Class'G' 3-1/2x3-3/16"x2-718" 881#162#16184 L-80 9791' 12267' 7904' 8761' 3-3/4" 90 cu ft Class'G' 24. Open to production or injection? 0 Yes ® No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/TVD) (MD+TVD of Top&Bottom; Perforation Size and Number): 3-1/2", 9.2#x 4-1/2", 12.6#, L-80 9822' 6214'/5105';9504'/7659'; rtk)-if"..�,t • 9777'/7892' I 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. jMif ❑ ®WAS HYDRAULIC FRACTURING USED DURING COMPLETION? Yes No • SCANNED FEB 2 0 2015 i lir f :_" DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED � 7(jik`.- 10794' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No Sidewall Core(s)Acquired? 0 Yes ® No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions,core chips, photographs and laboratory analytical results per 20 AAC 250.071. None Form 10-407 Revised 10/2012 CONTINUED ON REVERSE S1.> z, r3. " Submit Original Only 17�� 2/G/is ,. /4,� - ALEMSL�AI - 9 2010 ✓� 29. GEOLOGIC MARKERS(List all formations ar rkers encounter 30. FORMATION TESTS NAME ,.,J ND Well Tested? L]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. 21TS-Zone 2A 10782' 8719' None Zone 1B 10867' 8761' 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: Title: Drilling Technologist Joe Lastufka 11 ,, Signature: Phone 564-4091 Date: 12-14/I `— INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13. The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26 (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval) Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only 15-28A, Well History (Pre-Rig Sidetrack) Date Summary 11/06/14 PULL B&R FROM 9,503' SLM. ONE ATTEMPT TO PULL GLV FROM 3,793'SLM/3,820'MD. 11/07/14 PULL DCR-GLV FROM ST#3 FROM 3,793'SLM/3,820' MD. SET DGLV IN ST#3 @ 3,793'SLM/3,820' MD. LRS PERFORM PASSING MIT-T(see Irs log). PULL RHC BODY FROM X-NIP. @ @ 9,504'SLM/ 9,537' MD. DRIFTED TBG w/2.70" CENT., 1-3/4"S. BAILER TO 9,920' SLM (no sample). RIH w/10'x 2.25" P. BAILER DOWN TO 10,802' SLM. (recovered two metal bands) DRIFTED TBG w/20'x 2.70" DUMMY WHIPSTOCK, (no success getting to target depth of 10,800'slm). DRFITED TBG w/19'x 2.68" PACKER WHIPSTOCK, (no success getting to target depth of 10,800'slm). RAN 3-1/2" BLB w/2.70" G.RING TO 10,802'SLM/10,832' MD. DRIFTED TBG w/19'x 2.68" PACKER WHIPSTOCK TO 10,790' SLM/ 10,820' MD. RECOVERED PACKER WHIPSTOCK FROM 10,679' SLM. 11/07/14 MIT-T to 3000 psi (PASSED) Pumped 2.45 bbls of 60*crude down TBG to reach test pressure. 1st 15 min TBG lost 55 psi. 2nd 15 min TBG lost 24 psi for a total loss of 79 psi in 30 min, Bled back— 1 bbl. Tags hung. SL in control of well upon departure. IA OA= OTG. FWHPS=0/120/25. Page 1 of 1 North America-ALASKA-BP Page 1 af-a- Operation Summary Report Common Well Name:15-28 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/7/2014 End Date:11/24/2014 X3-015W2-C:(4,574,783.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:6/5/1992 12:00:00AM Rig Release:11/29/2014 Rig Contractor:NORDIC CALISTA UWI:500292224700 Active datum:Kelly Bushing/Rotary Table @67.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/7/2014 18:00 - 18:30 0.50 MOB P PRE WARM UP HYDRAULICS,PREP RIG TO MOVE 18:30 - 19:00 0.50 MOB P PRE PJSM AND BACK OFF WELL -NORDIC TOOLPUSHER,DRILLER, SUPERINTENDENT,AND WSL PRESENT WHILE BACK OFF WELL -BACK OFF WELLAND STAGE TO EDGE OF PAD -PICK UP RIG MATS,PREP RIG TO MOVE 19:00 - 22:00 3.00 MOB P PRE MOVE SATTELITE OFFICE TO DS 15 -MOVE SAT OFFICE AND STAGE ON DS 15 -RIG CONTINUE PREP TO MOVE WHILE WAIT ON SECURITY ESCORT ONCE SAT OFFICE MOVE COMPLETE CLEAN AROUND WELLSITE 22:00 - 00:00 2.00 MOB P PRE PJSM AND MOVE RIG FROM DS 2 TO DS 15 -HOLD PJSM WITH CREWAND SECURITY -DS 2 ACCESS ROAD,WEST DOCK,OXBOW, DS 15 ACCESS ROAD SIMOPS: -CHANGE INJECTOR BLOCKS,BRASS,AND PACKOFFS -CHANGE GOOSENECK ROLLERS 11/8/2014 00:00 - 03:00 3.00 MOB P PRE CONTINUE MOVE RIG FROM DS 2 TO DS 15 DS 2 ACCESS ROAD,WEST DOCK,OXBOW, DS 15 ACCESS ROAD -STAGE OFF EDGE OF PAD WHILE PRE-RIG WORK IS COMPLETED SIMOPS: -CHANGE INJECTOR BLOCKS,BRASS,AND PACKOFFS CHANGE GOOSENECK ROLLERS 03:00 - 06:00 3.00 MOB P PRE CONTINUE WITH RIG MOVE MAINTENANCE CHECKLIST -INSPECT AND CLEAN PITS -INSPECT HIGH PRESSURE SCREENS, SUCTION AND DISCHARGE SCREENS -GREASE CHOKE MANIFOLD AND ALL 2" IRON -GREASE MUD CROSS VALVES SIMOPS: -SLB INSPECT REEL STAND AND REEL PLATES -PREP TO PICK UP 2"REEL 06:00 - 14:00 8.00 MOB P PRE CONTINUE RIG MAINTENANCE. -GUAGE ALL MISMATCHED HAMMER UNIONS IN MUD MANIFOLD. -CONTINUE TO PREP TO PICK UP 2"REEL. -PICK UP AND SECURE 2"REEL IN REEL HOUSE. -MAKE UP INNER REEL IRON. -CONTINUE TO WAIT ON PRE-RIG WORK. SIMOPS: -WSL OPEN WWT WITH PAD OPERATOR -LO/TO WELL 15-27A ON WING VALVE Printed 12/1/2014 11:24:16AM • North America-ALASKA-BP Page 2 cep- Operation Summary Report Common Well Name:15-28 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/7/2014 End Date: 11/24/2014 X3-015W2-C:(4,574,783.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:6/5/1992 12:00:00AM Rig Release:11/29/2014 Rig Contractor.NORDIC CALISTA :UWI:500292224700 Active datum:Kelly Bushing/Rotary Table©67.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 15:30 1.50 MOB P PRE SPOT RIG ON DS 15-28 WELL. -PJSM SET T-MATS AND RIG MATS AROUND WELL. 1-PJSM MOVE RIG ONTO 15-28 WELL. -SET AND LEVEL RIG ON 15-28 WELL. -ACCEPT RIG AT 15:30 ON 11/08/2014. 15:30 - 16:00 0.50 RIGU P PRE BEGIN RIG UP ON 15-28. -SPOT ANCILLARY EQUIPMENT. 1.POSITION AND SET SATELLITE OFFICE. 16:00 - 22:00 6.00 BOPSUR P PRE PJSM NU BOPE. -CYCLE TREE VALVES. -LEAK TIGHT TREE VALVES. -ND TREE CAP. -NU BOPE. SIMOPS:PREP COIL AND INSTALL GRAPPLE TO PULL ACROSS 22.00 - 23.30 1.50 RIGU P PRE PJSM AND RIG UP INJECTOR -PU INJECTOR AND SET ON PACKOFF ASSEMBLY -PU GOOSENECK AND INSTALL ON INJECTOR 23:30 - 00:00 0.50 RIGU P PRE .PJSM AND PULL COIL ACROSS RU NIGHT CAP,SNATCH BLOCK,AND GRAPPLE •-PULL TEST GRAPPLE TO 4K# -PULL COIL ACROSS AND STAB IN INJECTOR -CUT OFF GRAPPLE,STAND BACK INJECTOR OVER BUNGHOLE 11/9/2014 00:00 02:00 2.00 BOPSUR P • PRE 'PJSMAND SHELLTEST BOPE -FILL STICK,PUT ON NIGHT CAP -VERIFY VALVE ALIGNMENT WSL PERFORM PRESSURE CROSSCHECK CHECKLIST WITH NORDIC DRILLER -SHELL TEST TO 250/4500 PSI FOR 5/5 CHARTED MIN SIMOPS: -LOAD KCL INTO PITS '-MEASURE STACK HEIGHTS 02:00 - 02:30 0.50 BOPSUR P PRE PERFORM RIG EVAC DRILL WITH AAR 1-ADD COMPLEXITY WITH SIMULATED MAN DOWN -DISCUSS METHOD OF SHUTTING IN WELL WITH RIG EVAC DUE TO LARGE FIRE Printed 12/1/2014 11:24:16AM North America-ALASKA-BP Page 3i Operation Summary Report Common Well Name:15-28 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/7/2014 End Date:11/24/2014 X3-015W2-C:(4,574,783.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:6/5/1992 12:00:OOAM Rig Release:11/29/2014 Rig Contractor NORDIC CALISTA UW:500292224700 Active datum:Kelly Bushing/Rotary Table @67.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:30 - 07:00 4.50 BOPSUR P PRE PJSM AND TEST BOPE STATE GIVEN NOTIFICATION OF BOPE TEST 11/07/2014 15:45 STATE INSPECTOR JOHNNIE HILL WAIVE WITNESS 11/08/2014 19:30 PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,SUNDRY#203-124,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER -LOWER 2"PIPE RAMS TESTED WITH 2" TEST JOINT -2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -UPPPER 2"PIPE RAMS TESTED WITH 2" TEST JOINT -BLIND RAMS TESTED ON EMPTY HOLE -ANNULAR TESTED WITH BOTH 2"AND 2-3/8" TEST JOINT -TEST FULL OPENING SAFETY VALVE -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS -PERFORM DRAW DOWN TEST OF ACCUMULATOR -ALL TESTS WITNESSED BY TOOLPUSHER AND WSL -UPPER 2"RAMS FAIL-PASS 07:00 - 08:00 1.00 BOPSUR P PRE PJSM AND PRESS TEST INNER REEL VALVE, PACKOFFS,AND INJECTOR LUBRICATOR -PU INJECTOR AND BOOT E-LINE -GET ON WELL,LINE UP TO REVERSE CIRCULATE -PRESS TEST TO 250/3500 PSI FOR 5/5 MIN 08:00 - 14:30 6.50 BOPSUR P PRE PERFORM SLACK MANAGEMENT AND MU CTC. -PUMP E-LINE FORWARD,AND CUT OFF 325'. -LINE UP TO REVERSE AND PUMP E-LINE INTO REEL. -GET OFF WELL,AND CUT 157'OF COIL. FOUND E-LINE EARLY. -GET BACK ON WELL,AND PUMP E-LINE INTO COIL AGAIN. -GET OFF WELLAND CUT AN ADDITIONAL 165'OF COIL. -MU SLB CTC AND PULL AND PRESSURE TEST SAME. -SET INJECTOR IN CIRCULATING HOLE,AND CIRCULATE COIL. Printed 12/1/2014 11:24:16AM • North America-ALASKA-BP Page 4.of-4106 Operation Summary Report Common Well Name:15-28 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/7/2014 End Date:11/24/2014 X3-015W2-C:(4,574,783.00) Project Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:6/5/1992 12:00:00AM Rig Release:11/29/2014 Rig Contractor:NORDIC CALISTA UWI:500292224700 Active datum:Kelly Bushing/Rotary Table©67.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 18:00 3.50 BOPSUR P PRE PJSM AND PRESS TEST BOP LOCKDOWNS -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN ,-LOWER 2"PIPE RAMS TESTED WITH 2" TEST JOINT -2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -UPPPER 2"PIPE RAMS TESTED WITH 2" TEST JOINT I-BLIND RAMS TESTED ON EMPTY HOLE 18:00 - 19:00 1.00 t BOPSUR P PRE PJSM AND TORQUE TREE BOLTS -INSTALL AND PT RISER CAP. -LINE UP AGAINST CLOSED CHOKE AND OPEN WELL. •-FLOW CHECK,NO FLOW. -TORQUE TREE BOLTS. 19:00 - 21:30 2.50 WHIP P WEXIT PJSM AND HEAD UP BHI -PU INJECTOR.MU STINGER AND NOZZLE. PUMP SLACK FORWARD OVER BUNGHOLE. -TESTED NIGHT CAP ON WELL.SHUT IN SWAB AS PER L2RA FOR HOTWORK ON THE RIG FLOOR. -TEST E-LINE CONNECTIVITY,GOOD. -INSTALL BHI UQC WITH FLOATS. -RE-TEST E-LINE CONNECTIVITY,GOOD. • PRESS TEST UQC TO 250/3500 PSI,GOOD. -TEST UQC FLOATS TO 250/3500 PSI,GOOD. 21:30 - 23:00 1.50 WHIP P WEXIT PJSM AND PU WHISTOCK ASSEMBLY -OPEN WELL TO CLOSED CHOKE,NO PRESSURE -REMOVE NIGHT CAP,LINE UP TO TIGER ;TANK PU 3.188"MONOBORE WHIPSTOCK AND SETTING TOOL -PU 2-3/8"COILTRAK -GET ON WELL,PRESS TEST QTS 23:00 - 00:00 1.00 WHIP P WEXIT RIH WITH WHIPSTOCK ASSEMBLY -70'/MIN WITH 0.40/0.67 BPM IN/OUT -TAKE RETURNS OUT TO TIGER TANK -SLOW DOWN TO 10'/MIN THROUGH JEWELRY �-RIH TO 3880'MD 11/10/2014 00:00 - 02:30 2.50 WHIP P WEXIT CONTINUE RIH WITH WHIPSTOCK FROM 3880'MD -70'/MIN WITH 0.40/0.67 BPM IN/OUT -TAKE RETURNS OUT TO TIGER TANK -SLOW DOWN TO 10'/MIN THROUGH JEWELRY -TIE-IN WITH-7.5'CORRECTION -RIH TO 10,810'MD 02:30 - 03:00 0.50 WHIP P WEXIT SET WHIPSTOCK AT 10,790'MD PU TO 10,798.5'MD(TOWS AT 10,790'MD). -ENSURE TOOLFACE AT 45DEG LOHS. -CLOSE EDC.PRESSURE UP TO 3515 PSI. SEE SHEAR. -RIH AND SET DOWN 3K#TO ENSURE SET. 03:00 - 04.30 1.50 WHIP P WEXIT CIRC 2X BU TO SWAP WELL TO CLEAN KCL PU TO 10,780'MD.OPEN EDC. -1.51/1.51 BPM IN/OUT WITH 3050 PSI. I-TAKE RETURNS OUT TO TIGER TANK Printed 12/1/2014 11.24:16AM North America-ALASKA-BP Page 5 0l40" Operation Summary Report Common Well Name:15-28 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/7/2014 End Date:11/24/2014 X3-015W2-C:(4,574,783.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:6/5/1992 12:00:00AM Rig Release:11/29/2014 Rig Contractor NORDIC CALISTA UWI:500292224700 Active datum:Kelly Bushing/Rotary Table @67.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:30 2.00 WHIP P WEXIT POOH WITH WHIPSTOCK SETTING TOOL -FLOW CHECK ABOVE WHIPSTOCK,NO FLOW -80'/MIN WITH 1.07/0.76 BPM IN/OUT -FLOW CHECK AT SURFACE,NO FLOW 06:30 - 08:15 1.75 STWHIP P WEXIT PJSM LD WHIPSTOCK BHA,MU WINDOW MILL BHA. -BREAK AND LD WHIPSTOCK RUNNING TOOLS. -LD MWD TOOLS -PU BTT MOTOR AND MILLS. -GAUGE MILLS;WINDOW:2.74"GO/2.73" NO-GO.STRING:2.74"GO. -MU2XJTSOF2-1/16"CSH. -MU MWD TOOLS. PU INJECTOR,STAB COIL AND GET ON WELL. -TEST QTS 250/3500 PSI. 08:15 - 11:00 2.75 STWHIP P WEXIT RIH W/WINDOW MILL BHA ON 2"COIL AT 80 FPM. -0.66/0.97 BPM IN/OUT. -LOG TIE-IN W/-4.5'CORRECTION. -BEGIN DISPLACING WELL FROM 8.4 PPG KCL TO 9.5 PPG POWERPRO 11:00 - 12:15 1.25 STWHIP P WEXIT FINISH DISPLACING WELL FROM 8.4 PPG KCL TO 9.5 PPG POWERPRO. -1.5/1.5 BPM IN/OUT -GET SLOW PUMP RATES -TAG TOWS AT 10794'PUMPS OFF. 12:15 - 23:00 10.75 STWHIP P WEXIT MILL WINDOW F/10,793.8'-10,799.1'MD CSL_ -FS:3800 PSI MTR WRK:50-200 PSI WOB: -1(V'4 1.0-2.0K# I /iS -BPM IN/OUT:1.40/1.40 PVT:387 BBLS MW IN/OUT:9.55/9.47 PPG -ECD/IA/OA:11.36 PPG/415 PSI/25 PSI -STALL AT 10,795.3'&10,797.4'MD.PU AND RESUME MILLING 0.5 ABOVE THE STALL. 23:00 - 00:00 1.00 STWHIP P WEXIT MILL RATHOLE F/10,799.1'-10,799.9'MD -FS:3800 PSI MTR WRK:100-200 PSI WOB: 1.0-1.5K# BPM IN/OUT:1.40/1.40 PVT:387 BBLS MW IN/OUT:9.55/9.47 PPG ECD/IA/OA:11.36 PPG/430 PSI/27 PSI TIME MILL FIRST 1.5'TO GET STRING REAMER THRU WINDOW -SEE SAND IN SAMPLES 11/11/2014 00:00 - 06:00 6.00 STWHIP P WEXIT CONTINUE MILL RATHOLE F/10,799.9'-10,810' MD -FS:3800 PSI MTR WRK:150-250 PSI WOB: 5.5-2.5K# BPM IN/OUT:1.40/1.40 PVT:387 BBLS MW IN/OUT:9.56/9.46 PPG -ECD/IA/OA:11.36 PPG/430 PSI/27 PSI -TIME MILL FIRST 1.5'TO GET STRING REAMER THRU WINDOW SEE SAND IN SAMPLES -SEE CHERT AND TRACE AMOUNTS OF PYRITE Printed 12/1/2014 11:24:16AM • North America-ALASKA-BP Page 6 000. Operation Summary Report Common Wet Name:15-28 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/7/2014 End Date:11/24/2014 X3-015W2-C:(4,574,783.00) Project:Prudhoe Bay Site:PB DS 15 Rig Name/No.:NORDIC 2 Spud Date/Time:6/5/1992 12:00:00AM Rig Release:11/29/2014 Rig Contractor:NORDIC CALISTA UWI:500292224700 Active datum:Kelly Bushing/Rotary Table(i3167.00usft(above Mean Sea Level) Date From-To Firs Task Code NPT NPT Depth Phase II Description of Operations (hr) (usft) 06:00 - 07:00 1.00 STWHIP P WEXIT DRESS THE WINDOW -BACK REAM WINDOW AT 1'/MIN -REAM WINDOW DOWN AND UP 3X AT 1'/MIN -DRY DRIFT WINDOW, 07:00 09:00 2.00 STWHIP P WEXIT POH W/MILLING BHA AT 100 FPM. -1.71 BPM W/3600 PSI THROUGH OPEN EDC. 09:00 - 10:00 1.00 STWHIP P WEXIT PJSM.LD MILLING BHA. FLOWCHECK WELL -POP OFF INJECTOR. -LD MWD TOOLS AND 2 X JTS 2-1/16"CSH. -PULL MOTOR AND MILLS. -GAUGE MILLS. WINDOW:2.73"NO-GO 10:00 - 12:30 2.50 DRILL P PROD1 PJSM.SLIP AND CUT DRILL LINE. -DISPLACE REEL TO FRESH WATER. 12:30 - 00:00 11.50 DRILL C PROD1 PJSM.CUT 2300'OF COIL TO REDUCE CIRCULATION PRESSURES. -PUMP SLACK OUT OF REEL AND CUT 310' OF E-LINE. -CUT 200'OF COIL. -PUMP SLACK INTO REEL. -CUT AN ADDITIONAL 293'OF COIL. -PUMP SLACK FORWARD. -MU SLB CTC,PULL TO 35K AND PT 250PSI/3500PSI. -HEAD UP BHI. 11/12/2014 00:00 - 01:00 1.00 DRILL C PROD1 CONTINUE TO PRESSURE TES BHI UQC- CHASE A FEW LEAKS. PLACE INJECTOR OVER BUNG HOLE& CIRCULATE FORWARD. 01:00 - 01:15 0.25 DRILL P PROD1 PJSM FOR MU BHA. 01:15 - 01:30 0.25 DRILL P PROD1 FLOW CHECK. 01:30 - 02:00 0.50 DRILL P PROD1 MU BHA#3-BUILD BHA. STAB ONTO WELL. 02:00 - 02:30 0.50 DRILL P PROD1 TEST QTS. 250PIS/4000PSI.PASS. 02:30 - 04:30 2.00 DRILL P PROD1 RIH WITH BUILD BHA. PVT-364 CIRCULATE 1.6BPM THRU EDC 3050PSI CTP. 04:30 - 04:55 0.42 DRILL P PROD1 LOG DOWN FOR TIE-IN FROM 10260',MINUS 6.5. 04:55 - 05:10 0.25 DRILL P PROD1 CONTINUE TO RIH 05:10 - 16:00 10.83 DRILL P PROD1 DRILL 3-1/4"BUILD SECTION F/10812' -NBI 53° -ROP 1-12'/HR -BPM IN/OUT:1.53/1.53 -CIRC PSI:3775 FREE SPIN (100-300PSI MW) -ECD:11.31 PPG(OBD) -MW IN/OUT:9.50 PPG/9.42 PPG -IA/OA/PVT:560 PSI/27 PSI/345 BBLS -DHWOB:1.00K LBS-2.5K LBS -75DEG F IN/66DEG F OUT -DRILL TO 10901' 16:00 - 18:30 2.50 DRILL P PROD1 PJSM. POH W/BUILD BHA. -LAND PILOT HOLE BUILD SECTION AT 10901' MD. -FLOWCHECK WELL. -POH 65FPM 1.92/1.66 BPM IN/OUT -CIRC PRESSURE:3735 PSI(OPEN EDC) Printed 12/1/2014 11:24:16AM FrEE= 4-1/16"GW WELL}E lD= FMC 15-28A, SAFE DIES:WELL ANGLE>70°@ 10862'*** ACTUATOR= BAKERCHROMc 5"LNR***MAX DLS:32.8°@ 10910. Ka ELEV= 67' BF.EI.EV= ? KOP" 1200 2519' -13-1/2"HES X NP,D=2.813" CONDUCTOR, - ? Aix Angle= 96*C 17r _ # Datum M3= NA � GAS LFT MANDRELS Datum ND= 8800'SS D= ST MD IVODEV TYPE VLV LATCH PORT DATE 110 3 3820 3315 43 MMG DMY RK 0 11/07/14 9-5/8`CSG,36#,J-55,O=8.921" 4052' 2 5284 4402 41 MMG DMY RK 0 11/02/14 1 6114 5029 41 MMG DMY RK 0 11/02/14 Minimum ID = 2.372" @ 11029' 3-3/16" X 2-7/8" LNR XO 6183' H3-112"1-ES X NP,D=2.813" 6214' H7'X 3-1/2'HES TNT PKR,D=2.949" 6250' -13-1/2" 3-1/2"HES X NP,D=2.813" 7"CSG CRETACEOUS LEAK(07/01/14) H-6600'-7260' -3 9477' -13-1/2"FES X NP,D=2.813" 9502' -13-1/2"X 4-1/2"xo,ID=2.980" :„I'i ►p, 9504' -17"X 4-1/2'HES TNT PKR D=3.856" 9511' -14-1/2"X 3-1/2"XO,D=2.98" 9537' H3-1/2"HES X NP,D=2.813" 3-1/2"TBG,9.2#,L-80 TC11,.0087 bpf,ID=2.992" - 9723' _____---I 9723' -13-1/2"X 4-1/2"XO,D=2.992" 4-1/2"TBG CUT(09/16/14) --I 9736' 9741' H 7'X 4-1/2"UNDUE MACHINE OVERSHOT ►�� x 9777' -7"X 4-1/2"BKR S-3 PKR,D=3.958' 9791' H3.7"BKR DEPLOY SLV,D=3.00" I rimill 9800' H4-1/2`HES X NP,D=3.813'(BEHIND LNR) 9811' -13-1/2"HOWCO X NP,D=2.813" 3-1/2"LNR,8.81#,L-80 TC11,.0080 bpf,D=2.880" H 9811' 9812' -3-1/2"X 3-3/16"XO,D=2.786' 4-1/2"TBG,126#,L-80 BT-M, .0152 bpf,ID ✓,� 9822' -I4-1/2"WLEG, 3.958` BEHIND=3.958" -{ 9$22' l _ CT LNR 9812' H EMD TT LOGGED 10/13/96 TOP OF 5'LNR I-1 9993' 1-i 9993' -17"X 5"BKR FLEX LOCK HGR/PKR ASSY MILLOUT WNDOW (15-28A) 10693'- 10701' r CSG,26#,L-80 TC4S/BTC,ID=6.276' -I 10306' \ - , TOP OF CEMENT(08/25/03) 10500' y MLLOUT WINDOW (15-28B)10794'-10799' 5"WHIPSTOCK(08/03/03) 10695' ►3i q w/RA TAG @ 10704' P4 4 10794' -WHPSTOCK(11/10/14) �'� H 5"LNR 15#,13CR FL4S,.0188 bpf,D=4.408" 11037' 3-3/16"X 2-7/8' XO, Itr 11029' -,'W�fir f1�t ./'- ID=2.372" PERFORATION SUMMARY `4 REF LOG: SVS MEM CNL/GR ON 08/26/03 PBTD - 12233' ANGLE AT TOP F UT: 93°@ 11320' NE ss-'''-................,..s..........._ aliii, Illiti Note:Refer to Production DB for historical pert data 4484.484844 4.48484' SEE SPF NTBRVAL Opn/Sqz SHOT SQZ 3-3/16"LNR,6.2#,L-80 TCI, - 11029' At 2" 4 11320-11570 0 08/27/03 .0076 bpi',D=2.805" 2" 4 11770- 11930 0 08/27/03 2" 4 12020-1208.0 0 08/27/03 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.372' - 12267' DATE REV BY COtLENTS [ATE REV BY COMMENTS PRUDHOE BAY UNIT 07/04192 0-9 ORIGINAL COMPLETION 11/13/14 SANJMD FINAL ODE APPROVAL WELL: 15-28A 07/22/96 D-14 RWO 11/13/14 TBD'JMO GLV C/O(11/07/14) FERMT No: 2031240 08/27/03 NORDIC 1 CTD SIDETRACK(15-28A) 11/25/14 TR/JMO CORRECTED 7'CSG DEPTH AR No: 50-029-22247-01 11/03/14 D-14 RWO SEC 22,T11 N,R14E 207'FTL 834'FZNL 11/07/14 JMO DRLG HO CORRECTIONS 11/10/14 PJC ADD TREE/VVELLHEAD NFO BP Exploration(Alaska) - ) Image h bject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. c:203 - Lc{ L& Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 o Rescan Needed 1111111111111111111 RESCAN ~olor Items: ¿GreYScale Items: I f9 DIGITAL DATA ~skettes, No. I D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Poor Quality Originals: OVERSIZED (Non-Scannable) D Other: D Logs of various kinds: NOTES: BY: C c-Maria) Date: , I 19-' C' os--- r D Other:: /5/ V\'1? 1111111111111111111 !J t11 Project Proofing BY: ? Maria ) Date: I~q V'~ . /5/ Scanning Preparation BY: f Maria J I x 30 =r '3 () Date: I J- Of Ó '::i + t 2 = TOTAL PAGES l/-7 (Count does not include cover she1tlll",() /5/ V r ' 1111111111111111 Production Scanning Stage 1 Page Count from Scanned File: Lf- ~ (Count does include cover sheet) Page Count Matches Number in Scannir¡g P'eparation: 1/ YES , Maria J Date: /3- q O.C; , , If NO in stage 1, page(s) discrepancies were found: YES NOO Isl ýV ¡' NO BY: Stage 1 BY: Maria Date: /5/ Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Maria Date: /5/ Comments about this file: Quality Checked III I! 11111111111111 10/6/2005 Well History File Cover Page.doc TE OF ALASKA ` ALASKA OIL ANNS CONSERVATION COMMISSION • REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations 0 Stimulate Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ 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 IS Exploratory ❑ . 203 -1240 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ' 50- 029 - 22247 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: . • ADLO- 028303 PBU 15 -28A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12267 feet Plugs (measured) 9791 feet true vertical 8760.96 feet Junk (measured) None feet Effective Depth measured 12233 feet Packer (measured) 9777 9993 feet true vertical 8764.14 feet (true vertical) 7892 8072 feet Casing Length th Size MD TVD Burst Collapse Structural Conductor 79' 20" 91.5# H -40 36 - 115 36 - 115 1490 470 Surface 4057' 9 -5/8" 36# J -55 35 - 4092 35 - 3514 3520 2020 Production 10278' 7" 26# L -80 34 - 10312 34 - 8323 7240 5410 Liner 702' 5" 15# 13CR80 9993 - 10695 8072 - 8651 8290 7250 Liner 21' 3 -1/2" 9.3# L -80 9791 - 9812 7904 - 7921 10160 10530 Liner 1217' 3- 3/16" 6.2# L -80 9812 - 11029 7921 - 8785 Liner 1238' 2 -7/8" 6.16# L -80 11029 - 12267 8785 - 8761 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ — True Vertical depth: - 01:: , - �► at �� 4 t - Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 33 - 9822 33 - 7930 Packers and SSSV (type, measured and true vertical depth) 4 -1/2" Baker S -3 Perm Packer 9777 7892 5" Baker Flex Lock Packer 9993 8072 RECEIVED a 12. Stimulation or cement squeeze summary: i {) t+ :� ') f I' Intervals treated (measured): Atka Oil & Gas CMS. Commission Treatment descriptions including volumes used and final pressure: A mnf 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 MI Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil e 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE] 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: NA Contact Joe Lastufka Printed Nam oe Lastufk Title Petrotechnical Data Technologist Signatu Phone 564 -4091 Date 11/23/2011 Form 10-404 Revised 10/2010 /1.36)./1 Submi ��Only 7BDMS NOV 2 8 Mil ' /i 1 1 15 -28A 203 -124 PERF ATTACHMENT 1 Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 15 -28A 8/26/03 PER 11,320. 11,570. 8,774.59 8,776.71 15 -28A 8/26/03 PER 11,770. 11,930. 8,782.78 8,779.25 15 -28A 8/26/03 PER 12,020. 12,080. 8,778.88 8,774.99 15 -28A 11/1/11 BPS 9,791. 12,080. 7,903.61 8,774.99 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 1 MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE L MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • • 15-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY EFALWifs.asff 11/1/2011;T/I/0=0/200/80 Assist S-Line / Load and MIT T Passed to 3000 psi (secure well) Pump 5 bbls 60/40 meth, 150 bbls crude down tbg. Pump 2.6 bbls crude to pressure tbg up to 3000 psi. TP lost 172 psi 1st 15 min, 55 psi 2nd 15 min. FWHP's=400/250/80 S-Line in control of well at LRS dep. MIT tag hung on wing ;DSO notified. 11/1/2011 ***WELL S/I ON ARRIVAL***(secure well) :RAN 3.80" G-RING & 3-1/2" BRUSH, TAG & BRUSH BKR DEPLOY SLV AT 9,769' SLM. LRS LOADS TBG W/ 150bbls CRUDE. :SET LTTP (3.0" seals) IN DEPLOY SLV AT 9769' SLM/ 9791' MD. LRS MIT-T TO 3000psi (pass) ***WELL S/I ON DEPARTURE, DSO NOTIFIED*** FLUIDS PUMPED BBLS 1 DIESEL 152.6 DEAD CRUDE 5 60/40 METH 158.6 TOTAL TREE = FMC ._,,,,_ WELLHEAD = MCEVOY 15 SA LOWER psi RATE THAN NORMAL CCHECK WITH WIE m .- ACTUATOR = BAKER C KB. ELEV = - 67' mm BF. ELEV = KOP = 7 - ----- - mm 1200' Max Angle = 96 @ 12227' ( 2104' I- I4 -1/2" CAMCO BAL -O SSSV NIP, ID = 3.812" I Datum MD = 10936' Datum TVD _ 8800' SS 19 -5/8" CSG, 36 #, J -55, ID = 8.921" H 4092' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE T Ilia 1 4069 3498 43 CA-KBG-2-LS INT 08/26/03 2 7416 6003 42 CA-KBG-2-LS NT 08/26/03 Minimum ID = 2.372" @ 11048' 3 9709 7834 33 CA- KBG -2 -LS NT 08/26/03 TOP OF 2 -7/8" LINER =1 kit J777' H7" X 4 -1/2" BAKER S -3 PKR, ID = 3.958" III 9791' I- ILTTPw /4 -1/2" G -F,N (11/01/11) 1 !I I 9791' H3.7" BKR DEPLOYMENT SLV, ID = 3.00" I 9800' H 4 -1/2" HES X NIP, ID = 3.813" (BEHIND LNR) 1 3-1/2" LNR (PUP), L -80 ?, ID = 2.88" H 9811' I I, 9811' H3-1/2'' X NIP, ID = 2.813" I 9812' I - 1 3 -1/2" X 3- 3/16" XO, ID = 2.88" 1 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 9822' 9822' H4 -1/2" TBG TAIL WLEG (BEHIND LNR) I I 9812' H ELMD TT LOGGED 10/13/96 (BEHIND LNR) I I TOP OF 5" LNR (BEHIND 3- 3/16" LNR) I 9993' 9993' --I BKR FLEX LOCK PKR (BEHIND 3- 3/16" LNR) I 17" CSG, 26 #, L -80, ID = 6.276" H 10312' r•1 y �, 10500' H I TOP OF CEMENT (08/25/03) 1 44, 1 TOP OF WHIPSTOCK (08/03/03) I- -L10695' ■ r # ∎ MILLOUT WINDOW 10695 ' - 10701' ■ N. I RA TAG H 10704' I IIIE 11029' -13-3/16" X 2 -7/8" XO, ID = 2.88" I 5" LNR, 15 #, 13 -C R, .0188 bpf, ID = 4.408" H 11037' WAWA" 11048' H I TOP OF 2 -7/8" LNR I PERFORATION SUMMARY REF LOG: SWS MEM CNL/GR ON 08/26/03 ANGLE AT TOP PERF: 93 @ 11320' 13- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.805" I 11029' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2" 4 11320 - 11570 0 08/27/03 I PBTD ( 12233' AIL 2" 4 11770 - 11930 0 08/27/03 �y 2" 4 12020 - 12080 0 08/27/03 I2 -7/8" LNR, 6.16 #, L -80, .0058 bpf, ID = 2.372" I-1 12267' DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/04/92 ORIGINAL COMPLETION 11/07/11 BSE/ PJC SET LTTP (11 /01/11) WELL: 15 -28A 07/22/96 LAST WORKOV ER j PERMIT No: ® 2031240 09/02/03 DACITLH CTD SIDETRACK (15 -28A) API No: 50- 029 - 22247 -01 08/16/03 JLA /KK WAIVER SAFETY NOTE SEC 22, T11N, R14E, 607.65 FEL & 4916.93' FNL 11/25/03 /TLH CORRECTIONS l 01/20/04 GRC/TLH CORRECTIONS BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 January 1, 2010 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7t" Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS 15 Dear Mr. Maunder, 3. ~ ~'~" ~ti ~~~~ 7 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS 15 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube. Sincerely, $~~~~~~ J~~ ~ ~~ 2Cl i Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-15 Data' 01/05/10 Well Name PTD # API # Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft na al 15-01 B 2042570 50029206960200- NA Sealed NA 15-028 2060720 50029206970200 NA Sealed NA 15-03 1820300 50029207220000 NA Sealed NA 15-048 2071380 50029207260200 NA Sealed NA 15-05A 1950340 50029207310100 NA Sealed NA 15-06A 1982540 50029207420100 NA 6.7 NA 40.8 11/7!2009 15-07C 2030970 50029211660300 NA 5 NA 34.0 11/10/2009 15-08C 2050050 50029211800300 NA 6.5 NA 45.9 11/28/2009 15-09A 1931380 50029212010100 NA 0.9 NA 5.1 11/11/2009 15-10A 1880850 50029205010100 NA Sealed NA 15-11 B 2041460 50029206530200 NA Sealed NA 15-128 2060870 50029206650200 NA Sealed NA 15-13A 1991240 50029206450100 NA Sealed NA 15-14A 2042220 50029206820100 NA Sealed NA 15-15C 2081820 50029206910300 NA Sealed NA 15-16A 2011920 50029211150100 NA 0.3 NA 3.4 11/7/2009 15-17 1840890 50029211260000 NA 14.7 NA 132.6 12/4/2009 15-18A 2080830 50029222740100 NA 0.4 NA 1.7 11/11/2009 15-19A 1990990 50029218290100 NA surface NA 15-20C 2050930 50029211330300 NA 17 NA 120.7 12/2/2009 15-21A 1990290 50029205030100 NA Sealed NA 15-22 1800970 50029205090000 NA Sealed NA 15-23A 2031110 50029222250100 NA 0.7 NA 3,4 10/7/2009 15-24 1911280 50029222230000 NA 1.3 NA 10.2 10/7/2009 15-258 2080240 50029218420200 NA 0.8 NA 6.8 11/12/2009 15-268 2041590 50029222350200 NA 0.3 NA 1.7 10/8/2009 15-27 1920060 50029222430000 NA 0.3 NA 1.7 10/8/2009 15-28A 2031240 50029222470100 NA 0.5 NA 8.5 11/9/2009 15-296 2090380 50029222590200 NA 0.1 NA 1.7 11/10/2009 15-30A 2020890 50029222820100 NA 0.8 NA 5.1 11/11/2009 15-316 2050860 50029222850200 NA 1.2 NA 3.4 11/11/2009 15-32A 2011840 50029224620100 NA 1.5 NA 10.2 10/7/2009 15-336 2031940 50029224480200 NA 1.6 NA 10.2 11/29/2009 15-34A 2001370 50029224740100 NA 1.4 NA 8.5 11/10/2009 15-35 1940880 50029224880000 . NA 1.8 NA 15.3 11/10/2009 15-368 2060730 50029224800200 NA 1 NA 5.1 11/10/2009 15-378 2040190 50029224850200 NA 1.3 NA 10.2 11/9/2009 15-38A 2030160 50029224960100 NA Sealed NA 15-39A 2060860 50029225030100 NA 0.3 NA 1.7 11 /9/2009 15-40A 1980980 50029225110100 NA 1 NA 5.1 11/9!2009 15-416 2011460 50029224920200 NA 1.2 NA 6.8 11/9/2009 15-428 2090730 50029226240200 NA 1.5 NA 11.9 11/11/2009 15-44 1961100 50029226830000 NA 3.5 NA 30.6 12/17/2009 15-456 2071790 50029226710200 NA 1.7 NA 11.9 11/8/2009 15-46 2041030 50029226650000 NA 1.9 NA 17.0 11 /9/2009 15-47 1951740 50029226170000 NA 1.5 NA 10.2 10/9/2009 15-486 2051660 50029226350200 NA 1.2 NA 10.2 10/8/2009 15-498 2090640 50029226510200 NA 7.3 NA 51.0 11!8/2009 • ~,_ MICROFILMED 03/01/2008 DO NOT PLACE. .~, _., ~.<~~` .y ,__ ~~-_ ., ~" ANY NEW MATERIAL UNDER THIS PAGE F:\La~rFiche\CvrPgs_Inserts\Microfilm Marker.doc 09/27/07 Alaska Data 8 Consulting Services 2525 Gambeil Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~ ~; ~~ r~ov ~ zao~ Wnll -Inh ~t 1 nn Dascrinfine NO.4437 Company: State of Alaska Alaska Qil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Date BL color CD • 15-29A 11686783 SCMT ab - 09/05/07 1 05-25B 11630496 SCMT _ < 08/30/07 1 02-33A 11813082 SCMT 08/31/07 1 15-28A 11686782 SCMT 09/04/07 1 N-27 11824345 SCMT - L 09/12/07 1 OS-22A 11813086 SCMT 09/18107 1 S-400A 11855508 USIT - 09118/07 1 E-27A 11676963 USIT (CEMENT) ~ 09118/07 1 E-27A 11676963 USIT (CORROSION) - 09/18107 1 MPG-07 11594520 USIT S - ' 08/29107 1 MPS-37 NIA SCMT 09/08/07 1 PLtASt At:KNVWLtU(at KtGtll' 1 t3Y SIIiNINCi ANU Kt 1 UKNINta UNt I:VYY tAGr1 1 V: BP Exploration (Alaska) Inc. Petrotechnicai Data Center LR2-1 900 E. Benson Blvd. `""`~ ~ ~~" ~~ `~ '~ I, ~ ", Anchorage, Alaska 99508 is - i- ~ ~: E - Date Delivered: - ,,t ,- ~,~ w. .., Alaska Data & Consulting Serv~ es 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-283 ATTN: Beth -~ Received b 19.i~~~., 's t` ; `.,°~9i1'fliiS~1Ut"4 ~~ ~r ` - ) ) WELL LOG TRANSMITTAL Dó 3~ IPi-- /35/3 February 16,2006 To: State of Alaska Alaska Oil and Gas Conservation COlnm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 RE: MWD Fonnation Evaluation Logs 15-28A, The technical data listed below is being subn1itted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AI( 99518 907-273-3500 15-28A: LAS Data & Digital Log hnages: 50-029- 2224 7 -01 SCANNED WlAH (I ~ ¿GOb 1 CD Rom ~()~\ ',(j) 0:. \W. /7) U , \3 u :J ~1T~uŒ . rmlUJlu.. fb," Æ\ n "ÆI, ~,~ l U LnJLsuuæJ . AI~ASIiA. OIL AlO) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Jennifer Julian Wells Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 3/ IJ.l\ ~O Re: PBU 15-28A Sundry Number: 305-381 . 'If 't' Ii'<'" ,-, . ':þ\,{} k,,1<'~~": "., ....~'""',..,-,> ¡; ~'t Dear Ms. Julian: 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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 me with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, DATED this /.J..aay of December, 2005 Encl. Abandon Alter casing D Change approved program D 2. Operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 1. Type of Request: cP:J./¿.' ..¡ ; · ~¥~1./f~Lj-z!d)" . STATE OF ALASKA ,---n; I ! DEC 1 2 lOÓ5 ALA OIL AND GAS CONSERVATION COMMI S APPLICATION FOR SUNDRY APPROVAL Alaska ü¡¡ & Gas Cons. Commission 20 MC 25.280 Anchorage Operational shutdown Perforate Waiver Other Plug Perforations D Stimulate D Time Extension D Perforate New Pool D Re-enter Suspended Well D 4. Current Well Class: 5. Permit to Drill Number: / Development ~ Exploratory 0 203-1240 /'~ Service 0 6. API Number: 50-029-22247-01-00 /' Suspend Repair well 0 Pull Tubing D Stratigraphic 0 Anchorage, AK 99519-6612 7. KB Elevation (ft): 8. Property Designation: ADL-028303 11. Total Depth MD (ft): 12267 Casing Structural Conductor Surface Production Liner Liner Liner Perforation Depth MD (ft): 11320 - 11570 11770-11930 12020 - 12080 Packers and SSSV Type: 9. Well Name and Number: 15-28A / 67 KB Total Depth TVD (ft): 8760.96 Length 10. Field/Pools(s): Prudhoe Bay Field / Prudhoe Bay Oil Pool PRESENT WELL CONDITION SUMMARY Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): 12233 8764.14 None Junk (measured): None Collapse Size TVD Burst 79 20" 91.5# H-40 4017 9-5/8" 36# J-55 10278 7" 26# L-80 702 5"15# 13CR80 1217 3-3/16" 6.2# L-80 1238 2-7/8" 6.16# L-80 115 3485 8323 8651 8785 8761 1490 3520 7240 8290 470 2020 5410 7250 115 4052 10312 10695 11029 12267 13450 13890 Tubing MD (ft): 33 - 9822 Perforation Depth TVD (ft): 8774.59 - 8776.71 8782.78 - 8779.25 8778.88 - 8774.99 4-1/2" Baker S-3 Packer Tubing Size: 4-1/2" 12.6# Tubing Grade: L-80 Packers and SSSV MD (ft): 9777 / 12. Attachments: DescriDtive Sum m ary of Proposal 0 Detailed Operations Program ~ BOP Sketch 0 14. Estimated Date for Commencing Operations: 16. Verbal Approval: Commission Representative: 13. Well Class after proposed work: Exploratory 0 Development ~ / Service 0 005 15. Well Status after proposed work: Oil ~ Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by Sharmaine Vestal 564-4424 Date: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name Title Contact Jennifer Julian Wells Engineer Signature Phone 564-5663 Date COMMISSION USE ONLY 12/9/2005 Conditions of approval: Notify Commission 50 that a representative may witness Sundry Number: ¿j) 5" 3 ~ I Plug Integrity D Other: BOP Test D ~ Location Clearance D Mechanical Integrity Test RBDMS 8FL DEC 1 4: 2005 APPROVED BY THE COMMISSION Date: /1r,/1 ,/)~ Submit in Duplicate bp To: . . J. Bixbyl D. Cismoski Well Operations Team Leader Date: December 1, 2005 / From: Janet Sack, Wells Engineer Est. Cost: ~ lOR: 250 BOPD Subject: 15-28 OA Cement DownsQueeze PBD15WL28-N Please downsqueeze the OA as described in the following procedure. This procedure . I d th f II . mc u es e 0 oWing steps: Step Type Procedure 1 F Depress OA FL wI AL 2 F OA cement downsqueeze 3 F MIT OA cement downsqueeze after WOC / 15-28 is a trouble producer with a PC leak. The well has had three OA downsqueezes ':.1.- that were within 10 days of each other in 07/03. The third downsqueeze was "7 "- successful with a passing MITOA on 08/01/03. The downsqueeze held until 09/03 when CTD completed a sidetrack on the well. Post ST, the well failed an MITOA on 06/23/04 with a LLR = 2.5 bpm @ 500 psi. This program is designed to pump a 1000' column of cement into the OA to achieve a / passing MITOA. If the well can pass an MITOA, it will be waivered for a PC leak. The procedure includes the following major steps: 1. F 2. DHD 3. DHD 4. F 5. F Depress OA FL wI AL Shoot fluid levels and record WHP's. Bleed the T, lA, and OA to +1- 200 psi and fluid pack with crude as required. OA Downsqueeze MIT OA after waiting on cement. If you have any questions or comments regarding this procedure, please call Jennifer Julian at (W) 564-5663, (H) 274-0929, (Cell) 240-8037. cc: w/a: Well File J. Sack T. Cahalane . . JOB PLANNING DETAILS: > 07/18/03: LLR-OA 2.5 bpm @ 850 psi / > 07/21/03: OA Downsqz > 07/25/03: MITOA Failed 2.0 bpm @ 800 psi > 07/26/03: 2nd OA downsqz > 07/30/03: 3rd OA Downsqueeze - 15 bbls 15.7 ppg Artic set cmt / > 08/01/03: MITOA to 2000 psi - Pass (Post OA dwnsqz test) > 08/01/03: Load IA w/153 bbls 9.8# brine > 08/02/03: LNFT-IA Pass > 08/02/03: MITOA to 3000 psi (over 80% burst) - Pass > 10/08/03: MIT-T to 3500 psi PASS. > 06/23/04: MITOA Failed - 2.5 bpm @ 500 psi > 11/06/04: Waiver canceled - MITOA failed Well has a PC leak. OA= 9-5/8" 36# J-55 IA= 7" 26# L-80 Shoe at 4092' OAxIA Annular Capacity=.0297 bblslft NOTE: Please contact Jennifer Julian post OA FL depress for adjustments to these volumes. Volume to shoe = 122 bbls 1000' of cement = 30 bbls Displacement= 122 -5 (H~O spacer) -30 (cement) - 5 (H20 flush) = 82 bbls ,/ Approximate Fluid Requirements (Downsqueeze Only): Fresh Water: 270 bbls of =80 degree F (includes water for cement mixing and clean up.) 60/40 Methanol: 20 bbls Crude Displacement: 82 bbls at 30-60 degree F Crude: (volume needed to load OA) OS CW101: 10 bbls Arctic Set 1 Cement (15.7 ppg): 30 bbls pumpable (design the pumping time for 3+ hrs.) Note: Adjustments may be made as necessary by supervisor on-site. PREP WORK (pre downsaueeze): DHD/FB: 1. Depress OA FL wI AL per PE Guidelines. 2. Shoot FLs and record WHPs. . . 3. The day prior to the downsqueeze, bleed the OAP to +1- 200 psi. 4. Fluid Pack the OA with crude. CEMENTING OPERATIONS: FB Pumping 5. Hold a pre-job safety meeting on location prior to pumping the job to discuss options to safe out the well house. 6. Rig up cementers to the OA via a flanged 1502 integral union and in-line T valve. 7. If well has IA x OA communication (well has not shown siqns of IAxOA to date), the IA pressure must be maintained at a pressure greater than the OA treating pressure to ensure no cement enters the IA. Tie into the IA with a triplex or pump. 8. Flood lines with warm fresh water and pressure test lines to 3000 psi. 9. Ensure the OA is fluid packed, and pump the following into the OA at maximum / rate up to the maximum pressure of 2000 psi. Note injectivity at pertinent /' times during the displacement. Start pumping into the OA as follows: a. 10 bbls of 60/40 Methanol to establish injectivity b. 10 bbls of OS CW101 surfactant (optional) c. -180 barrels of 800 freshwater to flush OA (approx. 1.5 x annular volume) d. 5 bbls of fresh water spacer e. 30 barrels of 15.7 ppg Arctic Set 1 cement f. 5 bbls of fresh water flush g. 82 bbls of 30-60 degree F crude flush. Deliver cement down the OA at maximum rate of 5 BPM until 72 bbls of displacement has been pumped. Then, cut the rate to 1 BPM for another 5 bbls, then drop the rate to 0.5 BPM for the last 5 bbls. The leading edge of the cement should be 5 bbls short of the shoe when the pumps stop. 10. Shut down pumps and leave the well SI. Please DO NOT try to achieve a SQueeze or to build SQueeze pressure. The intent of this job is to place cement near the OA shoe, not to achieve a squeeze past the shoe. Record final pressures. Rig down and release cementers and pump trucks. Note: Make sure that the valve to the OA gauge has been left open so that OA pressures can be monitored. Do not allow more than 500 psi to build up on the OA. . . 11. Notify the Pad Operator prior to leaving location that the OA may be subject to rapid thermal pressure increases when the well is BOL. Frequent OA monitoring will be necessary for several days following the OA downsqueeze. POST SQUEEZE FULLBORE: 12. M IT -OA to 2500 psi. // Previous OA History: 06/23/04: MITOA Failed - 2.5 bpm @ 500 psi TREE = WELLHEAD = A CTUA TOR = KB. ELEV = BF. ELEV KOP Max Angle = Datum MD = Datum TVD = FMC MCEV OY BAKER C 67' ? 1200' 96 @ 12227' 10936' 8800' SS 15-28A / SA ES: CHROME 5" LINER - GLMs HAVE LOWER psi RATE THAN NORMAL - CHECK WITH WIE. . t:If!7 2104' -14.1/2" CAMCO BAL·O SSSV NIP, 10 = 3,812" I 19-5/8" CSG, 36#, J·55, ID = 8,921" I 13.1/2"LNR(PUP),L-80?,ID=2.88" H 9811' ST MD TVD 1 4069 3498 2 7416 6003 3 9709 7834 GAS LIFT rv1ANDRELS DEV TYPE VL V LATCH 43 CA-KBG-2-LS INT 42 CA·KBG·2·LS INT 33 CA-KBG-2-LS INT PORT DATE 08/26/03 08/26103 08/26/03 Minimum ID = 2.372" @ 11048' TOP OF 2-7/8" LINER 9777' H 7" X 4-1/2" BAKER S-3 PKR, 10 = 3.958" 9791' -137" BKRDEPLOYMENTSLV, ID=300" -14.112" HES X NIP, ID = 3.813" (BEHIND LNR) -13-1/2" X NIP, ID= 2.813" -13.1/2" X 3·3/16" XO, ID = 2,88" I 14.1/2" TBG, 12.6#, L·80, ,0152 bpf, 10 = 3.958" 9822' 9822' 9812' 9993' -14.112" TBG TAIL WLEG (BEHIND LNR) I H ELMD TT LOGGED 10/13/96 (BEHIND LNR) I H BKR FLEX LOCK PKR (BEHIND 3·3/16" LNR) I 1 7" CSG, 26#, L·80, ID = 6.276" I TOP OF 5" LNR (BEHIND 3·3/16" LNR) TOP OF WHIPSTOCK (08/03/03) I MILLOUT WINDOW 10695'· 10701' I RA TAG 10500' -l TOP OF CEMENT (08/25/03) I 15" LNR, 15#, 13-CR, .0188 bpf, ID = 4.408" 11037' 11029' H3'3/16" x 2-7/8" XO, 10 = 288" I 11048' -lTOPOF2.7/8"LNR PERFORA TION SUMrv1A RY REF LOG: SWS MEM CNLlGR ON 08/26/03 ANGLE AT TOP ÆRF: 93 @ 11320' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 4 11320 11570 0 08/27/03 2" 4 11770 . 11930 0 08/27/03 2" 4 12020·12080 0 08/27/03 /3.3/16" LNR, 62#, L-80, .0076 bpf, 10 = 2.805" PBTD I 12.7/8" LNR, 6.16#, L·80, ,0058 bpf, ID 2,372" 12233' 12267' DATE 07/04/92 07/22/96 09/02/03 08/16/03 11/25/03 01/20/04 REV BY COMMENTS ORIGINAL COMPLETION LAST WORKOVER DAC/TL CrD SIDETRACK (15-28A) JLA/KK WAIVER SAFETY NOTE /TLH CORRECTIONS GRC/TLH CORRECTIONS DATE REV BY COMMENTS PRUDHOE BA Y UNrf WELL: 15·28A PERMrf No: 2031240 API No: 50·029-22247-01 SEC 22, T11 N, R14E, 607,65' FEL & 4916.93' FNL BP Exploration (Alaska) :2 ì àtr DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031240 Well Name/No. PRUDHOE BAY UNIT 15-28A Operator BP EXPLORATION (ALASKA) INC >"...¿ ;t;L .~ .-tÖ 0) API No. 50-029-22247-01-00 MD 12267 ~ TVD 8761 /' Completion Date 8/27/2003 ~ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, ROP, MEMORY CNL, CCL (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH/ ~~p Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments ¿ C ~~tJ 12153 LIS Verification 9659 12214 Open 10/10/2003 LDWG edit of 1 pass Memory CNL y Neutron 2 Blu 9659 12214 Open 1 0/1 0/2003 Compensated Neutron Log - Memory GRlCCUCNL _og Casing collar locator 2 Blu 9659 12214 Open 1 0/1 0/2003 Compensated Neutron Log - Memory GRlCCUCNL ~ D Las 12205 Rate of Penetration 10355 12241 Open 10/10/2003 GR, ROP Log Rate of Penetration Blu 10355 12241 Open 1 0/1 0/2003 GR, ROP ED D Pdf Directional Survey 10685 12267 9/24/2003 Rpt Directional Survey 10685 12267 9/24/2003 Log Casing collar locator 5 Blu 10514 12228 Case 3/12/2004 Memory PPROF & IPROF - I Log-Mem ~ GRlCCUSPINfTEMP/PRE S Spinner 5 Blu 10514 12228 Case 3/12/2004 Memory PPROF & IPROF Log-Mem GRlCCUSPINfTEMP/PRE S Log Temperature 5 Blu 10514 12228 Case 3/12/2004 Memory PPROF & IPROF Log-Mem GRlCCUSPINfTEMP/PRE S DATA SUBMITTAL COMPLIANCE REPORT 10/6/2005 Permit to Drill 2031240 Well Name/No. PRUDHOE BAY UNIT 15-28A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-22247-01-00 MD 12267 TVD 8761 Completion Date 8/27/2003 Completion Status 1-01L Current Status 1-01L UIC N ~ Pressure 5 Blu 10514 12228 Case 3/12/2004 Memory PPROF & IPROF Log-Mem GRlCCUSPINrrEMP/PRE ~eo S klS 13049 Neutron 2 Blu 10514 12228 2/3/2005 memory cnl, borax log, mem gr, ccl, cnl Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ~/ ADDITIONAL INFORMATION Well Cored? Y G) Chips Received? - Y / N Daily History Received? ~N ØN Formation Tops Analysis Received? "'YíJ\J Comments: Compliance Reviewed By: ~ Date: ) l)~ J))JJS Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth ;~~""'1 t Well ;~(j -¿""z-01 1;3-12 Y DS 15-28A ;¡f..2.1...'i NK-22A i:í - fer E-35A s.)-. i 2:'!) DS 03-22 ~. Ût.~ C-17A ~. Job # 10662999 10715362 10568415 10715373 10687697 10687693 RST-SIGMA MCNL RST -SIGMA/BORAX MCNL RST-SIGMA USIT ;;Zo 3 '- ( 2- cj NO. 3320 01/31/05 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 02/25/04 1 1 11/22/03 1 1 02126/03 1 1 12/27/03 1 1 07/24/04 1 1 07/05/04 1 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: &/3/0 :3 Alaska Data & Consulting SeNices 2525 Gambell Street, Suite 400 Anchorage, AK 995,0,.3-2_8313 " /1 ATTN: Beth ,.11 f" ReceiVC;::>/O ' l ,~ !tb<t~ Received ~\\~~/~"-C D~\ tè'//ì Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth -~ I Color Blueline Prints CD 1 1 );). LI5 5/ 1 1 1 /). LIST Field: Prudhoe Bay Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 NO. 3087 12/31/03 ,"1E~h~ O~! t~ GäS Cons. Ccmm~ r~.G :~h~~fage ¡. -' ~" ..-t~,,:'\ ~ i ,"" -' f /!IUjf : -,.,,: L~..;· .~~ ~~~\\~~ Date Delivered: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 R. L. f' b. Iv E- - D 900 E. Benson Blvd. ~_ t:Vt-I' Anchorage. Alaska 99508 1 1 1 08/12/03 04/25/03 06/10/03 OS/28/03 09/20/97 C'"."·- ..' -O~i"ü':7 -L 11/22-'~:' ~.I MCNL SCMT SCMT SCMT MWD GR (REPROCESSED) MWD GR MD MWD GR TVD MEM PPROF & IPROF Date Log Description 10558569 10560252 10564482 10559786 40001315 40001315 40001315 10715362 Job# ,--. H-17A \~::I -. , f) 0 K-03A \ q Co{ '" co ~ D.S. 07-32À , q C\ '- 0Œ:"~ D.S. 07-08A lq-~ -~ ~ L-\ Z-03')_ q '1 - "::ë) l Z-03 Z-03 D.S.15-28A ,3-ð3-\@ t.-t Well ..-. Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TIN: Beth Schlumbepgep ) J 803- JeLl WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation COtn1ll. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska October 03, 2003 RE: MWD Fonnation Evaluation Logs 15-28A, AK-MW-2621480 1 LDWG fonnatted Disc with verification listing. J Ô â CD API#: 50-029-22247-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Sign~~J~~ ft""''''' f<\ .~, ,if ~ ...:. ,.....\ic ill""'· (;; I,': # ~'""" Ur¡\ _~=". ~I ·iMr ~. ,v O (' .',- '1.." ¡ 1 0 J". .,/~ [i :r , LI,p,",.,) U!i I' ::);::mmit3~Cm /1,i!C,'ilOft'i!Jü' ~~~\\\~ 09/26/03 Scblumbepgep NO. 2976 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Color Date Blueline Prints CD 06/11/03 /" 1 ;~\~~ 08/26/03 1/ ~ 1 09/16/03 it./' 1 l~/ f5 v 04123/03 1 jõd~ 02103/03 1/ 1 01/04/03 ~/ MPL-01A ~I~-O~YI 23433 CH EDIT MGR (PDC) D.S. 15-28A <- ;3-1 ~ 23431 MCNL K-07C ~ .~ 10560303 RST-SIGMA C-31 B .... 23423 CH EDIT MGR (PDC) D.S. 15-30A - ...rft 23422 CH EDIT MGR (PDC) 3-25A1N-24 ~\ <6 rl- SCMT (REPLACES 3-25A1M-27 PRINTS) . J PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 .....- .'''-';:. .-- ~;... ¡.' Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth _~.:."'" ,'c-:r'"""" Date Delivered: Receivedb~ IJ'I\ "'b\OÖ)--<t-iY"\. .:....:¿::.:<~ -- -' .: .~~-< '.- . . . '7,- ...... ~_~ ~ ~~~(\\~ - STATE OF ALASKA ALAS~ )IL AND GAS CONSERVATION COM )SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: 181 Oil 0 Gas 0 Plugged 0 Abandoned 0 Suspended 0 WAG 20AAC 25.105 20AAC 25.110 o GINJ 0 WINJ 0 WDSPL No. of Completions 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 207' SNL, 34' EWL, SEC. 22, T11 N, R14E, UM Top of Productive Horizon: 335' NSL, 598' WEL, SEC. 09, T11 N, R14E, UM Total Depth: 141' NSL, 654' EWL, SEC. 10, T11N, R14E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: x- 6759~q.__._ y- _ 5961273 ... Zone- ASP4 TPI: x- 675160 y- 5967080 Zone- ASP4 -~-_._.-.._._-'--~.- Total Depth: x- 676416 y- 5966915 Zone- ASP4 18. Directional Survey iii Yes 0 No 21. Logs Run: MWD, GR. ROP, MEMORY CNL, CCL One Other 5. Date Comp., Susp., or Aband. 8/27/2003 6. Date Spudded 8/22/2003 7. Date T. D. Reached 8/25/2003 8. Elevation in feet (indicate KB, OF, etc.) KBE = 67' 9. Plug Back Depth (MD+ TVD) 12233 + 8764 Ft 10. Total Depth (MD+ TVD) 12267 + 8761 Ft 11. Depth where SSSV set (Nipple) 2104' MD 19. Water depth, if offshore NI A MSL 1b. Well Class: 181 Development 0 Exploratory o Stratigraphic 0 Service 12. Permit Number 203-124 13. API Number 50- 029-22247-01-00 14. Well Number PBU 15-28A 15. Field and Pool Prudhoe Bay Field 1 Prudhoe Bay Pool 16. Lease Designation and Serial No. ADL 028303 17. Land Use Permit: 20. Thickness of Permafrost 1900' (Approx.) 22. CASING. . SIZ5 20" 9-5/8" " GRADE H-40 J-55 L-80 FL4S L-80 CASING, LINER AND CEMENTING RECORD ':$'ET"INGDEP;rH·. "RC?L~'i: ;':!',:'i'!I'¡:"": I :,'TOp'.:.'· .···BO'TTOM:· ':'/SIZ~," ':Q~MENT~NGREC9RO Surface 115' 30" 298 cu ft Coldset Surface 4052' 12-1/2" 2235 cu ft AS III, 343 cu ft Class 'G' 34' 10306' 8-1/2" 725 cu ft Class 'G' 10019' 10693' 6" 129 cu ft Class 'G' 9791' 12267' 3-3/4" 90 cu ft Class 'G' Wr .P~R Fr; , 91.5# 36# 26# 15# 8.81# /6.2# /6.16# 7" 5" 23. Perforations open to Production (MD + TVD of Top and Bottom Interval, Size and Number; if none, state "none"): 2" Gun Diameter, 4 spf MD TVD MD TVD 11320' - 11570' 8775' - 8777' 11770' - 11930' 8783' - 8779' 12020' - 12080' 8779' - 8775' 26. Date First Production: September 4,2003 Date of Test Hours Tested PRODUCTION FOR 9/14/2003 6.1 TEST PERIOD -+ Flow Tubing Casing Pressure CALCULATED ....... Press. 914 24-HoUR RATE""'" 2'4:.,¡:!,::';",::':',',:, I 11'\': SIZE 4-1/2", 12.6#, L-80 \, ¡AMOUNT'P0'LLED ·3-1/2" x 3-3/16" x 2-7/8" ¡" TÚalNGREdöRO .. DEPTH SET (MD) 9822' PACKER SET (MD) 9777' 25.' ,ACID,FRÅcmJRE,·· CEMENT SaLJEEzE,'ETC. DEPTH INTERVAL (MD) 2000' PRODUCTION TEST Method of Operation (Flowing, Gas Lift, etc.): Flowing Oll-Bsl 1,101 Oll-Bsl 4,332 GAs-McF 42,635 GAs-McF 167,744 W A TER-BsL -0- WATER-BsL -0- AMOUNT & KIND OF MATERIAL USED Freeze Protect with MeOH CHOKE SIZE 900 GAS-Oil RATIO 38,726 Oil GRAVITy-API (CORR) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach sepa_~ate sheet, if necessary). Submit core chips; if none, state "none".-,;¡:':':, y; 4: . None £4?fj ...;¡Pc·· ORIGINAL CONTINUED ON REVERSE SIDE Co P ~S t6~L Form 10-407 Revised 2/2003 Str 2 ~ '2 (mJJ 21TS GEOLOGIC MARKEF ) NAME MD TVD 10782' 8719' 10867' 8761' 29. )ORMATION TESTS Include and briefly sûmmarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". 28. None Zone 1 B 30. List of Attachments: Summary of Daily Drilling Reports, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed . --< I: ~ Ll IJ. 1.. /J_ TerneHubble-- leAt"-<., ~ Title Technical Assistant Date OQ-;J../i--Q3 PBU 15-28A Well Number 203-124 Permit No. / Approval No. Prepared By Name/Number: Drilling Engineer: Terrie Hubble, 564-4628 Mary Endacott, 564-4388 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-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 elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". ORIGINAL Form 10-407 Revised 2/2003 ') Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/19/2003 8/20/2003 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From- To Hours Task Code NPT Phase 00:00 - 01 :20 1.33 MOB P PRE 01 :20 - 01 :45 0.42 MOB P PRE 01 :45 - 01 :55 0.17 MOB P PRE 01 :55 - 03:30 1.58 MOB P PRE 03:30 - 03:40 0.17 MOB P PRE 03:40 - 04:30 0.83 MOB P PRE 04:30 - 16:30 12.00 MOB N WAIT PRE 16:30 - 17:00 0.50 MOB P PRE 17:00 - 22:30 5.50 MOB P PRE 22:30 - 23:00 0.50 MOB P PRE 23:00 - 23: 15 0.25 MOB P PRE 23: 15 - 00:00 0.75 MOB P PRE 00:00 - 01 :00 1.00 MOB P PRE 01:00-01:15 0.25 MOB P PRE 01:15-03:15 2.00 MOB P PRE 03:15 - 03:30 0.25 MOB P PRE 03:30 - 04:00 0.50 MOB P PRE 04:00 - 06:00 2.00 MOB P PRE 06:00 - 06: 10 0.17 RIGU P PRE 06:10 - 06:30 0.33 RIGU P PRE 06:30 - 08:00 1.50 RIGU P PRE 08:00 - 09:15 1.25 RIGU P PRE 09:15 - 10:00 0.75 RIGU P PRE 10:00 - 10:15 0.25 RIGU P PRE 10:15 -10:35 0.33 RIGU P PRE 10:35 - 12:30 1.92 BOPSURP PRE 12:30 - 15:00 2.50 RIGU P PRE 15:00 - 22:00 7.00 BOPSURP PRE 22:00 - 23:15 1.25 RIGU P PRE Pagè1 of 8 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 Description of Operations Install the bogey wheels in the cellar. Prepare to layover the wind walls. PJSM re: laying over the wind walls. Layover the wind walls. PJSM re laying down the derrick. Lay down the derrick. Wait for X pad access road prep to be completed prior to moving to DS 15. Pre-rig move safety meeting with all rig move personnel. Move rig to OS 15, good rig move, no incidents. Stop rig on first part of pad. Need to raise mast and wind walls to get past Nabors rig. PJSM. Review procedure, hazards and mitigation to raise mast. Raise mast. No incidents. Raise mast. PJSM. Review procedure, hazards and mitigation to raise wind walls and hyd rams. Raise wind walls and hyd rams for mast. PJSM. Review procedure, hazards and mitigation to move rig to front of DS15-28 well. Move rig past Nabors rig 2ES and down pad to front of OS 15-28 well. Remove Bogey wheels and R/U rig BOP's. Safety meeting with Little Red and Veco re loading well with seawater. Pre tour meeting with rig hands. Sim ops with Little Red discussed. Rig hands bring BOP into cellar, rig up control lines, replace stairs and mousehole. Little red continues to kill well. Little Red finished with well kill, pumped 5 bbls methanol spear, 290 bbls 120 def 2% KCL, 6 bbls methanol tail. Well on a vac when they were finished. Rig hands continue with rig up of BOP's. Place secondary containment around wellhead, and install work platform on tree. Note: Well 15-28 is twinned with 15-22. To ensure that we had complete isolation and security, the S riser on 15-28 was removed, and the flowline blind flanged. PJSM prior to moving over well. Move over well with rig. Nipple down tree cap and nipple up BOP stack. Accept rig at 11 :00 AM, 08/20/2003. Pick up Injector out of stabbing box, attach gooseneck, stab pipe. Initial BOP test. Witness waived by Jeff Jones AOGCC. TOT blind rams leaked. C/O twice before getting good low pressure test. M/U CT connecter, Pull test CTC, instert dart, fill coil with 2% KCL water. Dart on seat at 58.9 bbls, Press test inner real Printed: 9/2/2003 10:00:02 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date· 8/20/2003 8/21/2003 ) ') ARGO Operatiions$umrnaryReport Pagfa 2 of8 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 From·..;To Hours Task Code NPT Phase· 22:00 - 23:15 1.25 RIGU P PRE 23:15-23:30 0.25 ZONISO P WEXIT 23:30 - 00:00 0.50 ZONISO P WEXIT 00:00 - 01 :30 1.50 ZONISO P WEXIT 01 :30 - 01:45 0.25 ZONISO P WEXIT 01:45-02:15 0.50 ZONISO P WEXIT 02: 15 - 02:45 0.50 ZONISO P WEXIT 02:45 - 03:35 Description of Operations 0.83 ZONISO P valve and CTC. M/U Cementing Nozzle BHA. Length = 7.5 ft. RIH with Cementing nozzle BHA to lay cement plug and isolate perforations. RIH with Cementing nozzle BHA. Tag BKR whipstock at 10,703', correct -8 ft to 10,695'. Pick up 10 ft and flag CT. SAFETY MEETING. Review procedure, hazards and mitigation to pump cement plug with SWS cementers. Mix chemicals for cement. Press test cement line. Stg 5 bbl water. Stg 21 bbl. 15.8 PPG, G cement. 2.6 bpm, 2000 psi, Stg 10 bbl water. Displace with 30 bbls, 1.5 PPB Biozan water. 2.6 bpm, 1000 psi. 95 % returns. Slow rate to 1.5 bpm at 33 bbl displacement. Close choke. 700 psi WHP at 1.0 bpm. WEXIT Sqz cement to perfs at 1.0 bpm, 900 psi, POH at 9 fpm. Sqz press of 1200 psi at 46 bbls displacement, 4 bbls out perfs. Open choke and lay in cement 1 for 1 at 1.0 bpm, 600 psi, Pull CT at 52 fpm. CMT fully out nozzle at 58.9 bbls displacement, CT depth = 9920'. Pull to safety at 9700'. Sqz cement to 1400 psi WHP, Holding OK, Hold Sqz Press for 30 min. RIH and clean out cement to 10' above liner top with 1.5 PPB Biozan. 2.6 bpm, 1600 psi, Clean out to 10685'. POH while circ at 2.7 bpm, jet across top of liner, GLM's and SSSV Tag up, PU injector, remove cementing BHA, attach swizzle stick nozzle, MU injector, jet stack of cement residue. Stand back injector. 03:35 - 04:10 0.58 ZONISO P WEXIT 04:10 - 06:00 1.83 ZONISO P WEXIT 06:00 - 07: 15 1.25 ZONISO P WEXIT 07:15 - 07:50 07:50 - 09:40 09:40 - 10:00 10:00 - 15:30 15:30 -16:15 0.58 STWHIP P 1.83 STWHIP P WEXIT MU window milling BHA. (BHA #2) WEXIT RIH with BHA #2. First window milling BHA. IAP=O, OAP=O, Pit vol=301 bbls WEXIT 10580', Make -8' correction to be consistent with depth shift from last run in the hole. Weight check up = 49 klbs. Free spin = 1370 psi at 2.5 bpm. Tag up at 10686'. Mill cement @ 40 fph. Tag top of the whipstock, re set depth. Pickup weights are high and slack off weights are very low. May be due to crome liner and bring in the hole. WEXIT Begin window milling at 10695'. 0.33 STWHIP P 5.50 STWHIP P 0.75 STWHIP P Depth Time Motor Work WOB 10695' 9:58 100 psi 100 Ibs 10696' 11:03 212 psi 3500lbs 10697' 12:05 289 psi 4095 Ibs 10698' 13:04 346 psi 4400lbs 10699' 14:07 405 psi 4330lbs 10700' 15:02 402 psi 4504 Ibs WEXIT 10700.5', Drilling break. Getting drilloffs now. Probably exited the window. Drill 1 0' of rathole. Pump 30 bbl 2# biozan sweep. Printed: 9/2/2003 10:00:02 AM ) ) ARCO Ope~åti:()n$Su.rtnna.-yRepórt · Page ~. of8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 Date From - To Hours Task Code NPT Phase Description of Operations 8/21/2003 16:15 - 16:45 0.50 STWHIP N WAIT WEXIT 10701.5', Schlumberger computer crashed. PU above window and work on computer. 16:45 - 18:10 1.42 STWHIP P WEXIT Running thru the window, getting stalls at bottom of window at 10701.0', ream tight area. Continue with drilling rathole. Window depths are 10695.0'-10701.0' These depths may be adjusted after tieing in the RA tag to the BHC sonic tie in log. 18:10 - 20:30 2.33 STWHIP P WEXIT 10711', Rathole finished. Backream window and swap to mud. Clean window. Ream up and down 3 times while swap to FloPro. Stop pump and RIH to TO of 10,711' clean. 20:30 - 22:30 2.00 STWHIP P WEXIT POH while continue to circ FloPro around. 22:30 - 23:00 0.50 STWHIP P WEXIT LlO Milling BHA. Mill = 3.80" gauge, String reamer = 3.79" gauge. 23:00 - 23: 15 0.25 DRILL P PROD1 SAFETY MEETING. Held Pre-Spud Meeting with all personnel. Reviewed well plan and HSE concerns. Had PJSM for BHA M/U. 23:15 - 00:00 0.75 DRILL P PROD1 M/U BHA #3. MWD BHA with 2.29 deg motor and HYC Bi-Center 3-3/4" x 4-1/2" PDC Bit #2. M/U new SWS CTC. 8/22/2003 00:00 - 00:30 0.50 DRILL P PROD1 M/U SWS CTC. Pull test and press test. 00:30 - 02:45 2.25 DRILL P PROD1 RIH with Sperry MWD BHA #3, 2.29 deg motor, HYC Bi-center bit #2. Shallow test OK. RIH. 02:45 - 03: 15 0.50 DRILL P PROD1 Orient TF to high side, went thru window with no wt loss. Tag TO at 10,712'. Correct-1 ftt010,711'. 03:15 - 04:30 1.25 DRILL P PROD1 Drilling Build Section. 2.5/2.5 bpm, 3500/3900 psi, 10R, 30 fph, Drilled to 10730'. 04:30 - 06:00 1.50 DRILL P PROD1 Drilling Build Section. 2.5/2.5 bpm, 3500/3900 psi, 10R, 30 fph, Drilled to 10760'. 06:00 - 07:40 1.67 DRILL P PROD1 Continue drilling ahead. 2.5/2.5/3560 free spin. Drilling at 3810 psi. Pit vol=317 bbls. IAP=OAP=O. ROP slow at 30-40 fph. Sperry tool keeps shutting off. 07:40 - 07:45 0.08 DRILL P PROD1 10794', MWD pulser keeps shutting off. Try a higher pump rates, and can't seem to get it to work. 07:45 - 09:25 1.67 DRILL N DFAL PROD1 10794', POH for Sperry pulser. It keeps shutting off. Also, RPMs were also higher than expected. They were getting 3800 RPM instead of 2600 RPM expected. Can't drive. 09:25 - 10:30 1.08 DRILL N DFAL PROD1 Tag up at surface. Stand back injector. Change out MWD probe. Check motor. It was tight and appeared in good shape. Check bit. It was graded 1,2 and was rerun. 10:30 - 12:15 1.75 DRILL N DFAL PROD1 RIH with BHA #4, Second build section BHA. Shallow hole test of MWD ok at 500'. 12:15 - 12:30 0.25 DRILL P PROD1 Tag bottom, set depth to last tag of 10794' (Made -6' correction). Orient to 1 OR. 12:30 - 14:55 2.42 DRILL P PROD1 Resume drilling. Free spin=3030 psi at 2.5 bpm. Drilling at 2.4/2.4/3770 psi. Pit level=312 bbls. IAP=OAP=O. 14:55 -15:00 0.08 DRILL P PROD1 10914', Take 1 click. 15:00 - 15:50 0.83 DRILL P PROD1 Resume drilling. 15:50 - 16:20 0.50 DRILL P PROD1 10980', wiper trip to window. 16:20 - 16:40 0.33 DRILL P PROD1 Orient 16:40 - 17:10 0.50 DRILL P PROD1 Drill 17:10 - 18:20 1.17 DRILL P PROD1 11017', Orient to high side. Unable to get clicks on bottom, pulled up to window to orient. RIH. 18:20 - 18:40 0.33 DRILL P PROD1 Drilled to 11037'. Need to orient again. 18:40 -19:15 0.58 DRILL P PROD1 Orient TF. Pull to window to get clicks. RIH. Printed: 9/2/2003 10:00:02 AM ) ) Page4 of 8 Legal Well Name: 15-28 Common Well Name: 15-28 Spud Date: 6/5/1992 Event Name: REENTER+COMPLETE Start: 8/20/2003 End: 8/27/2003 Contractor Name: NORDIC CALISTA Rig Release: 8/27/2003 Rig Name: NORDIC 1 Rig Number: N1 Date From- To . Hours Task Code NPT Phase Description of Operations 8/22/2003 19:15 - 19:50 0.58 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3500 I 3900 psi, 90R, Drilled to 11,080'. 19:50 - 21:45 1.92 DRILL P PROD1 POH for lateral BHA. 21:45 - 22:00 0.25 DRILL P PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for BHA C/O. 22:00 - 22:30 0.50 DRILL P PROD1 Adjust motor to 1.37 deg bend, M/U Bit #3, used DS49 PDC bit. Check MWD impeller. 22:30 - 00:00 1.50 DRILL P PROD1 RIH with MWD BHA #4, 1.37 deg motor and 3.75" DS49 bit. Shallow test tools. RIH. 8/23/2003 00:00 - 00:45 0.75 DRILL P PROD1 RIH with lateral MWD BHA #4. 1.37 deg motor and DS49 bit. 00:45 - 01 :45 1.00 DRILL P PROD1 Log tie-in inside liner at 10390' for Geo. [-8 ft CTD], Log across RA tag at 10703' to confirm tie-in. 01:45 - 02:10 0.42 DRILL P PROD1 RIH to TO. Clean hole. 02:10-04:10 2.00 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3500 I 3900 psi, 10R, 70 fph, 90 deg incl, Drilled to 11,184'. 04: 1 0 - 05:00 0.83 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3500 I 3900 psi, 90R, 70 fph, 93 deg incl, Drilled to 11,225'. 05:00 - 05:45 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 05:45 - 06:00 0.25 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3500/3900 psi, 90R, 70 fph, 93 deg incl, Drilled to 11,245'. 06:00 - 06:40 0.67 DRILL P PROD1 11270', Free spin=3550 psi at 2.5 bpm. Pit vol=295 bbls, IAP=OAP=O psi. 06:40 - 07: 15 0.58 DRILL P PROD1 11321', Orient around. Only getting 10 degree clicks on orienter. 07:15 - 07:50 0.58 DRILL P PROD1 Resume drilling. 2.5/2.5/3950 psi. 07:50 - 07:55 0.08 DRILL P PROD1 11351'. Currently drilling ahead in shale and orienting to dive down deeper into it as per asset instructions. 07:55 - 08: 15 0.33 DRILL P PROD1 Resume drilling in shale. 08: 15 - 08:45 0.50 DRILL P PROD1 11382', Wiper trip to the shoe. 08:45 - 10:30 1.75 DRILL N SFAL PROD1 10800', While making wiper trip, found a pinhole in the coil tubing. Good eyes Dave Duerr. POOH to swap coil tubing. Total running footage on pipe is 315,000', and maximum wear is 40% according to coil cade. There is nothing from pipe history to indicate that this should be a problem area. The pinhole was unexpected. Held SIMOPS meeting with rig hands and the hands working on 15-29 doing an OA down squeeze while POH. No conflicts between operations anticipated. 10:30 -11:15 0.75 DRILL N SFAL PROD1 Lay down drilling BHA. 11: 15 - 11 :40 0.42 DRILL N SFAL PROD1 Stab injector back on the tree, hold PJSM re: pumping N2. 11:40 - 12:50 1.17 DRILL N SFAL PROD1 PT hardline to 3500 psi, displace mud, water, methanol from coil tubing with N2, taking returns to the tiger tank. 12:50 - 16:20 3.50 DRILL N SFAL PROD1 Stand back injector, spool back coil and secure to reel. Used the new SWS winch and the Nordic 2 "Bull by a ring in his nose" technique. It worked very well. Secure coil with shipping bar. Knock apart hard line. Prep reel for removal. 16:20 - 16:35 0.25 DRILL N SFAL PROD1 Safety meeting with crane crew and Schlumberger hands re: swapping reels. 16:35 - 19:00 2.42 DRILL N SFAL PROD1 Pick reel from rig with Peak crane. C/O reel support bushings to fit next reel. 19:00 - 19:30 0.50 DRILL N SFAL PROD1 Set in next reel of coil with Peak crane. 19:30 - 21 :45 2.25 DRILL N SFAL PROD1 Pull CT stub to injecter head and thru chaines and pack-off. Printed: 9/2/2003 10:00:02 AM ) ) ARGO O:pE:)ratiol1s SUrrtmäry Réport Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/23/2003 8/24/2003 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 From·.;. To Hours Task Code NPT Phase Descriptionöf Operations 19:30 - 21:45 2.25 DRILL N SFAL PROD1 M/U new SWS CT connecter. Pull test CTC. M/U reel hardline. 21 :45 - 22: 15 0.50 DRILL N SFAL PROD1 Pump dart and fill coil. Dart on seat at 60.0 bbls. CT length = 15,660'. 22:15 - 22:30 0.25 DRILL N SFAL PROD1 SAFETY MEETING. Review procedure, hazards and mitigation for MWD BHA M/U. 22:30 - 23: 15 0.75 DRILL N SFAL PROD1 M/U MWD BHA #6, with 1.04 deg motor and used HYC DS49 bit #4. BHA = 65.8'. 23: 15 - 00:00 0.75 DRILL N SFAL PROD1 RIH with MWD BHA #6 to drill lateral section. 00:00 - 01: 15 1.25 DRILL N SFAL PROD1 RIH with MWD BHA #6 to drill lateral section. 01:15 - 01:30 0.25 DRILL P PROD1 Log tie-in at RA tag at 10,703'. [-11 ft CTD). 01 :30 - 02:00 0.50 DRILL P PROD1 RIH to TO. 02:00 - 02:50 0.83 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3600 I 4000 psi, 85R, 120 fph, 92 deg incl, Drilled to 11,447'. 02:50 - 03:00 0.17 DRILL P PROD1 Orient TF to 85L. 03:00 - 04:00 1.00 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3600 I 4000 psi, 85L, 80 fph, 90 deg incl, Drilled to 11,500'. 04:00 - 04:45 0.75 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3600 I 4000 psi, 85L, 80 fph, 88 deg incl, Drilled to 11,550'. 04:45 - 05:30 0.75 DRILL P PROD1 Wiper trip to window. Clean hole. RIH. 05:30 - 06:00 0.50 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3600 14000 psi, 85L, 80 fph, 88 deg incl, Drilled to 11,585'. 06:00 - 06:30 0.50 DRILL P PROD1 11570', Drilling ahead. Free spin=2450 psi at 2.4 bpm. Drilling at 2.4/2.4/3600 psi. Pit vol=282 bls. ROP=60 fph. 06:30 - 07:00 0.50 DRILL P PROD1 Drilling ahead, encountered significant reactive torque at 11600' . 07:00 - 07: 1 0 0.17 DRILL P PROD1 Orient to stay ahead of the reactive. 07:10- 08:15 1.08 DRILL P PROD1 Resume drilling. 08:15 - 08:30 0.25 DRILL P PROD1 Orient to 0 deg. We appear to have drilled in to the basement as per geo instructions. 08:30 - 09:30 1.00 DRILL P PROD1 11700', Wiper trip to shoe. 09:30 - 09:50 0.33 DRILL P PROD1 Orient to 20R. 09:50 - 11 :50 2.00 DRILL P PROD1 Resume drilling. 2.35/2.35/3900 psi. Pit vol=271 bbls. 11 :50 - 13:00 1.17 DRILL P PROD1 400' wiper. Drilling hard shale, and not making much ROP. Appears to be the base of the Sad. Plan is to drill up out of it. 13:00 - 13:35 0.58 DRILL P PROD1 Resume drilling. Performing mud swap to new mud. 13:35 - 13:50 0.25 DRILL P PROD1 11761', PU to orient. 13:50 - 14:35 0.75 DRILL P PROD1 Resume drilling. 14:35 - 14:50 0.25 DRILL P PROD1 11822', In sand now, ROP has pcked up quite nicely, orient around to 65R. 14:50 -15:15 0.42 DRILL P PROD1 Resume drilling. Free spin with new mud is 2.5 bpm, 3450 psi. Drilling at 2.5/2.5/3900 psi, Still taking mud on. 15:15 -16:10 0.92 DRILL P PROD1 11875', Wiper trip to the shoe. 16:10 -16:20 0.17 DRILL P PROD1 Orient to 80L. 16:20 - 17:20 1.00 DRILL P PROD1 Resume drilling. Mud swap complete. Pit vol=327 bbls. 17:20 - 17:25 0.08 DRILL P PROD1 11984', Take 2 clicks. 17:25 - 17:40 0.25 DRILL P PROD1 Resume drilling. 17:40 - 17:50 0.17 DRILL P PROD1 12006', Take 3 clicks. 17:50 -18:15 0.42 DRILL P PROD1 Resume drilling. 2.6/2.6 bpm, 35001 3900 psi, 90 deg incl, Drilled to 12,025'. 18:15 - 19:35 1.33 DRILL P PROD1 Wiper trip to window, clean hole, RIH. 19:35 - 21 :00 1.42 DRILL P PROD1 Drilling, 2.5/2.5 bpm, 3400/3900 psi, 30L, 94 deg incl, Drilled to 12110 ft. Printed: 9/2/2003 10:00:02 AM ) ') ARGO· Qpe ratlº nsSl.nnrna ryRe pO rt Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/24/2003 8/25/2003 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 From;. To Hours Task Code NPT Phase Description of Operations 21':00 - 21 :30 0.50 DRILL P PROD1 Orient TF to 100L. 21 :30 - 22:50 1.33 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3400 I 3900 psi, 30L, 100L, 92 deg incl, Drilled to 12,152'. 22:50 - 00:00 1.17 DRILL P PROD1 Wiper trip to window, clean hole, RIH. 00:00 - 00:30 0.50 DRILL P PROD1 Wiper trip to window, clean hole, RIH. 00:30 - 01 :30 1.00 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3450 I 3900 psi, 93 deg incl, 70L, Drilled to 12,200'. 01 :30 - 02:50 1.33 DRILL P PROD1 Drilling, 2.5 I 2.5 bpm, 3400 I 4000 psi, 95 deg incl, 100R, Drilled to 12,265'. Call TO. At end of polygon. 02:50 - 03:45 0.92 DRILL P PROD1 Wiper trip to window. Clean hole. 03:45 - 04: 15 0.50 DRILL P PROD1 Log final Tie-in with RA tag at 10703'. Log down. On depth, no correction. 04: 15 - 04:40 0.42 DRILL P PROD1 RIH, clean hole, Tag Final Corrected TO at 12,267'. 04:40 - 07:00 2.33 DRILL P PROD1 POH. Flag CT at 9700' EOP and 8100' EOP. POH. 07:00 - 07:40 0.67 DRILL P PROD1 Tag up at surface. Lay down Drilling BHA. 07:40 - 08:20 0.67 CASE P COMP Pickup liner running eq from BOT pickup, MU safety joint, pick up elevators for running liner. 08:20 - 08:40 0.33 CASE P COMP Safety meeting prior to picking up liner. 08:40 - 12:45 4.08 CASE P COMP PU and run 2-7/8" x 3-3/16" liner as per procedure. Details in well folder. 12:45 - 13:40 0.92 CASE P COMP PU injector, cut SWS CTC, install BOT CTC. Pull test to 35 klbs, PT to 3500 psi. MU CT to liner. Stab on well. 13:40 - 15:10 1.50 CASE P COMP RIH with Liner on coil tubing. 15:10 - 15:40 0.50 CASE P COMP Weight check at the window, 42klbs up weight. Continue RIH. Very slick to bottom. Tag up at 12280', Make a -13' correction to get on depth to ELM logs. PU weight with liner is 49 klbs. RIH, tag a 2nd time at same depth. Confirm on bottom. Shoe depth = 12267', Top of liner = 9791.28' 15:40-16:10 0.50 CASE P COMP PU to ball drop depth. Drop 5/8" ball to release from deployment sleeve. Chase with mud. Ball on seat at 53.2 bbls away. (Coil vol=60 bbls). Pressure up, good indication of shear. PU # 36 klbs, confirming the liner is released. 16:10 - 18:30 2.33 CEMT P COMP Circulate the well to KCL. 2.7 bpm, 1400 psi, Full returns. 18:30 -19:15 0.75 CEMT P COMP Circ. while R/U cementers and build 30 bbl Biozan pill in pill pit. 19:15 - 19:30 0.25 CEMT P COMP SAFETY MEETING. Review procedure, hazards and mitigation for pumping cement job. 19:30 - 20:25 0.92 CEMT P COMP Press test cement line. Cement at weight at 19:30 hrs. Stage 16.1 bbl, 15.8 ppg, G cement with Latex. 1.8 bpm, 1200 psi, Stop pump, close inner reel valve. clean lines, insert Dart. Displace with 0.5 bbl Biozan water. Check Dart. OK. 20:25 - 21 :00 0.58 CEMT P COMP Displace cement with 35 bbls, 2# Biozan water with friction reducer. 3.0/2.9 bpm, 2000 psi, Full returns, Displace with 2% KCL water, Slow to 1.5 bpm at 50 bbls, Dart on LWP at 58.7 bbls. Sheared at 2800 psi, Displace LWP at 2.9 bpm, 2400 psi, 2.8 bpm returns, Slow pump to 1.0 bpm, 900 psi, at 72 bbls displacement. LWP bumped at 75.0 bbls [calculated = 75.14 bbls], hold 1500 psi, OK. Check floats, OK. Cement job went with no problems, full returns, all tools worked OK. Printed: 9/2/2003 10:00:02 AM ) ') ARCO Operations $umrfiaryReport Page 7 9fH . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 8/25/2003 8/26/2003 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 From -To Hours Task Code NPT Phase Description of Operations 20:25 - 21 :00 0.58 CEMT P caMP Top of cement behind liner estimated at 10,500 ft. 21 :00 - 22:30 1.50 CEMT P CaMP paH, eirc. at rate to replace CT displacement. 150 psi pump press. 22:30 - 23:30 1.00 CEMT P CaMP Lla BKR CTLRT. Clear rig floor of liner handling tools. 23:30 - 00:00 0.50 EVAL P CaMP P/U SWS logging tools and BKR 2-1/8" motor and 2.30" diamond mill. 00:00 - 00: 15 0.25 EVAL P CaMP SAFETY MEETING. Review procedure, hazards and mitigation to M/U mill, motor and SWS Memory CNLlGR logging BHA. 00:15 - 01 :00 0.75 EVAL P CaMP M/U 2.30" diamond mill, 2-1/8" motor and SWS memory CNLlGR with carrier. 01 :00 - 03:45 2.75 EVAL P CaMP M/U 84 jts of CSH workstring. M/U SWS MHA. 03:45 - 05:00 1.25 EVAL P caMP RIH with mill, motor and SWS memory CNLlGR on CSH and CT. BHA = 2,644 ft. 05:00 - 06:30 1.50 EVAL P CaMP Start logging down from 9700 ft to PBTD with SWS CNLlGR at 30 FPM, 0.5 bpm. 06:30 - 07:45 1.25 EVAL N WAIT CaMP Yo Yo pipe while circulating mud to bit for perf pill. (Late arrival of vac truck on location). Pump 15 bbls, save 15 bbls back for dropping perf ball. 07:45 - 08:25 0.67 EVAL P CaMP Log up at 60 fpm laying in drilling mud at 0.5 bpm. 08:25 - 09:35 1.17 EVAL P CaMP End logging pass, paH with coil. 09:35 - 09:50 0.25 EVAL P CaMP Tag up at surface, stand back injector. Safety meeting prior to standing back CS hydril. 09:50 - 11 :30 1.67 EVAL P CaMP Stand back CS hydril. 11 :30 - 11 :40 0.17 EVAL P CaMP Safety meeting re radioative sources. 11 :40 - 12: 1 0 0.50 EVAL P CaMP Remove radioactive source from BHA. Lay down MCNL tool and accessories. 12:10 - 12:45 0.58 EVAL P CaMP Pressure test liner lap to 2000 psi for 30 min. Start pressure=2148 psi, Final pressure=2095 psi. Good pressure test. Liner held fine. 12:45 -14:10 1.42 EVAL N WAIT CaMP Wait on town to confirm perforation intervals. 14:10 - 15:30 1.33 PERF P CaMP Bring perf guns into the pipe shed. Total of 37. Prep rig floor to run perf guns. 15:30 - 15:45 0.25 PERF P CaMP SAFETY MEETING. Review procedure, hazards and mitigation for running pressure fired perf guns. Ensure all signs are up and required personnel only on the rig floor. 15:45 - 17:00 1.25 PERF P CaMP M/U 2" SWS PowerJet perf guns and blanks. 4 SPF. 17:00 - 18:00 1.00 PERF P CaMP M/U BKR Hyd disconnect and CSH. 18:00 - 18:30 0.50 PERF P CaMP SAFETY MEETING. Review procedure, hazards and mitigation for M/U CSH workstring. 18:30 - 19:20 0.83 PERF P CaMP M/U total of 31 stds of CSH workstring and SWS MHA for perforating. Total BHA = 2711 ft. 19:20 - 21 :00 1.67 PERF P CaMP RIH with SWS 2" Perforating guns on coil. Circ at .6 bpm, 200 psi, 21 :00 - 21 :20 0.33 PERF P CaMP Tag PBTD at 12,240 ft and correct to 12,228 ft on pick up. Tag again and had pick up at 12,228 ft. Bottom of BHA on depth with CNUGR of 8/26/03. Pull up to 12100'. Pump 10 bbls high viscosity new FloPro perf pill. Insert 5/8" steel ball. Displace with 2% KCL water. Ball moving inside reel. Position bottom shot at 12,080 ft BKB. 21 :20 - 21 :50 0.50 PERF P CaMP Perf guns in position. Displace 5/8" ball at 2.4 bpm, 2500 psi, slow down to 1.1 bpm, 700 psi, at 45 bbls, Ball on seat at 55.5 Printed: 9/2/2003 10:00:02 AM ) ) ARGO Ope ratiol1s $;ummary Report Page 8 gf8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 15-28 15-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 8/20/2003 Rig Release: 8/27/2003 Rig Number: N1 Spud Date: 6/5/1992 End: 8/27/2003 Date From·- To Hours .·Task Code NPT Phase Descri phon · of· Operatiöns 8/26/2003 21 :20 - 21 :50 0.50 PERF P COMP bbls, firing head sheared at 3600 psi, lost returns, indicating guns fired. 21 :50 - 23:30 1.67 PERF P COMP POH with fired guns. PERFORATION INTERVALS: 11,320 - 11,570 FT. 11,770 - 11,930 FT 12,020 - 12,080 FT, TOTAL = 470 FT of Perfs at 4 SPF 23:30 - 00:00 0.50 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation to layout CSH workstring in singles. 8/27/2003 00:00 - 01 :30 1.50 PERF P COMP Lay down CSH work string in singles, 62 jts. 01 :30 - 01 :45 0.25 PERF P COMP PJSM for laying down perforating guns. 01 :45 - 05:30 3.75 PERF P COMP LD perforating guns. All shots fired. Remove guns from pipe shed. 05:30 - 06:00 0.50 PERF P COMP Crew change, Safety meeting to layout rest of CSH workstring 06:00 - 07:30 1.50 PERF P COMP RIH with 11 stds CSH workstring, layout CSH in singles for rig move. 07:30 - 08:45 1.25 WHSUR P COMP RIH with nozzle and freeze protect to 2000 ft with MEOH. POH. Close master and swab valves. 08:45 - 09:00 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation to pump N2. 09:00 - 10:30 1.50 RIGD P POST Pump N2 with SWS N2 unit, 1500 CFM for 13 min, 1100 psi. Bleed down pressure to tiger tank. 10:30 - 12:30 2.00 RIGD P POST Clean rig pits. Cut off CTC. Pull CT out of injecter head and set CT stub to side of rig floor. 12:30 - 14:30 2.00 RIGD P POST N/D BOPE and N/U Tree cap. Pressure test tree cap. RELEASED RIG AT 14:30 HRS, 08/27/2003 Total time on well was 7 days and 3-1/2 hours. Printed: 9/2/2003 10:00:02 AM ) ) §03--/ J l.. \. . 12-Sep-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 15-28A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 10,685.69' MD Window / Kickoff Survey: 10,693.00' MD (if applicable) Projected Survey: 12,267.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) ..1..... ~~ ;~? :.:~ - -.- ;. .~~ ~~,,\,,,~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_EOA DS 15 15-28A ~ Job No. AKMW0002621480, Surveyed: 21 August, 2003 Survey Report 11 September, 2003 Your Ref: API 500292224701 Surface Coordinates: 5961273.88 N, 675940.36 E (70017' 59.2767" N, 148034'29.9417" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ..----- Surface Coordinates relative to Project H Reference: 961273.88 N, 175940.36 E (Grid) Surface Coordinates relative to Structure Reference: 2444.11 N, 300.46 W (True) Kelly Bushing: 67.00ft above Mean Sea Level Elevation relative to Project V Reference: 67.00ft Elevation relative to Structure Reference : 67.00ft 5r""""1 ·.....V-5LJr1 DR f L'C'i~NG'~Suen:ivn:=ueS A Halliburton Company Survey Ref: svy4092 Dri/lQuest 3.03.02.005 Page 2 of4 11 September, 2003 - 16:32 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-28A Your Ref: API 500292224701 Job No. AKMW0002621480, Surveyed: 21 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 10685.69 27.120 8.160 8575.41 8642.41 5697.04 N 678.69 W 5966953.46 N 675128.47 E -1270.48 Tie On Point MWD Magnetic 10693.00 27.060 8.140 8581.92 8648.92 5700.33 N 678.22 W 5966956.77 N 675128.86 E 0.830 -1270.35 Window Point 10735.19 36.920 12.390 8617.66 8684.66 5722.27 N 674.13 W 5966978.79 N 675132.43 E 23.959 -1268.58 10769.64 45.370 14.580 8643.58 8710.58 5744.28 N 668.81 W 5967000.92 N 675137.23 E 24.879 -1265.59 10798.90 53.650 15.990 8662.56 8729.56 5765.72 N 662.94 W 5967022.50 N 675142.61 E 28.533 -1261.99 ~ 10831.52 61.610 17.280 8680.01 8747.01 5792.09 N 655.04 W 5967049.04 N 675149.88 E 24.629 -1256.89 10862.05 69.250 19.470 8692.70 8759.70 5818.41 N 646.28 W 5967075.57 N 675158.02 E 25.859 -1250.93 10909.74 81.500 29.520 8704.75 8771.75 5860.22 N 627.11 W 5967117.81 N 675176.21 E 32.766 -1236.24 10956.05 82.820 42.560 8711 .09 8778.09 5897.22 N 600.17 W 5967155.44 N 675202.27 E 28.038 -1213.31 10985.65 83.230 51.760 8714.69 8781.69 5917.18 N 578.65 W 5967175.89 N 675223.32 E 30.882 -1194.00 11013.71 86.430 57.710 8717.22 8784.22 5933.30 N 555.85 W 5967192.54 N 675245.74 E 23.998 -1173.00 11051.35 89.340 65.290 8718.62 8785.62 5951.23 N 522.82 W 5967211.24 N 675278.34 E 21.556 -1142.03 11081.24 88.460 73.040 8719.19 8786.19 5961.85 N 494.91 W 5967222.51 N 675306.00 E 26.090 -1115.38 11110.59 92.950 76.040 8718.83 8785.83 5969.67 N 466.63 W 5967230.99 N 675334.08 E 18.397 -1088.08 11144.60 94.160 80.330 8716.72 8783.72 5976.62 N 433.42 W 5967238.72 N 675367.13 E 13.082 -1055.77 11174.75 93.830 85.910 8714.62 8781.62 5980.23 N 403.57 W 5967243.02 N 675396.88 E 18.495 -1026.46 11210.32 92.860 90.310 8712.54 8779.54 5981.40 N 368.09 W 5967245.02 N 675432.32 E 12.646 -991.30 11241.62 92.420 93.830 8711.10 8778.10 5980.27 N 336.85 W 5967244.62 N 675463.58 E 11 .322 -960.11 11275.15 92.330 99.470 8709.71 8776.71 5976.39 N 303.58 W 5967241.52 N 675496.93 E 16.808 -926.62 11311.24 92.860 1 07.400 8708.07 8775.07 5968.02 N 268.55 W 5967233.97 N 675532.15 E 21.999 -890.90 11342.33 93.570 113.390 8706.33 8773.33 5957.21 N 239.46 W 5967223.85 N 675561.48 E 19.371 -860.85 ~ 11380.64 91.370 121.850 8704.67 8771.67 5939.48 N 205.59 W 5967206.92 N 675595.76 E 22.796 -825.30 11410.47 90.660 126.790 8704.14 8771.14 5922.67 N 180.96 W 5967190.69 N 675620.78 E 16.728 -799.06 11438.70 88.460 129.250 8704.36 8771.36 5905.28 N 158.72 W 5967173.83 N 675643.41 E 11 .690 -775.13 11470.32 88.110 125.910 8705.31 8772.31 5886.01 N 133.68 W 5967155.15 N 675668.90 E 10.616 -748.20 11503.87 87.750 122.380 8706.52 8773.52 5867.19 N 105.94 W 5967136.98 N 675697.08 E 10.569 -718.65 11536.16 87.310 119.390 8707.91 8774.91 5850.64 N 78.25 W 5967121.08 N 675725.14 E 9.351 -689.38 11569.03 86.520 115.680 8709.68 8776.68 5835.46 N 49.16 W 5967106.59 N 675754.59 E 11.524 -658.86 11610.63 86.170 110.050 8712.33 8779.33 5819.34 N 10.92 W 5967091.37 N 675793.19 E 13.532 -619.14 11645.05 86.700 106.520 8714.48 8781 .48 5808.56 N 21.70 E 5967081.36 N 675826.05 E 10.351 -585.58 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-28A Your Ref: AP/500292224701 Job No. AKMW0002621480, Surveyed: 21 August, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) e/100ft) 11677.25 86.780 104.050 8716.31 8783.31 5800.09 N 52.70 E 5967073.61 N 675857.25 E 7.662 -553.86 11708.13 89.340 103.530 8717.35 8784.35 5792.73 N 82.67 E 5967066.96 N 675887.38 E 8.459 -523.28 11739.66 91.810 104.410 8717.04 8784.04 5785.12 N 113.27 E 5967060.07 N 675918.14 E 8.316 -492.06 11776.71 93.040 111.810 8715.47 8782.47 5773.63 N 148.43 E 5967049.40 N 675953.56 E 20.229 -455.90 11806.64 91.720 115.860 8714.22 8781 .22 5761.54 N 175.77 E 5967037.96 N 675981.18 E 14.221 -427.44 ". .J - 11842.70 91.450 120.790 8713.22 8780.22 5744.45 N 207.49 E 5967021.61 N 676013.30 E 13.687 -394.10 11876.89 90.480 124.500 8712.65 8779.65 5726.01 N 236.27 E 5967003.85 N 676042.50 E 11.214 -363.55 11908.97 90.400 120.440 8712.40 8779.40 5708.79 N 263.33 E 5966987.27 N 676069.95 E 12.658 -334.84 11940.82 90.220 115.680 8712.23 8779.23 5693.81 N 291.43 E 5966972.96 N 676098.39 E 14.956 -305.33 11970.55 90.040 112.160 8712.16 8779.16 5681.76 N 318.60 E 5966961.54 N 676125.84 E 11 .855 -277.05 12003.50 90.040 107.930 8712.14 8779.14 5670.47 N 349.55 E 5966950.98 N 676157.04 E 12.838 -245.09 12037.35 93.130 105.820 8711.20 8778.20 5660.65 N 381.92 E 5966941.92 N 676189.64 E 11.052 -211.87 12069.02 94.980 103.350 8708.96 8775.96 5652.69 N 412.49 E 5966934.68 N 676220.39 E 9.728 -180.64 12100.39 94.710 100.000 8706.31 8773.31 5646.37 N 443.10 E 5966929.08 N 676251.13 E 10.676 -149.54 12134.34 92.860 95.770 8704.07 8771.07 5641.72 N 476.64 E 5966925.22 N 676284.78 E 13.574 -115.69 12162.13 91.980 92.600 8702.90 8769.90 5639.70 N 504.33 E 5966923.84 N 676312.51 E 11.828 -87.94 12195.33 95.240 92.600 8700.81 8767.81 5638.20 N 537.43 E 5966923.11 N 676345.63 E 9.819 -54.87 12227.17 95.770 97.890 8697.75 8764.75 5635.30 N 568.98 E 5966920.96 N 676377.24 E 16.621 -23.19 12243.64 95.330 99.470 8696.16 8763.16 5632.83 N 585.18 E 5966918.86 N 676393.49 E 9.915 -6.82 12267.00 95.330 99.470 8693.99 8760.99 5629.00 N 608.12 E 5966915.57 N 676416.52 E 0.000 16.40 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. ~ The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 96.000° (True). Magnetic Declination at Surface is 25.815°(21-Aug-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12267.00ft., The Bottom Hole Displacement is 5661.75ft., in the Direction of 6.166° (True). 11 September, 2003 - 16:32 Page 3 of 4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_EOA DS 15 - 15-28A Your Ref: AP/500292224701 Job No. AKMW0002621480, Surveyed: 21 August, 2003 BPXA North Slope A/aska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 10685.69 10693.00 12267.00 8642.41 8648.92 8760.99 5697.04 N 5700.33 N 5629.00 N 678.69 W 678.22 W 608.12 E Tie On Point Window Point Projected Survey .-/ Survey tool program for 15-28A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 10685.69 0.00 10685.69 8642.41 12267.00 8642.41 BP High Accuracy Gyro (15-28) 8760.99 MWD Magnetic (15-28A) .-..-T' 11 September, 2003 - 16:32 Page 4 of4 DrillQuest 3.03.02.005 ) ('Of, 7'\ ¡-[:::::I . ¡ I .. j :, I J-- , J ~ L } .................... .'" ) f\[1 r ~íY1 Lk ~iÆJ)u~ FRANK H. MURKOWSKI, GOVERNOR AIfA.~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field 15-28A BP Exploration (Alaska) Inc. Permit No: 203-124 Surface Location: 207' SNL, 34'EWL, SEC. 22, TIIN, R14E Bottomhole Location: 84' NSL, 586'EWL, SEC. 10, T11N, R14E Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above development well. This permit to . redrill does not exempt you ITom obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, . /~~r _. ~. , ~~~/ ¿::;-. ~ Sarah Palin Chair BY ORDER OF THE COlVlMISSION DATED this...!.£... day of July, 2003 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section ) STATE OF ALASKA ) ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 ~mtQr~Pl)\f ~~~!,,~.g~~~IB'rerr¡~flt9i!:; \ t o Service 0 Development Gas 0 Single Lone i\ J:J\ ~W!~iple Zone 5. Datum Elevation (DF or KB) 10. Field and' Pöòl ",,:, '." KBE = 67' 6. Property Designation ADL 028303 x = 675940, Y = 5961273 7. Unit or Property Name Prudhoe Bay Unit X=675111,Y=5966802 8. Well Number /' 15-28A x = 676350, Y = 5966856 9. Approximate spud date 07/30/03 /'" Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12325' MD /8671' TVDss 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 94 0 Maximum surface 2096 psig, At total depth (TVD) 8800' /3152 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD /' TVD (include staae data) 9785' 7831' 12325' 8671' 87 cu ft Class 'G' /" 181 Filing Fee 0 Property Plat 181 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 18120 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th~f~orEJPJ~n? is tn~,nd correct}o the best of my kn~~ledge . ~)'i I,. J Signed Mary Endacott If! 1\(1.:t1t (I..I( þ. ,/¿.;:¡j0cÁ ' Title CT Dnlllng Engineer Date ~(f / I~ ",I~ I, . ';:.:(:.,!."i:(~i$s~~n,Y":ønly':;::,:,·:: " Permit Number API Number Approval Dflte See cover letter ';>O.i. - 1.2. ~ 50- 029-22247-01 '7/ S- /03 for other requirements Conditions of Approval: Samples Required 0 Yes JiI No Mud Log Required 0 Yes !S] No Hydrogen Sulfide Measures iii Yes 0 No Directional Survey Required J8I Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU ß. ,ther:T€.~1- "ßOP,6-1 ŠÇOÐ ((.1/. ~ i ¿_ / · \ by order of ' :~;~o~~~~r Rev. 12~l" u~ I'~^-- ðr~rGe' N A:romm¡SSiOn Date 7 U~~it n ~r~icate 1 a. Type of work 0 Drill 181 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 207' SNL, 34' EWL, SEC. 22, T11 N, R14E At top of productive interval 59' NSL, 655' WEL, SEC. 9, T11 N, R14E At total depth 84' NSL, 586' EWL, SEC. 10, T11 N, R14E 12. Distance to nearest property line 13. Distance to nearest well ADL 028306,84' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 10695' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size Hole Casina Weight Grade Couplina Lenath 3-3/4" 3-3116" x 2-7/8" 6.2#/6.16# L-80 ST-L 2540' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing 11037 feet 8958 feet 1 0979 feet 8906 feet Length Size Structural Conductor Surface Intermediate Production Liner 115' 20" 4052' 9-5/8" 10272' 7" 1037' 5" Perforation depth: measured 10876' - 10906' true vertical 8813' - 8840' 20. Attachments 'yJG,1\ ì /iSll-003 ~"''''~\ It"'" t' F·· l~·~~ i:: :\~:,.; ø r¡!:J'L'I~.~ JUL 1 1 í!.003 Prudhoe Bay Field / Prudhoe ...- ./ Bay Pool 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 Plugs (measured) Junk (measured) Cemented MD TVD 298 cu ft Coldset 115' 115' 2235 cu ft AS III, 343 cu ft Class 'G' 4052' 3485' 725 cu ft Class 'G' 10306' 8318' 129 cu ft Class IG' 10019' - 11037' 8092' - 8958' ) ) BP 15-28a CrD Sidetrack Summary of Operations: /" Phase 1: Prep work - downsqueeze OA, set secondary vlv on lA, integrity testing tree, set whipstock Phase 2: Oownsqueeze cmt into perfs, mill window /' Phase 3: Drill and Complete sidetrack Mud Program: · Phase 2: Viscosified Seawater · Phase 3: Flo-Pro (8.6 - 8.7 ppg) /' Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: ,_ /' The production line ~I b 33/16" x 2 7/8" from 9785'MD (-7831 'TVOss) to TO. The liner will be cemented with a minimum 15.5 Is to bring cement up to -200ft above the window. Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. /' · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 92 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · MWO Gamma Ray will be run in the open hole section. Memory CNL will be run inside the liner. Ha~~s / · The maximum recorded H2S at OS 15 is 33 ppm, last sample on 15-28 15ppm 3/01. · One mapped fault will be crossed, medium risk of lost circulation. · Cretaceous leak on IA Reservoir Pressure Res. press. is estimated to be 3152psi at 8800'ss (6.9ppg emw) estimated. Max. surface pressure with gas (0.12 psi/ft) to surface is 2096 psi. /" TREE = FMC WELLHEAD= MCEVOY 'À ëfDÄ të)^R;;' ''^w''''Mw····SÄ'KEFfC . 'A Wo'o'.W"w.'...'.'.w...............'."'...."""......" KB. ELEV = 67' BF. ELEV = ,,,,',",,,,.,w''^'''''''''''''.''.'.'''? ,wMY,'WM.......................................W.,W.WNr,""'.·.W..."'''''''''''''''.........',w,'''...'.......,'.....',,,,'''",'w...,'.................',.......... KOP = 1200' 'Mäx'^Ãr:¡g'leM;;....^'.""W'.'N4^5"@'3149~ 15ãiûmrv1D ~."..^'''^ ·".N"·"'.".'. 1 0936' ·Dätü·m··iV-~."..^....-"www·1r8ÕÖÎ"SS. ) 15-28 A ) SAFElY NOTES: GAS LIFT MANDRELS HAVE LOWER psi RATE THAN NORMAL, CHECK WITH ACE/FE Proposed cro Sidetrack -- 21041 1-14-1/2" CAMCO BAL-O SSSV NIP, ID = 3.812" 1 I 9-5/8" CSG, 36#, J-55, ID = 8.921" 1-1 40521 I~ ~ L ST MD TVD DEV 1 4069 3498 43 2 7416 6003 42 3 9709 7834 33 GAS LIFT MANDRELS 1YÆ VLV LATCH SIZE CA-KBG-2-LS 1" INTEGRAL CA-KBG-2-LS 1" INTEGRAL CA-KBG-2-LS 1" INTEGRAL DATE Minimum ID = 3.812" @ 2104' 1 1-17" x 4-1/2" BAKER S-3 PACKER, ID = 3.958" 4-1/2" CAMCO BAL-O SSSV NIP :8 ~ 97771 8 ·1 9785' l-i Top of 3-3/16" Liner I ~/ I I 1 9800' 1-14-1/2" HES X NIPPLE, ID = 3.813" . . ······1 9815' 1-13-1/2" X NIP, ID == 2.813" I 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, ID = 3.958" l-i 98221 98221 98121 - 4-1/2" ITWLEG 1 - ELMD IT - LOGGED 10/13/96 I TOP OF 5" LNR l-i 9993' 1 I 17" CSG, 26#, L-80, ID = 6.276" l-i 10312' ~ I ~ ÆRFORA TION SUMMARY REF LOG: BHCS on 06/29/92 ANGLEATTOPÆRF: 26 @ 10876' Note: Refer to Production DB for historical perf data I SIZE I SPF I INTERVAL I Opn/Sqz I DATE I 3-3/8" 6 10876 - 10906 isolated proposed 'i 10500' 1-1 Top of cement 1 / 11100' 1-13-3/16 x 2-7/8 X-over ! r-----1 ,..-----, r> /' 12325' I 1/ 3-3/16" X 2-7/8" cmt'ed and perfedl-l 10695' 1-1 Mechanical Whipstock I PBTD 1-1 10979' 1 5" LNR, 15#, 13CR, 0.0188 bpf, ID = 4.408" 1-1 110371 ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 07/04/92 ORIGINAL COMPlETION 07/22/96 LAST WORKOVER 12/14/00 SIS-lsl CONVERTED TO CANVAS 01/23/01 SIS-LG REVISION 06/27/01 RNItlh CORRECTIONS PRUDHOE BA Y UNIT WELL: 15-28 ÆRMIT No: 92-015 API No: 50-029-22247-00 SEC22, TUN, R14E607.65 FEL4916.93 FNL BP Exploration (Alaska) ") ) bp BP Baker Hughes INTEQ Planning Report Company: BP Amoco Field: Prudhoe Bay Site: PB DS 15 Well: 15·26 Wellpath: Plan#415-26A Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1666) Sys Datum: Mean Sea Level Site: PB DS 15 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 15-28 15·28 Well Position: Well: +N/-S 2444.72 ft Northing: +E/-W -299.14 ft Easting: Position Uncertainty: 0.00 ft Wellpath: Plan#4 15-28A 500292224701 Current Datum: 15-28 RKB Magnetic Data: 7/7/2003 Field Strength: 57552 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Name Description Dip. Dlr. 15-28A Polygon4.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 15-28A Fault 1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 15-28A Fault 3 ·Polygon 1 ·Polygon 2 15-28A Fault 2 -Polygon 1 -Polygon 2 15-28A Fault 4 -Polygon 1 -Polygon 2 15-28A Fault 5 -Polygon 1 -Polygon 2 15-28A T4.3 TVD ft 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 8675.00 5958837.36 ft 676296.98 ft 5961274.23 ft 675940.61 ft Height 67.00 ft +N/-S ft 0.00 +N/-S ft 5656.75 5656.75 5471.83 5644.79 5844.06 6074.55 5896.16 6319.91 6319.91 6068.62 6057.50 6068.62 5399.88 5399.88 5736.59 5616.98 5616.98 5367.27 5689.62 5689.62 6149.60 6054.56 6054.56 6315.23 5563.83 -æ ïÑ-;fEii~--··-· Date: 7/7/2003 Time: 16:10:26 Page: Co-ordinate(NE) Reference: Well: 15-28, True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N.0.00E,96.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle +E/-W ft 638.04 638.04 503.67 -4.46 -226.87 -201.46 111.47 -469.81 -469.81 -375.66 99.24 -375.66 586.01 586.01 773.96 -13.11 -13.11 654.27 814.87 814.87 96.40 11.14 11.14 285.34 547.83 Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Latitude: Longitude: North Reference: Grid Convergence: 70 17 35.236 N 148 34 21.213W True 1.34 deg Slot Name: 28 Latitude: Longitude: 70 17 59.280 N 148 34 29.934 W Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Map Map Northing Easting ft ft 5966944.00 676445.99 5966944.00 676445.99 5966756.00 676316.00 5966917.00 675803.99 5967111.00 675576.99 5967342.00 675597.00 5967171.00 675914.00 5967581.00 675322.99 5967581.00 675322.99 5967332.00 675422.99 5967332.00 675897.99 5967332.00 675422.99 5966686.00 676399.99 5966686.00 676399.99 5967027.00 676580.00 5966889.00 675795.99 5966889.00 675795.99 5966655.00 676468.99 5966981.00 676621.99 5966981.00 676621.99 5967424.00 675893.00 5967327.00 675809.99 5967327.00 675809.99 5967594.00 676078.00 5966849.00 676357.99 15-28 10685.69 ft Mean Sea Level 25.86 deg 80.84 deg Direction deg 96.00 <--- Latitude --->: Deg Min Sec 70 18 54.914 N 70 18 54.914 N 70 18 53.095 N 70 18 54.796 N 70 18 56.756 N 70 18 59.023 N 70 18 57.268 N 70 19 1 .436 N 70 19 1.436 N 70 18 58.964 N 70 18 58.855 N 70 18 58.964 N 70 18 52.387 N 70 18 52.387 N 70 18 55.699 N 70 18 54.523 N 70 18 54.523 N 70 18 52.066 N 70 18 55.237 N 70 18 55.237 N 70 18 59.761 N 70 18 58.826 N 70 18 58.826 N 70 19 1.390 N 70 18 54.000 N <- Longitude -> Deg Min Sec 148 34 11.319 W 148 34 11.319 W 148 34 15.240 W 148 34 30.064 W 148 34 36.553 W 148 34 35.812 W 148 34 26.682 W 148 34 43.642 W 148 34 43.642 W 148 34 40.894 W 148 34 27.039 W 148 34 40.894 W 148 34 12.838 W 148 34 12.838 W 148 34 7.354 W 148 34 30.317 W 148 34 30.317 W 148 34 10.847 W 148 34 6.160 W 148 34 6.160 W 148 34 27.121 W 148 34 29.609 W 148 34 29.609 W 148 34 21.609 W 148 34 13.951 W ) ) , . ÏÑ";'i;EQ'~-;'- ,bp BP Baker Hughes INTEQ Planning Report Company: 6P Amoco Field: Prudhoe Bay Site: PB OS 15 Well: 15-28 Wellpath: Plan#4 15-28A Targets Date: 7/7/2003 Time: 16:10:26 Page: 2 Co-ordinate(NE) Reference: Well: 15-28, True North Vertical(TVD)Reference: System: Mean Sea L~vel Section (VS) Reference: Well (O.00N.0.00E,96.00Azi) Survey Calculation Method: Minimum Curvature Dbl Oracle Map Map <--- . Latitude --> <;- . Longitude .;..-> Name Description TVD +N/-S +~/-W Northing Easting Deg Min Sec Deg Min See Dip. Dir. ft ft ft ft ft 15-28A T4.2 8700.00 5908.68 -124.32 5967178.00 675677.99 70 18 57.392 N 148 34 33.561 W 15-28A T4.1 8725.00 5968.72 -552.06 5967228.00 675248.99 70 18 57.982 N 148 3446.041 W Annotation MD TVD ft ft 10685.69 8575.41 TIP 10695.00 8583.70 KOP 10715.00 8601.37 3 10961.91 8721.39 4 11061.91 8721.39 5 11211.91 8715.38 6 11421.91 8701.31 7 11571.91 8696.40 8 11696.91 8692.77 9 11971.91 8682.41 10 12221.91 8674.44 11 12325.00 8671.48 TO Plan: Plan #4 Date Composed: 717/2003 Identical to Lamar's Plan #4 Version: 3 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +N/-S +E/..W DLS Build Tun~ TFO Target ft deg deg ft ft ft deg/100ft deg/100ft dag/100ft deg 10685.69 27.12 8.16 8575.41 5697.04 -678.67 0.00 0.00 0.00 0.00 10695.00 27.04 8.13 8583.70 5701.23 -678.07 0.87 -0.86 -0.32 189.67 10715.00 28.80 8.91 8601.37 5710.50 -676.68 9.00 8.81 3.88 12.00 10961.91 90.00 19.46 8721.39 5904.84 -620.84 25.00 24.78 4.27 12.00 11061.91 90.00 44.46 8721.39 5989.01 -568.33 25.00 0.00 25.00 90.00 11211.91 94.44 81.73 8715.38 6055.69 -437.08 25.00 2.96 24.85 82.70 11421.91 92.70 134.32 8701.31 5993.03 -244.79 25.00 -0.83 25.04 90.00 11571.91 91.02 116.38 8696.40 5906.65 -123.01 12.00 -1.12 -11.95 265.00 11696.91 92.28 131.34 8692.77 5837.24 -19.55 12.00 1.01 11.96 85.00 11971.91 91.91 98.32 8682.41 5723.45 226.43 12.00 -0.13 -12.01 270.00 12221.91 91.66 128.33 8674.44 5625.65 453.27 12.00 -0.10 12.01 90.00 12325.00 91.62 115.95 8671.48 5570.93 540.35 12.00 -0.04 -12.00 270.00 Survey Incl Azim SSTVD N/S E/W ¡vIapN MapE VS DLS TFO Tool deg deg ft ft ft ft ft ft deg/100ft deg 10685.69 27.12 8.16 8575.41 5697.04 -678.67 5966953.45 675128.79 -1270.45 0.00 0.00 TIP 10695.00 27.04 8.13 8583.70 5701.23 -678.07 5966957.66 675129.29 -1270.29 0.87 189.67 KOP 10700.00 27.48 8.33 8588.14 5703.50 -677.74 5966959.93 675129.57 -1270.20 9.00 12.00 MWD 10715.00 28.80 8.91 8601.37 5710.50 -676.68 5966966.95 675130.46 -1269.88 A'OO 11.82 3 10725.00 31.25 9.91 8610.03 5715.43 -675.86 5966971.90 675131.17 -1269.58 25.00 12.00 MWD 10750.00 37.40 11.89 8630.66 5729.26 -673.18 5966985.79 675133.53 -1268.36 25.00 11.13 MWD 10775.00 43.58 13.38 8649.67 5745.09 -669.61 5967001.70 675136.72 -1266.47 25.00 9.49 MWD 10800.00 49.77 14.57 8666.81 5762.73 -665.21 5967019.43 675140.70 -1263.94 25.00 8.36 MWD 10813.12 53.02 15.11 8675.00 5772.64 -662.59 5967029.40 675143.10 -1262.36 25.00 7.54 15-28A T 10825.00 55.97 15.56 8681.90 5781.96 -660.03 5967038.78 675145.44 -1260.79 25.00 7.20 MWD 10850.00 62.17 16.41 8694.74 5802.57 -654.12 5967059.52 675150.86 -1257.07 25.00 6.94 MWD 10861.85 65.12 16.78 8700.00 5812.74 -651.09 5967069.75 675153.65 -1255.12 25.00 6.50 15-28A T 10875.00 68.39 17.17 8705.19 5824.30 -647.56 5967081.39 675156.91 -1252.82 25.00 6.34 MWD 10900.00 74.60 17.87 8713.12 5846.89 -640.42 5967104.15 675163.51 -1248.08 25.00 6.19 MWD ) ) ..bp BP . Baker Hughes INTEQ Planning Report --------.------. INTEQ Company: BP Amoco Date: 7/7/2003 Time: 16:10:26 Page: 3 Field: Prudhoe Bay Co--ordinate(NE) Reference: Well: 15-28, True North Site: . P8 DS 15 . Vertical (T\'D) Reference: System: Mean $ea Level Well: 15-28 Section (VS) Reference: Well (0.OON.O.OOE,96.00Azi) Wellpath: Plan#415-28A Surve)' Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S EIW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 10925.00 80.82 18.53 8718.44 5870.08 -632.80 5967127.51 675170.59 -1242.92 25.00 5.96 MWD 10950.00 87.04 19.16 8721.09 5893.60 -624.77 5967151.21 675178.07 -1237.40 25.00 5.82 MWD 10961.91 90.00 19.46 8721.39 5904.84 -620.84 5967162.53 675181.74 -1234.66 25.00 5.76 4 10975.00 90.00 22.73 8721.39 5917.05 -616.13 5967174.85 675186.16 -1231.25 25.00 90.00 MWD 11000.00 90.00 28.98 8721.39 5939.53 -605.23 5967197.58 675196.53 -1222.76 25.00 90.00 MWD 11025.00 90.00 35.23 8721.39 5960.70 -591.95 5967219.05 675209.31 -1211.77 25.00 90.00 MWD 11050.00 90.00 41.48 8721.39 5980.29 -576.44 5967239.00 675224.35 -1198.40 25.00 90.00 MWD 11061.91 90.00 44.46 8721.39 5989.01 -568.33 5967247.91 675232.26 -1191.23 25.00 90.00 5 11075.00 90.42 47.70 8721.35 5998.09 -558.90 5967257.20 675241.47 -1182.81 25.00 82.70 MWD 11100.00 91.20 53.90 8720.99 6013.88 -539.54 5967273.44 675260.46 -1165.20 25.00 82.71 MWD 11125.00 91.98 60.11 8720.30 6027.48 -518.59 5967287.53 675281.08 -1145.79 25.00 82.80 MWD 11150.00 92.73 66.32 8719.27 6038.73 -496.30 5967299.30 675303.10 -1124.80 25.00 82.97 MWD 11175.00 93.45 72.54 8717.92 6047.50 -472.94 5967308.61 675326.24 -1102.49 25.00 83.23 MWD 11200.00 94.13 78.76 8716.27 6053.68 -448.79 5967315.35 675350.24 -1079.11 25.00 83.56 MWD 11211.91 94.44 81.73 8715.38 6055.69 -437.08 5967317.64 675361.90 -1067.68 25.00 83.97 6 11225.00 94.43 85.01 8714.36 6057.20 -424.12 5967319.45 675374.82 -1054.95 25.00 90.00 MWD 11250.00 94.38 91.28 8712.44 6058.00 -399.22 5967320.83 675399.69 -1030.27 25.00 90.25 MWD 11275.00 94.27 97.55 8710.56 6056.08 -374.38 5967319.50 675424.57 -1005.36 25.00 90.74 MWD 11300.00 94.11 103.81 8708.73 6051.47 -349.89 5967315.45 675449.16 -980.52 25.00 91.21 MWD 11325.00 93.91 110.08 8706.98 6044.20 -326.05 5967308.75 675473.17 -956.05 25.00 91.67 MWD 11350.00 93.65 116.33 8705.33 6034.38 -303.13 5967299.46 675496.30 -932.23 25.00 92.10 MWD 11375.00 93.36 122.59 8703.80 6022.11 -281.41 5967287.71 675518.30 -909.35 25.00 92.52 MWD 11400.00 93.02 128.84 8702.41 6007.54 -261.16 5967273.63 675538.89 -887.69 25.00 92.90 MWD 11421.91 92.70 134.32 8701.31 5993.03 -244.79 5967259.49 675555.59 -869.89 25.00 93.25 7 11425.00 92.67 133.95 8701.17 5990.88 -242.58 5967257.40 675557.85 -867.4 7 12.00 265.00 MWD 11450.00 92.40 130.96 8700.06 5974.02 -224.15 5967240.98 675576.67 -847.38 12.00 264.98 MWD 11475.00 92.13 127.97 8699.07 5958.15 -204.87 5967225.56 675596.32 -826.54 12.00 264.85 MWD 11500.00 91.85 124.98 8698.20 5943.30 -184.78 5967211.19 675616.75 -805.01 12.00 264.73 MWD 11525.00 91.57 121.99 8697.46 5929.52 -163.94 5967197.90 675637.90 -782.84 12.00 264.63 MWD 11550.00 91.28 119.00 8696.84 5916.83 -142.41 5967185.73 675659.72 -760.10 12.00 264.54 MWD 11571.91 91.02 116.38 8696.40 5906.65 -123.01 5967176.00 675679.35 -739.75 12.00 264.47 8 11575.00 91.06 116.75 8696.34 5905.27 -120.25 5967174.69 675682.15 -736.86 12.00 85.00 MWD 11600.00 91.32 119.74 8695.82 5893.45 -98.23 5967163.38 675704.43 -713.73 12.00 85.01 MWD 11625.00 91.57 122.73 8695.19 5880.49 -76.87 5967150.92 675726.09 -691.12 12.00 85.07 MWD 11650.00 91.82 125.72 8694.45 5866.43 -56.21 5967137.36 675747.07 -669.11 12.00 85.14 MWD 11675.00 92.07 128.71 8693.60 5851.32 -36.31 5967122.72 675767.32 -647.74 12.00 85.23 MWD 11696.91 92.28 131.34 8692.77 5837.24 -19.55 5967109.03 675784.41 -629.60 12.00 85.33 9 11700.00 92.28 130.97 8692.65 5835.21 -17.22 5967107.06 675786.78 -627.07 12.00 270.00 MWD 11725.00 92.28 127.96 8691.65 5819.33 2.06 5967091.64 675806.42 -606.24 12.00 269.99 MWD 11750.00 92.27 124.96 8690.66 5804.49 22.15 5967077.27 675826.85 -584.71 12.00 269.87 MWD 11775.00 92.25 121.96 8689.67 5790.72 42.99 5967063.99 675848.01 -562.55 12.00 269.75 MWD 11800.00 92.23 118.96 8688.70 5778.06 64.52 5967051.84 675869.83 -539.81 12.00 269.63 MWD 11825.00 92.20 115.96 8687.73 5766.54 86.68 5967040.85 675892.25 -516.56 12.00 269.51 MWD 11850.00 92.17 112.95 8686.78 5756.20 1 09.42 5967031.04 675915.23 -492.87 12.00 269.39 MWD 11875.00 92.13 109.95 8685.84 5747.06 132.67 5967022.45 675938.68 -468.79 12.00 269.28 MWD 11900.00 92.08 106.95 8684.92 5739.16 156.36 5967015.10 675962.55 -444.40 12.00 269.17 MWD 11925.00 92.03 103.95 8684.03 5732.50 180.44 5967009.02 675986.78 -419.76 12.00 269.06 MWD 11950.00 91.97 100.95 8683.16 5727.12 204.84 5967004.20 676011.29 -394.93 12.00 268.95 MWD 11971.91 91.91 98.32 8682.41 5723.45 226.43 5967001.05 676032.96 -373.08 12.00 268.85 10 11975.00 91.91 98.69 8682.31 5723.00 229.48 5967000.66 676036.02 -369.99 12.00 90.00 MWD 12000.00 91.91 101.69 8681.48 5718.58 254.07 5966996.82 676060.71 -345.08 12.00 90.01 MWD 12025.00 91.90 104.69 8680.64 5712.88 278.39 5966991.69 676085.16 -320.29 12.00 90.11 MWD ') ) .Q<bp BP « r,\ù .,::' ,.',"',: ','.~ . Baker Hughes INTEQ Planning Report 1~'tEQ: : Company: BP Amoco Date: 7/7/2003 Time: 16:10:26 P~e: 4 Field: Prudhoe Bay Co-Ordinate(NE) Reference: Well: 15-28, True North Site: PB DS 15 Vertical (TVD) Reference: System: Mean Sea Level Well: 15..28 Section (VS) Rderence: Well (O.00N,0.00E,96.00Azi) WeUpath: Plan#4 15-28A Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey 1\1D loci Azim SSTVD N/S EIW. MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 12050.00 91.89 107.69 8679.82 5705.91 302.39 5966985.29 676109.30 -295.70 12.00 90.21 MWD 12075.00 91.87 110.69 8679.00 5697.70 325.98 5966977.63 676133.08 -271.38 12.00 90.31 MWD 12100.00 91.85 113.70 8678.19 5688.26 349.11 5966968.74 676156.43 -247.38 12.00 90.41 MWD 12125.00 91.82 116.70 8677.39 5677.62 371.72 5966958.63 676179.28 -223.79 12.00 90.51 MWD 12150.00 91.78 119.70 8676.60 5665.82 393.74 5966947.35 676201.57 -200.66 12.00 90.60 MWD 12175.00 91.74 122.70 8675.83 5652.88 415.11 5966934.91 676223.23 -178.05 12.00 90.70 MWD 12200.00 91.70 125.70 8675.08 5638.83 435.78 5966921.36 676244.22 -156.03 12.00 90.79 MWD 12221.91 91.66 128.33 8674.44 5625.65 453.27 5966908.58 676262.01 -137.26 12.00 90.88 11 12225.00 91.66 127.96 8674.35 5623.74 455.69 5966906.74 676264.48 -134.65 12.00 270.00 MWD 12250.00 91.65 124.96 8673.63 5608.89 475.79 5966892.36 676284.92 -113.11 12.00 269.99 MWD 12275.00 91.65 121.96 8672.91 5595.12 496.63 5966879.08 676306.08 -90.93 12.00 269.90 MWD 12300.00 91.64 118.96 8672.19 5582.45 518.17 5966866.92 676327.91 -68.19 12.00 269.82 MWD 12325.00 91.62 115.95 8671.48 5570.93 540.35 5966855.93 676350.34 -44.93 12.00 269.73 TD Nordic 1 big hole All Measurements are from top of Riser 7/10/2003 ~ Q.) en .- cr: top of bag BAG 7 1/16" 5000psi bttm of bag middle of slips Blind/Shears .......................... middle of pipes 2 3/8" combi ram/slips I I TOTs L..............········· 7 1/16" 5000psi .....-. .....-. middle of flow cross Mud Cross Mud Cross 7 1/16" 5000psi '---' '---' middle of blind/shears I variable bore pipe 3 1/2"-27/8" I 2 3/8" combi ram/slips r·· ......................., TOTs I ..................·····7 1/16" 5000psi ..' middle of pipe/slips ~ ~.~~ Flow Tee ~. -' *******$100.00******* AMOUNT NOT VALID ~FTF;.R1?~~;:. (:.\ ::·~·;,:::·:·S::··~·:~ ::':-'.. Y'iì!t:~ CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 Nos P 055088 ---- H NET CHECK NO. 055088 VENDOR DISCOUNT DATE 6/9/2003 III 0 5 5 0 a 8 III ft ~ 0 L. . 2 0 ~ B g 5 I: O. 2 ? 8 g b liD DATE June 9, 2003 NATIONAL CITY BANK Ashland, Ohio \s- J-8.n- GROSS ALASKA OIL &'GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 B P r; ~ ..,... ,,¡H,. <,Ed. ,....J..'} I.i, t'~"I,J ( ,~/ Li"J 'it'S . .~~..I[ ·1., .",. """ ",,,,.,,,. TO THE ORDER OF: PAY: BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK 99519-6612 . . - TOTAL þÞ- THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. PERMIT TO DRILL =EE INV# CK060403H DESCRIPTION INVOICE / CREDIT MEMO 6/9/2003 DATE p055088 ) ) TRANSM1T AL LETTER CHECK'LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production, should continue to be reported as a function' of the original API number, stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated . in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). P~OT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 Ojody\templates The permit is approved subject ,to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) assumes the liability of any protest to the spacing . exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater tban 30' sample intervals from below the permafrost or from where samples are first caught and to' sample iIitervals through target zones. ,v,vELL PERM~TC;HECKLI~T' Company BP_E)(PLQRA TIQ~JALASK,L\) INC Well Name: PRUDHQE E3AY U}~II 15=2,8A Program DEV Well bore seg r l PTD#: 2031240 Field & Pool ERUDH.QE.BAY,PRUDHQE OIL-:6L.to150. Initial ClasslType . DEVLt::QlL. GeoArea .8.9.Q__... Unit JJ650__ On/Off Shore On Annular Disposal Administration 11 P.ßrmit fee attached Y.ßS 12 Lease number appropriate. Yes 13 .U.ni.q\.!e well. n.am.ß .ancj ou.mb.er . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .Y.ß$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , . . . . . . . . . . . . . . I 4 .WellJQcated in.adefinedpool Yes. !5well.lQCated properdi.stance from drilling unit boundary Yes 1 ¡6Well,lQcated pr.operdtstance from otber wells Yes ¡7 S.ufficient .acreageavailable in drilling unit yes i8 If deviated, is. weJlbore platinc.lu.ded Yes 19 Qperator only: ~ffected party Y.ßs '10 .Qper:.ator bas.apprppr[ate. Q,ond tn .fQrce . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Ye$ . . . . . . . . . . . . . . . . . . . . . . . . . . . . _ _ _ _ _ _ _ . . . _ . . . . . . . . . . _ . _ . _ . . . . . . . _ . . . _ . _ _ . . . . . . 11 P.ßrmit can be issued without conservation order. Yes. . Appr Date 12 Permit c.an be tssued witho.ut administrative. approval Yes. RPC 7/14/2003 13 Can permit be approved before 15-daywait Yes 14 .Well.lQcated within area and. strata .authorized by. Injection Order # (putlO# in.comments).(For. NA ( 15 .AJI wel)s. wit.htn.1 ¿4.llJile.are.a.of reyiew jd.ßot[fied (Fp( ~ervjc.ß well 9111y). . . . . . . . . . . . . . . NA. . . . . . _ . . . . . . . . . . . . . . . . . . . . . . . . . _ . . . . . _ _ . _ . . _ . . . . . . . . . . . . _ . _ . . . . . . . . . . . . . . . . 16 Pre-pr9du.ced injector: .duratio.nof pre-:productipn l.ßss. than 3 1')10ntbs. (For.ser:vtce well QnJy) . . NA. 17 ACM.P. Finding .of CQnsi.$tency h.as bee.ni~sued. for. tbis pr.olect NA Engineering Appr Date WGA 7/15/2003 Geology Appr RPC Date 7/14/2003 Geologic Commissioner: D~S ___ n.n.___.__._ ______....._,___.____.,.__..__.. ~"_ __...._..._____.._ -.... -- -....---...--.-.---.- . ._--,-,-,._.,-_.._.,'--_._--~,- -.-------.-.--,,----.------,-...--------,.----..,.-..----.--.------- ---------- -"-----.----. -..--- n_ '__",__'_'__·'__U_". .__.__~_._~__.__________.____.______.___._.___ _.___._ _ __ 18 .C.ondu.ctor string,PJQvided NA. 19 .S.urf~c.ß .casing. PJQtec.ts. all.known. USQW$ . NA 20CMT. v.at adequate.to circulate.on.c9nd.uctor, & sU,rf.c.$g NA . 21 .CMT. v.ol. a.deq u.ate.to tie-in JQng.string to .s\.! rf ç~g, NA , 22 .CMT. wil! cover..allknown.Pfo.d\.!ctive hQrizons. , . . . . . . Yes. 23 .C.asing designs adequate for C,,T, B.&.perroafr.ost Yes. . . 24Ap~qu~te.t~n.kage.of re.s~rye pit yes CTQU.., 25 Jf.are-drill, has..a, 1..o.~4.0;3 Jo.raba,ndonrne.nt be.!:!n apprQved ., Yes. 7/14/20.03. 26 Adl;!qu~te.w.e!lbore. $.epªr~tjo.n.pro.p9$.ep _ . _ _ _ _ . . _ . _ . . . . . . . _ . . . . . . . . . . . . . . Yes. . _ _ _ . _ . . . . . . . . . . . . . . . . . . . . _ . . . . . . . . . _ _ . _ _ _ _ _ . _ . . _ . _ . . . . . . . . . . . . _ _ _ . _ . . . . . . 27 .Ifdjver:ter Jeq.uiJe.d, dQes jt meet. regu.lati9ns. . . . " _ . . . . NA , . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . , 28 .DJilJiog fluid, pfogr~m sc.h!:!l')1ati,c.& eq.uip listadequate Y.ßs . . . Max. MW.8.. 7. ppg. . . 29 .B.OPEs,.dq ,they meet. rl;!guJa.tiol) . Yes 30 .BOP.E.Pfess ratiog ~p.propri~te;test to.(pu.t psig in.comments) . . . . . . . . . .. .Y.ß$_, 31 .C.hok.e.llJanjfold coropJies, w/API. RP-53. (May 84). . Yes, 32 WOJk. will pccur withPLltoperatjon .,shutdown., Y.ßs. 33 .Is pres.ence. oJ H2S gas. prQb.able. . Yes ., 34 Meçba.n[cal.cQnd,ition .of wells within AOR YeriJied (.ForS,ervice welJ on.ly:) NA _ _ _ ~ _ R ~ -( . Te.st to .3500. psi. MS~ 20.96 psi.. -------.-..-.---....-.-.- - -. -- ..,,--,_...~._~-_..,'_._--~ ..--.-.--.--.----..---..-.--. ---'>.-----..- .. . _._.,_.____..._,___ _.__. _.__ ~_. .__..,_.__.._~_..~__ u..___ .___.__,.._..____..___._... 35 P.ßrmit c.an be i,ssu.eq w/o hyqrogen. s.ulfide meaS.ures 36 D.ata.Pfesenteq on pote.ntial OVerpres.sure ,ZOl1e.$. 37 .S.ßi.smic.analysjs Qfsballow gaszooes. 38S.ßabep .condjtiplJ surveY (if off-shore) 39 CQnta.ct. narne/p.hone.forweek.ly prpgr~~sJeports [e?<ploratpryonly]. No NA . .NA NA . NA Date: Engineering Commissioner: Public ,__~~ commiSSioner~~ ~~,. .--:::::-- r ~S Date 7!JS/:;; ') ) Well History File APPENDIX Information of detailed nature that is not particulariy germane to the Well Pennilling Process but is part of the history file. To improve the readability of the Well History file and to sin1plify finding infanllation, infonnation of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ) ) ~03 - / ¿Y-{ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Thu Oct 02 14:03:53 2003 ~ ;2), {) ) Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 15-28A 500292224701 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 02-0CT-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002621480 S. LATZ SARBER/WHITL MWD RUN 2 MW0002621480 S. LATZ SARBER/WHITL MWD RUN 3 MW0002621480 S. LATZ SARBER/WHITL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 4 MW0002621480 S. LATZ SARBER/WHITL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 22 llN 14E 207 34 67.00 # WELL CASING RECORD ';.~,.._ I::~~:-' 1 :'1"'1-' . ~ .~. 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.130 5.000 10702.0 OCT /.:\~:~:~":':'{'U" :;..!i:.L~ ~.< ""l.. # REMARKS: -~.\~; ::~:~~ .:~-~ ~\~: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE ~~""\'\~~ ) ) NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. MWD RUNS 1 - 4 COMPRISED DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. UPHOLE SGRC TIE-IN DATA FROM MWD RUN 3 WERE MERGED WITH RUN 1 DATA. 4. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE (CNL) GAMMA RAY LOG RUN IN 15-28A ON 26 AUGUST 2003. THESE DIGITAL DATA WERE PROVIDED BY K. COONEY (BP) ON 9/30/2003. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 5. MWD RUNS 1 - 4 REPRESENT WELL 15-28A WITH API#: 50-029-22247-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12267'MD/8694'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. $ File Header Service name......... ... .STSLIB.001 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation..... ..03/10/02 Maximum Physical Record. .65535 File Type.. ............. .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10355.0 10712.5 STOP DEPTH 12241. 5 12268.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10355.0 10357.5 10367.0 10371. 0 10374.0 10377.5 10381. 0 10385.0 10388.0 10390.5 10686.5 10688.5 10703.0 10720.5 10733.0 10744.0 10747.5 10751.0 10753.5 10757.0 10758.0 10759.5 GR 10355.0 10357.0 10366.0 10369.5 10372.5 10376.0 10379.5 10384.0 10387.0 10390.0 10684.5 10687.5 10702.0 10719.0 10728.0 10741.0 10747.0 10749.0 10752.0 10755.0 10756.5 10758.0 ) ) 10770.0 10767.0 10780.0 10778.5 10781.5 10780.0 10783.0 10781. 0 10787.5 10784.5 10813.5 10811. 5 10817.0 10815.5 10823.5 10821. 0 10828.0 10827.0 10831.5 10832.0 10840.0 10840.0 10847.0 10847.0 10850.0 10848.5 10866.0 10864.0 10870.0 10869.5 10874.0 10873.0 10880.0 10879.5 10883.5 10884.0 10889.0 10887.5 10890.0 10889.0 10901.0 10902.0 10905.5 10906.5 10910.5 10910.0 10919.5 10921. 5 10929.0 10928.5 10938.0 10938.5 10943.5 10942.5 10946.0 10946.0 10948.0 10948.5 10951.0 10954.0 10958.0 10959.0 10972.0 10971.5 10974.0 10973.0 10980.0 10979.5 10989.0 10990.5 11002.5 11004.5 11016.0 11017.0 11037.5 11035.0 11043.0 11042.0 11048.0 11047.5 11050.5 11051.0 11056.0 11056.0 11063.5 11064.5 11067.5 11067.0 11071.0 11070.0 11077.5 11076.0 11086.0 11084.5 11096.5 11097.5 11110.0 11109.5 11119.5 11119.5 11142.5 11145.0 11144.5 11146.5 11146.0 11148.5 11149.5 11151.0 11162.5 11166.0 11168.5 11171. 5 11173.0 11174.0 11183.5 11185.5 11188.0 11190.5 11209.0 11211.5 11216.5 11216.0 11221.5 11220.5 11224.5 11224.0 11227.5 11227 . 5 11230.0 11229.0 11234.0 11235.0 11237.0 11238.5 11249.5 11248.5 11265.0 11264.5 11270.5 11269.5 11277 . 0 11274.5 11280.5 11279.5 11286.5 11286.0 11293.5 11295.0 11296.5 11297.5 11306.0 11306.5 ') 11310.0 11325.0 11339.0 11341.0 11354.0 11367.5 11380.5 11386.5 11392.5 11408.5 11413.0 11434.0 11444.5 11447.5 11453.5 11460.0 11478.0 11498.5 11512.5 11536.5 11568.5 11576.0 11580.5 11588.5 11593.5 11601.5 11609.5 11616.0 11632.0 11652.5 11657.5 11662.5 11666.5 11673.5 11683.5 11698.5 11709.0 11714.0 11724.0 11727.5 11730.5 11734.0 11741.5 11749.5 11 763.5 11770.0 11777.5 11794.0 11811.0 11827.0 11856.5 11887.0 11901.5 11906.0 11946.0 11951. 5 11956.0 11959.5 11966.0 11984.0 11996.0 12004.0 12022.0 12054.0 12062.5 12064.0 12068.5 12070.5 12082.0 12090.5 12099.5 12104.0 12106.5 12110.5 12124.0 12129.0 11311.0 11325.5 11339.5 11341.5 11352.5 11363.0 11376.5 11382.5 11389.5 11405.0 11410.0 11429.5 11439.0 11442.5 11450.0 11460.0 11476.5 11495.5 11509.0 11534.0 11564.5 11574.0 11580.0 11585.5 11591.0 11597.0 11608.0 11616.0 11633.5 11654.5 11658.0 11663.0 11666.0 11671.0 11683.0 11699.0 11709.0 11715.5 11726.0 11728.5 11731.5 11735.5 11740.0 11746.5 11758.5 11766.0 11776.0 11792.5 11811.0 11827.5 11860.0 11889.5 11904.0 11908.5 11947.5 11952.0 11958.0 11960.0 11966.0 11983.5 11995.5 12002.5 12022.0 12050.5 12060.0 12061. 5 12067.0 12071. 5 12081.5 12090.0 12097.5 12102.5 12105.5 12109.5 12126.5 12130.0 ") ') 12140.0 12147.0 12164.5 12183.0 12186.5 12191. 5 12196.5 12268.5 $ 12142.0 12148.5 12162.5 12181. 5 12185.0 12190.5 12195.5 12267.5 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD $ BIT RUN NO 1 2 3 4 MERGE TOP 10355.0 10794.0 11080.0 11382.0 MERGE BASE 10794.0 11080.0 11382.0 12267.5 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing................ .... .60 .1IN Max frames per record........... ..Undefined Absent value..................... .-999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD GR MWD Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10355 12268.5 11311.8 3828 10355 12268.5 ROP MWD FT/H 0.38 687.36 86.2945 3113 10712.5 12268.5 GR MWD API 17.7 245.12 55.4663 3207 10355 12241. 5 First Reading For Entire File...... ....10355 Last Reading For Entire File.......... .12268.5 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/10/02 Maximum Physical Record..65535 File Type............... .LO Previous File Name. .... ..STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 ) RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ ') header data for each bit run in separate files. 1 .5000 START DEPTH 10355.0 10711.0 STOP DEPTH 10765.5 10794.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN); # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.. .............. ..0 Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units.......... .Feet Data Reference Point............ ..Undefined Frame Spacing.......... .......... .60 .1IN Max frames per record.... ........ .Undefined Absent value...... .............. ..-999 Depth Units.... . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 22-AUG-03 Insite 4.3 Memory 10794.0 10711. 0 10794.0 10693.0 10769.0 TOOL NUMBER 93091 4.130 10702.0 Flo Pro 8.60 65.0 9.0 21000 7.0 .000 .000 .000 .000 .0 121. 0 .0 .0 Name Service Order DEPT ROP MWD010 GR MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) Name Service Unit DEPT FT ROP MWD010 FT/H GR MWD010 API Min 10355 0.38 17.7 Max 10794 186.21 245.12 First Reading For Entire File......... .10355 Last Reading For Entire File.......... .10794 File Trailer Service name........... ..STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/10/02 Maximum Physical Record. .65535 File Type... ...... ...... .LO Next File Name......... ..STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number... ...... ..1.0.0 Date of Generation...... .03/10/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 Mean 10574.5 28.7622 52.1947 Nsam 879 167 258 ) First Reading 10355 10711 10355 Last Reading 10794 10794 10765.5 header data for each bit run in separate files. 2 .5000 START DEPTH 10766.0 10794.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: STOP DEPTH 11058.0 11080.0 22-AUG-03 Insite 4.3 Memory 11080.0 10794.0 11080.0 53.7 89.3 TOOL NUMBER 72829 4.130 10702.0 Flo Pro 8.60 65.0 9.0 ) MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: 21000 7.0 .000 .000 .000 .000 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type........... .......0 Data Specification Block Type.....O Logging Direction........ ........ . Down Optical log depth units.......... .Feet Data Reference Point.......... ....Undefined Frame Spacing................ .....60 .1IN Max frames per record........ .... .Undefined Absent value................. .... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H GR MWD020 API Min 10766 2.45 19.45 Max 11080 328.46 140.2 Mean 10923 91.6713 36.4956 Nsam 629 572 585 First Reading For Entire File.... ..... .10766 Last Reading For Entire File...... .... .11080 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/02 Maximum Physical Record. .65535 File Type........ ....... .LO Next File Name.. .... .... .STSLIB.004 Physical EOF File Header Service name... ........ ..STSLIB.004 Service Sub Level Name... Version Number... ....... .1.0.0 Date of Generation..... ..03/10/02 Maximum Physical Record. .65535 File Type......... ...... .LO Previous File Name.. .... .STSLIB.003 ) .0 131.0 .0 .0 First Reading 10766 10794.5 10766 Last Reading 11080 11080 11058 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. ) BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 3 .5000 START DEPTH 11058.5 11080.5 STOP DEPTH 11354.0 11382.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record...... ...... .Undefined Absent value...................... -999 Depth Units... . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ') 23-AUG-03 Insite 4.3 Memory 11382.0 11080.0 11382.0 88.5 93.8 TOOL NUMBER 72829 3.750 10702.0 Flo Pro 8.60 65.0 9.0 20000 9.6 .000 .000 .000 .000 .0 141.0 .0 .0 Name Service Order DEPT ROP MWD030 GR MWD030 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last ) Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API Min 11058.5 3.16 24.9 Max 11382 175.54 179.77 Mean 11220.3 86.5289 52.0635 Nsam 648 604 592 First Reading For Entire File......... .11058.5 Last Reading For Entire File.......... .11382 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/10/02 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number..... .... ..1.0.0 Date of Generation. ..... .03/10/02 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 5 header data for each bit run in separate files. 4 .5000 START DEPTH 11354.5 11382.5 STOP DEPTH 12240.5 12267.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 25-AUG-03 Insite 4.3 Memory 12267.0 11382.0 12267.0 86.2 95.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 72829 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10702.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): Flo Pro 8.70 65.0 8.5 20000 8.2 ) Reading 11058.5 11080.5 11058.5 Reading 11382 11382 11354 ) ') RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: .000 .000 .000 .000 .0 141.4 .0 .0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type.... ....... .......0 Data Specification Block Type.....O Logging Direction.......... ...... . Down Optical log depth units........ ...Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value.. ....... ....... ..... .-999 Depth Units....................... Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD040 GR MWD040 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11354.5 12267.5 11811 1827 11354.5 12267.5 ROP MWD040 FT/H 0.62 687.36 90.1607 1771 11382.5 12267.5 GR MWD040 API 24.61 167.15 62.5035 1773 11354.5 12240.5 First Reading For Entire File......... .11354.5 Last Reading For Entire File..... .... ..12267.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation... ... .03/10/02 Maximum Physical Record. .65535 File Type........... .... .LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/02 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name........... .... . UNKNOWN Continuation Number..... .01 Next Tape Name....... ... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name. .... .... ... .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/10/02 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name.... ......... ...UNKNOWN Continuation Number.... ..01 Next Reel Name...... .... . UNKNOWN ) ) Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
