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Home My WebLink About199-057• STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ^ Oil ^ Gas ^ SPLUG ^ Other ®Abandoned ^ Suspended 1b. Well Class: zoAAC zs.~os zoAAC zs.»o ^ Development ^ Exploratory ^ GINJ ^ WINJ ^ WAG ^ WDSPL ^ Other No. of Completions Zero ®Service ^ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: .Permit to Drill Number: BP Exploration (Alaska) Inc. 6/1/2010 199-057 310-096 3. Address: 6. Date Spudded: .API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 07/08/1999 50-029-20341-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 4. Well Name and Number: Surface: ' ' 09/04/1999 PBU B-13A 1740 FNL, 1608 FEL, SEC. 31, T11 N, R14E, UM g, KB (ft above MSL): 64 16' 15. Field /Pool s ()~ Top of Productive Horizon: . 3871' FNL, 868' FEL, SEC. 36, T11 N, R13E, UM GL (tt above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD+TVD): Oil Pool 5105' FNL, 318' FEL, SEC. 36, T11 N, R13E, UM 2824' 2824' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD+TVD): 16. Property Designation: Surface: x- 664051 y_ 5948910 Zone- ASP4 12245' 8969' ADL 028310 & 028286 TPI: x- 659837 y- 5946688 Zone- ASP4 11 • SSSV Depth (MD+TVD): 17. Land Use Permit: Total Depth: x- 660413 Y- 5945466 Zone- ASP4 N/A 18. Directional Survey: ^ Yes ®No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): Submit electronic and rinted information r 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 MDlTVD: MWD, GR, ROP, Memory Induction 10605' 8805' 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.. 30" x 2 Insul e n r rf 110' rf 1 6" 454 cu ft Perm fr 1 -/" 2# rf 17-1/" 7 f II 9- /8" 47# L-80 10364' 2 0' 1' 12-1/4" 106 cu ft I 00 cu PF' ' 7-5/8" 29.7# NT- 241' 44' 2 -1/2" 230 c ft Clas i ack 7,. ~ ~ _ / " 17 I 2-7/ " 6.16# L- 1 2 1' 121 24' -3/4" 393 u ft Cla ' 24. Open to production or injection? ^ Yes ®No 25. TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD / TVD 5-1/2", 17#, NT80S 3187' - 9785' MD TVD MD TVD 4-1 /2", 12.6#, L-80 9785' - 10567' sao7~ i s2a3~ & 10538 ~ 87s7' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ~~ :, y~ `~ ~ ~ ; DEPTH INTERVAL MD AMOUNT AND KIND OF MATERIAL USED 9416' P&A w/ 26.3 Bbls Class 'G' 3184' Set Posiset Plug & 10' of Cement of Top of Plug 2852' Set EZSV 2824' 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 (CORK): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ^ Yes ®No Sidewall Core(s) Acquired? ^ Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize litholog f r water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory e C 250.071. ~~u~.. ~ zoo None ~~sska ~~! Et ~; ~~~.~ ~©rmnissian RBDMS JUL 4 7 Z0~ . Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ~ ~_ ~ _~ c~ T~~~bmit Original Only 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. RMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Sadlerochit 10600' 8801' None 45N 10632' 8823' 45P 10636' 8826' 44N 10729' 8878' 44P 10734' 8881' 43N 10792' 8901' 43P 10798' 8903' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,^~ V 701v~j d Signed: Terrie Hubble Title: Drilling Technologist Date: PBU B-13A 199-057 310-096 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Permit No. /Approval No. Drilling Engineer: Maria Medvedeva, 564-5786 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only B-13A, Well History (Pre Rig Sidetrack) Date Summary 4/6/2010 WELL S/I ON ARRIVAL. DRIFT WITH 5.93 GAUGE RING TO 7" INSERT AT 2,085' SLM / 2,112' MD. JAR 1 HR ON 7" INSERT AT 2,088' SLM / 2,112' MD. PULL 4.5 XX- PLUG FROM 9,770' SLM / 9,798' MD. MADE TWO ATTEMPTS TO PULL 7" INSERT FROM 2,085' SLM / 2,112' MD. (JAR TIME 2 HRS) (CURRENTLY JARRING ON 7" INSERT.) 4/7/2010 JARRED FOR -5 HRS AT 1800-2000#'s ON 7" HES INSERT C«~ 2,085' SLM / 2,112' MD. LRS PUMPED 580 BBLS KCL & 114 BBLS 60/40 METH TO FREEZE PROTECT. RIG DOWN SLICKLINE & RIG UP BRAIDED LINE TO PULL 7" HES INSERT. CURRENTLY JARRING ON 7" HES INSERT C~ 2,088' BLM W/ 7" GS. 4/7/2010 T/I/0=500/0+/0 (Infectivity Test w/ SLB) Pumped 14 bbls 60/40 meth down TBG followed by 554 bbls 1%KCL, established injection rate of 5 bpm @ 800 psi for last 291 bbls of 1%KCL. Freeze protected TBG w/ 100 bbls of 70° 60/40 meth. FWP's=Vac/0/280 4/8/2010 JARRED -3.5 HRS AT 3800-4000#'s ON 7" HES INSERT C~3 2,112' MD W/ BRAIDED LINE (No movement). UNABLE TO APPLY ENOUGH PRESSURE TO TUBING FOR EXTRACTION (See log). INSTRUCTED BY REP TO RDMO UNTIL NEW PLAN CAN BE PUT TOGETHER. WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS. 4/12/2010 T/IA/OA= SSV/0/0 Temp=Sl PPPOT-T (PASS) PPPOT-IC (PASS) (Pre RST) PPPOT-T : RU 1 HP BT onto THA 10+ psi, bled to 0 psi. Flushed void until clean returns achieved, pressured void to 5000 psi for 30 minute test, 5000/ 15 minutes, 5000/ 30 minutes. Bled void to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition. RD all test equipment. PPPOT-IC : RU 1 HP BT onto IC 10+ psi bled to 0 psi. Flushed void until clean returns achieved, pressured void to 3500 psi for 30 minute test, 3500/ 15 minutes, 3500/ 30 minutes. Bled IC void to 0 psi, cycle and torque LDS "Standard" all were in good working and visual condition. RD all test equipment. 4/15/2010 T/I/0= 1740/O+Nac. Temp=Sl. Depress TBG FL below SSSV (RWO prep). TBG FL C~ 960'. Depress TBG FL to 1296' with AL gas from B-12 (3 hrs). ALP= 1820 psi. Final WHPs=1810/O+Nac. 4/16/2010 WELL S/I ON ARRIVAL. SET 4-1/2" XRO PLUG IN 7" HES INSERT C«? 2,087' SLM / 2,112' MD. RAN 7" GR TO 7" HES INSERT C~3 2,087' SLM / 2,112' MD. OPEN LOCK. BLEED TBG DOWN FROM 1650 TO 640 psi (SWAPPED TO FLUID). RAN RX TO 7" HES INSERT ~ 2,112' MD. SHUT LOCK. RAN 4-1/2" GR & X-EO. DEVICE, PULL 4-1/2" XRO PLUG FROM 7" HES INSERT Q 2087' SLM / 2112' MD. DRIFTED TO 3600' SLM W/ 3.80" CENTRALIZER & SAMPLE BAILER (no problems). RDMO. 4/22/2010 WELL SHUT IN ON ARRIVAL. MIRU. JAR DOWN ON 7" INSERT AT 2,087' SLM WJ 7" RX FOR 1 HR. SET 4 1/2" RX LOCK W/ PRT LATCHING EXTENSION C~ 2,090' SLM. RAN 7" GR TO VERIFY LOCK IS OPEN. SET 4 1/2" BAIT SUB W/ PRT PULLING TOOL IN RX LOCK C~ 2087' SLM. JAR ONE HR ON 7" INSERT AT 2,087' SLM / 2,212' MD (NO MOVEMENT). RIG DOW N SLICKLINE. CURRENTLY RIGGING UP B/L. 4/23/2010 JAR ON 7" INSERT AT 2,089' BLM / 2,012' MD FOR 15 MIN AT 3000#. (SHEARED PRT) ATTEMPTED TO SET PRT PULLING TOOL AT 2,089' BLM (unable to latch). RAN 7" GS TO VERIFY LOCK IS OPEN AT 2,087' BLM. ATTEMPTED TO SET PRT PULLING TOOL AT 2,089' BLM. (unable to latch) RAN 7" GS W/ 5' PRONG TO VERIFY LOCK IS OPEN AT 2,087' BLM. ATTEMPT TO SET PRT PULLING TOOL AT 2,089' BLM (unable to latch). RAN 7" GR TO VERIFY LOCK IS OPEN AT 2,087' BLM. SET 4-1/2" BAIT SUB W/ PRT PULLING TOOL AT 2,089' BLM. 4/24/2010 JAR ON 7" INSERT AT 2,089' BLM / 2,112' MD FOR 1 HR AT 4000# (sheared prt). SET BAITED 4-1/2" PRT AT 2,089' BLM. JAR FOR 2 hrs AT 4000# ON PRT C~3 2089' BLM (no movement, PRT sheared). PULLED 4-1/2" X-LOCK WITH PRT EXTENSION FROM 7" INSERT C~ 2087' BLM. RAN RX RUNNING TOOL TO CLOSE LOCK ON 7" INSERT. RAN 3.80" DRIFT TO 4000' BLM (no restrictions). WELL LEFT S/I, DSO NOTIFIED. Page 1 of 2 • B-13A, Well History (Pre Rig Sidetrack) Date Summary 5/3/2010 Fullbore P & A Pumoed 335 bbls of 1 % KCL 10 bbls of Chemi~l wash 100 26 3 bbls of 15.8 nno"G"._ Cmt 7 bbls clean. 13 bbls w/ agregate, 6.3 bbls clean CmU, 2 bbls H2O, Drop 8" sponge ball, 5 bbls H2O. Displace with 262.3 diesel. CIP= 14:00 hrs. TOC= 9416' MD /SLM. 5/5/2010 WELL SHUT IN ON ARRIVAL. DRIFTED TUBING WITH 3.70" CENTRALIZER, 10' OF 2" DUMMY PERF GUN, 3.67" SWAGE & 3.00" SAMPLE BAILER. TAGGED TOP OF CEMENT C~ 9416' SLM, BAILER RECOVERED CEMENT. MIT-T TO 2500 PSI (PASSED). WELL LEFT SHUT IN DSO WALK THROUGH UPON DEPARTURE. 5/6/2010 INITIAL T/ I/ O = 500/ 0/ 0 PSI. LOGGED RST -GRAVEL PACK FROM 2900' TO 9427' MD. DID NOT FIND ANY FILL IN IA. SHOT 2" HSD 2006 PF HMX, 6 SPF, 60 DEG PHASING FROM 9355' - 9365'. LRS CIRCULATING BRINE THROUGH TUBING AND IA - IN PROGRESS. 5/7/2010 SET 5-1/2" POSISET PLUG AT 3194' TOP OF SEALING EL FMEN~ _DUMPED 10' OF CEMENT_QN TOP OF PLUG. TOP OF CEMENT AT 3184'. BAILERS CAME BACK EMPTY. FINAL PRESSURES 0/0/0. JOB COMPLETE. 5/12/2010 RIH tag cement plug C~3 3181' ctm. PUH 0.5' Start cutting tubing. Cut tubing, circulate,_in 9~8# brne,_ freeze protect 200' IA & tubing. POOH. Blow down CT with N2. RDMO. Job complete. 5/17/2010 MIT OA 2000 psi -- PASS. Pumped 2.4 bbls crude down OA to test. OA lost 130 psi in 15 min's, 20 psi in 2nd 15 min's, for a total loss of 150 psi in 30 min's. Bled back approx 1.4 bbls. FWHP's=BPV/0/0 Page 2 of 2 North America -ALASKA - BP Page 1 p;~ Operation Summary Report -- __-- Common Well Name: B-13 AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/20/2010 End Date: 5/23/2010 X3-OOTW7-C (791,984.00 ) I Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date(Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) ~ (ft) ____ _ _ 5/20/2010 00:00 - 12:00 12.00 MOB N WAIT PRE WAIT ON WEATHER -WAITING ON SECURITY - WINDS IN EXCESS OF 30 MPH -WAITING ON SNOW REMOVAL ON B-PAD ___ 12:00 - 15:00 3.00 MOB N WAIT PRE ALL RIG MOVES DELAYED DUE TO WEATHER WAITING ON SECURITY ESCORT -SECURITY NOTIFIED @ 11:00 HRS j i - 7ES RIG MOVE IN PROGRESS _ 15:00 - 00:00 9.00 j MOB P __ PRE MOVE RIG TO B-PAD i -WITH SECURITY ESCORT - 17 MILE MOVE 5/21/2010 00:00 - 05:30 5.50 MOB P PRE MOVE RIG TO'B-PAD' _.,..~. ~ ~ -WITH SECURITY ESCORT ~ - t7 MILE MOVE 05:30 - 06:30 1.00 MOB P PRE HOLD AT PUP STATION #1 INTERSECTION PER SECURITY _ 06:30 - 09:30 3.00 MOB P PRE MOVE RIG FROM PUMP STATION #1 TO B-PAD 09:30 - 12:00 2.50 MOB ° N WAIT PRE WAIT ON PAD PREP ~ -REMOVE BOOSTER -INSTALL MOUSEHOLE ~ -HANG CELLAR DOORS -GLYCOL HEATERS _ __ 12:00 - 00:00 12.00 MOB N WAIT PRE WAIT ON PAD PREP - -INSTALL #2 CONVEYOR - REPLACE PIT #4 GUN LINE -REPLACE HANGING ARM ON MU SIDE OF RIG TONGS -INSPECT SAVER SUB ~ -WORK ON PIT SENSOR - CALLIBRATE TOTCO SLIPS MODE -INSTALL STEAM TRAP ON THE RIG FLOOR - WORK ON ACCUMULATOR UNIT -REMOVE FRONT STAIRS 5/22/2010 00:00 - 08:30 8.50 MOB N WAIT PRE WAIT ON EQUIPMENT FOR PAD PREP - DIRT WORK BEING DONE TO LEVEL B-13 - PERFORM RIG MAINTENANCE -ORGANIZE & INVENTORY TOOL CABINETS ~ -PULL 2 LINKS OFF OF CONVEYER AND i TIGHTEN -INSPECT DRAW WORKS HI 8 LOW DRUM i -PERFORM DERRICK INSPECTION 08:30 - 10:30 2.00 MOB P PRE ( SPREAD HERCULITE AROUND WELL LAY RIG MATS AROUND WELL SIMOPS: ~ ~ -CUT PAD EYES OFF OF RIG EQUIPMENT Printed 6/1/2010 11:53:14AM >i i' ~ North America -ALASKA - BP Page 2 s~ Operation Summary Report -_ _ ___ Common Well Name: B-13 AFE No Event Type: MOBILIZATION (MOB) Start Date: 5/20/2010 ~ End Date: 5/23/2010 X3-OOTW7-C (791,984.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud DatelTime: ~ Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations __ __ (hr) (ft) 10:30 - 16:00 5.50 i MOB P PRE ___ _ SKID RIG ONTO MATTING BOARDS j SPOT RIG OVER WELL SHIME UP & LAY MATS SPOT THE ROCKWASHER DRY RUN VAC TRUCK UNDER RIG RIG UP ROCKWASHER SPOT FUEL TANK, MWD SHACK, & BLEED TANK 16:00 - 16:30 0.50 MOB P PRE' pRE-JOB SAFETY MEETING SKID RIG FLOOR RIG UP FLOOR AND LINES 16:30 - 17:00 0.50 MOB P PRE . PREP PITS TO TAKE ON BRINE PREP MUD PUMPS 17:00 - 22:00 5.00 RIGU P PRE _ TAKE ON 9.8 PPG BRINE INTO PITS RLGACCEPT @ 17:OONRS ON 05/22!2010 INSTALL DOUBLE ANNULUS VALVES ON OA & IA, PUMPiN SUB ON THE WING VALVE -.TUBING PRESSURE = 0 PSI -1A PRESSURE = 0 PSI - OA PRESSURE = 250 PSI 22:00 - 23:00 t.00 RIGU P PRE ____ RIG UP HARDLINE CREW TEST LINES - 1,000 PSI, 5 MIN ~ BLEED 250 PSI FROM THE OA -- BLEED OFF LINES - 23:00 - 23:15 0.25 - RIGU. - P - PRE ~ PRE-JOB SAFETY MEETING 23:15 - 00:00 0.75 i RIGU. P PRE PRESSURE TEST OA - 2,000 PSI, 30 MIN _ __ _ ___ -GOOD TEST ____ 5/23/2010 00:00 - 01:00 1.00 RIGU P PRE PRESSURE TEST OA - 2,000 PSI, 30 MIN -GOOD TEST Printed 6/1/2010 11:53:14AM North America -ALASKA - BP Pace 1 ~t Operation Summary Report ___ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 j End Date: X3-OOTW7-C (3,142,752.00 ) - ~ -- Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ~ Phase Description of Operations (hr) (ft) 5/23/2010 01:00 - 01:15 0.25 BOPSUR P DECOMP pRE-JOB SAFETY MEETING WITH DSM FOR LUBRICATING OUT BPV 01:15 - 03:00 1.75 BOPSUR P DECOMP RIG UP DSM AND LUBRICATOR ~ TEST LUBRICATOR - 500 PSI, 5 MIN TO CHECK FOR LEAKS - NO LEAKS LUBRICATE OUT BPV _ ~ ~ ; RD DSM ___ _ ___ 03:00 03:15 __ __ 0.25 _ BOPSUR P DECOMP ' pRE-JOB SAFETY MEETING ON CIRCULATING ' OUT FREEZE PROTECT 03:15 - 06:30 3.25 BOPSUR P DECOMP R IR AT T 25 BBLS OF DIESEL DOWN IA WITH 9.8'PPG BRINE - 3 BPM, 230 PSI - TAKING RETURNS OUT TUBING TO OPEN TOP ~ TANK ~ BLOW DOWN LINE, LINE UP TO PUMP DOWN ~ TUBING ~ CIRCULATE OUT 56 BBLS OF DIESEL DOWN i TUBING WITH 9.8 PPG BRINE - 4 BPM, 300 PSI -TAKING RETURNS OUT IA TO OPEN TOP TANK BLOW DOWN ONES, RIG DOWN LINES SIM-OPS: CHANGE OUT TOP PIPE RAMS TO 4-1/2" X 7" VBRS ______ 06:30 - 07:00 0.50 BOPSUR P DECOMP FLOW CHECK ~ -STATIC SET TWC _ _ 07:00 - 09:30 2.50 ~ BOPSUR P DECOMP FILL TREE j TEST TWC FROM BELOW WITH ROLLING TEST - 2 BPM, 650 PSI, SHUT DOWN PUMPS, PRESSURE STABILIZED @ 300 PSI TEST TWC FROM ABOVE - 4,000 PSI, 10 MIN -LEAK LOCATED ON SWAB VALVE FLANGE TIGHTEN FLANGE AND RE-TEST -GOOD TEST _ ___ __ __ _ _ ___ 09:30 - 14:00 ~ 4.50 ___ BOPSUR __ P DECOMP MU SAFETY VALVE & CROSSOVER TO 7" FOR WELL CONTROL CHANGE OUT BLIND RAMS TO BLIND SHEAR i RAMS - CLEAN AND INSPECT WEAR PLATES, DOOR SEALS, CLEAN OUT BODIES, -GREASE & INSTALL NEW BLIND SHEARS -CLOSE DOORS AND TORQUE UP SIMOPS: CHANGE OUT SUCTION PLATEFOR PUMP #1 INSIDE PIT #4 TEST GAS ALARMS ON RIG Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page 2 qf~C Operation Summary Report Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs j Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:00 - 16:30 ~ 2.50 BOPSUR P _ DECOMP SUCK OUT TREE ~ BREAK TREE ATADAPTOR/SPOOL PLUG HOLES WITH ABSORB AND TAPE BAGS TO FLANGES REMOVE FROM CELLAR REMOVE EXTRA BLINDS FROM CELLAR RE-TOQUE LOCK DOWN SCREWS AND GLAND ~ NUTS i INSPECT TUBING HANGER THREADS, SCREW 7" IJ4S THREADS INTO TBG HANGER 6 3/4 TURNS 6:30 - 20:30 4.00 BOPSUR _ P DECOMP _ INSTALL 3' S TURNBUCKLES, CHOKE LINE, RISER, FLOW LINE, i BLEED OFF LINE, HOLE FILL LINE, FLOW LINE _ COVERS, AND GLAND NUTS 20:30 - 00:00 3.50 BOPSUR P DECOMP _ TEST BOPS. - 4,000 PSI HIGH, 250 PSI LOW -,UPPER RAMS (4-1/2" X 7") W/ 7" TEST JOINT VALVES t,2,4,5,6,7,8,9,10,11,12,13,14 -UPPER IBOP ON TOP DRIVE .TEST WITNESSED BY BP WSL ZACH SAYERS , ~ DOYON TP TOM SHONES ~ AOGCC WITNESS WAIVED BY JOHN CRISP ~ TEST MUD PUMP POP OFF - #1 MP= 830 PSI - #2 MP= 1,020 PSI OA PRESSURE = 150 PSI 5/24!2010 00:00 - 03:30 3.50 BOPSUR P DECOMP CONTINUE TESTING BOPE - 4,000 PSI HIGH, 250 PSI LOW, 5 MIN EACH - CHOKE & KILL LINE, BLIND SHEARS, KILL LINE VALVE, - LOWER RAMS (3-1/2" X 6") W/ 4" TEST JOINT ~ - VALVE 3 - TIW DART VALVE ~ -ANNULAR PREVENTOR TO 2,500 PSI HIGH, 250 PSI LOW -ACCUMULATOR TEST TEST WITNESSED BY BP WSL ZACH SAYERS , DOYON TP TOM SHONES ___ _ AOGCC WITNESS WAIVED BY JOHN CRISP 03:30 - 04:00 0.50 BOPSUR P DECOMP BACK OUT TEST JOINT AND LAY DOWN. __ RIG DOWN TEST LINES AND EQUIPMENT 04:00 - 06:00 2.00 PULL P DECOMP __ PU DSM LUBRICATOR EXTENSION & TOOLS ' RU 8 TEST TO 500 PSI FOR 5 MIN - NO LEAKS PULL TWC - WELL WENT ON A VAC (TOOK 12 BBLS TO I FILL UP) FLOW CHECK I -STATIC RD & LAY DOWN DSM TOOLS ~Q ~~;~ ~g%I1~ /~~ Printed 6/1/2010 11:53:51AM r~ ~~ North America -ALASKA - BP Page 3 ~ Operation Summary Report _ __ Common Well Name: B-13 ' AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 i End Date: X3-OOTW7-C (3,142,752.00 ) _ -~ - Project: Prudhoe Bay Site: PB B Pad ! Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. _ UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 08:00 2.00 i PULL P DECOMP RU SPOOLING UNIT, POWER TONGS, HANDLING TOOLS TO 7-1/2" X 5-1/2" SAFETY, VALVE & CROSS-OVER, 1 JOINT OF 4" __ _ _ _ DP W/CROSS-OVER TO 7" IJ4S 08:00 - 08:15 0.25 PULL P _ DECOMP PRE-JOB SAFETY MEETING ON PULLING TUBING 08:15 - 08:30 0.25 PULL P DECOMP SCREW INTO HANGER WITH TOP DRIVE 08:30 - 09:00 0.50 PULL P DECOMP ~ USE RIG VAC TO EMPTY STACK 09:00 - 09:30 0.50 PULL P DECOMP PULL TUBING -TUBING CAME FREE AT 120K OVERPULL _. _ PULL TUBING HANGER ABOVE RIG FLOOR 09:30 - 11:00 1.50 PULL P DECOMP CIRCULATE BOTTOMS UP - 4 BPM, 70 PSI MONITOR WELL I -WELL U-TUBING CIRCULATE BOTTOMS UP ! i - 10 BPM, 300 PSI MONITOR WELL - -- --- - WELL STATIC 11:00 - 11:30 0.50 PULL , P DECOMP LAY-DOWN HANGER ____ __ BLOW DOWN TOP DRIVE 11:30 - 12:00 0.50 PULL P DECOMP LAy DOWN 7", 26#, L-80 IJ4S TUBING FROM 3,181' TO 2,782' ___ __ _ - 10 JTS 12:00 - 12:30 0.50 PULL. P DECOMP SERVICE AND INSPECT TOP DRIVE, BLOCKS, __ __ AND DRAW WORKS 12:30 - 18:30 6.00 PULL P DECOMP LAY DOWN 7", 26#, L-80 IJ4S TUBING FROM 2,782' TO SURFACE - LAY DOWN CONTROL LINE SPOOL - 22 SS BANDS RECOVERED (30 EXPECTED) ____ _ -CUT JOINT = 19.38' LONG 18:30 - 19:30 1.00 PULL P DECOMP CLEAN CASING TOOLS ~ CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED ____ FOR UPCOMING OPERATIONS 19:30 - 20:00 0.50 PULL P DECOMP ___ INSTALL WEAR BUSHING 20:00 - 20:15 0.25 PULL P DECOMP PRE-JOB SAFETY MEETING ON PICKING UP DRILL PIPE 20:15 - 23:00 2.75 PULL P _ DECOMP PU 4" DP FROM PIPESHED SINGLING IN HOLE _ _ FROM SURFACE TO 2,400' 23:00 - 00:00 1.00 PULL P DECOMP POOH RACKING BACK STANDS FROM 2,400' TO 6' 5/25/2010 00:00 - 00:30 0.50 PULL P _ DECOMP SERVICE RIG -GREASE BLOCKS, -INSPECT PINS, SAFETY WIRING, & FLUID LEVELS 00:30 - 00:45 0.25 PULL P DECOMP PRE-JOB SAFETY MEETING 00:45 - 02:30 1.75 PULL P DECOMP RIH WITH 4" DP FROM SURFACE TO 2,279' MD - PICKING UP SINGLES 02:30 - 03:45 ! 1.25 PULL P DECOMP POOH STANDING BACK 03:45 - 04:30 0.75 PULL P DECOMP PU BAKER TOOLS TO RIG FLOOR 04:30 - 05:00 0.50 PULL P DECOMP CHANGE OUT ELAVATORS & SLIPS TO HANDLE I 5" TOOLS Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page a oi~F Operation Summary Report Common WeII Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud DatelTime: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 06:30 __ 1.50 CLEAN P _ DECOMP MU 9-5/8" CLEAN OUT BHA - 8-1/2" BIT - (2) BOOT BASKETS -MILL -BUMPER SUB -CROSS OVER i -DRILL COLLARS ~ - HWDP 06:30 - 10.00 _ 3 50 _ CLEAN P _ ~ DECOMP RlH PICKING UP SINGLES FROM 856' TO 3,137 10:00 - 10:30 0.50 CLEAN P ~ DECOMP SLACK OFF TO TAG TUBING STUB AT 3,187 SETDOWN 5K PU & RE-CONFIRM - PUW - 123K, SOW - 125K' ___ _____ _ 10:30 - 11:30 1.00 CLEAN P DECOMP POOH 2 STANDS FRAM 3,187 TO 2,947 CIRCULATE 35 BBLS SAFE SURF O SWEEP - 10$PM, 880 PSI - RECIPRICAT PIPE WHILE PUMPING - ------- 11:30 - 12:00 0.50 i CLEAN P DECOMP ~ gLOW DOWN TOP DRIVE i i ` ~ - MONITOR WELL =STATIC 12:00 - 12:30 0.50 CLEAN P DECOMP SERVICE & INSPECT TOP DRIVE, BLOCKS, & DRAWWORKS 12:30 - 14:00 ~ 1.50 CLEAN P DECOMP POOH FROM 2,947 TP 2T MD 14:00 - 14:30 0.50 CLEAN P DECOMP LAY DOWN CLEAN OUT BHA - 8-1/2" BIT - (2) BOOT BASKETS -MILL -BUMPER SUB I -CROSS OVER _ _ _ _ _ 1 __ 4:30 - 15:30 1.00 CLEAN __ P __ DECOMP CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED ~ FOR UPCOMING OPERATIONS _ 15:30 - 15:45 0.25 CLEAN P _ __ DECOMP PRE-JOB SAFETY MEETING WITH SLB E-LINE 15:45 - 17:30 1.75 CLEAN ~ P DECOMP RIG UP E-LINE AND DUTCH SYSTEM TEST TO 500 PSI - NO LEAKS 17:30 - 20:30 3.00 CLEAN P DECOMP RIH WITH E-LINE TO 2,900' CALIBRATE DEPTHS AND SET EZSV -TOP OF EZSV SET AT 2,866' MD _ _ 20:30 22:30 2.00 CLEAN P DECOMP POOH WITH E-LINE "~"'~ RIG DOWN E-LINE UNIT Printed 6/1!2010 11:53:51AM North America -ALASKA - BP Page 5gf~ Operation Summary Report -- -__ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5123/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) _ __ 22:30 - 00:00 1.50 __ CLEAN P DECOMP RIG UP TEST EQUIPMENT TEST 9-5/8" CASING AND EZSV 0'' - CLOSED BLIND SHEAR RAMS FIRST ATTEMPT - LOST 300 PSI IN 5 MIN SECOND ATTEMPT -LOST 400 PSI IN 15 MIN THIRD ATTEMPT -LOST 400 PSI IN 15 MIN - HAVEATTEMPTED TO SET BLINDS USING 800, 1,200, & 1,500 PSI OA PRESSURE = 180 PSI 5/26/2010 00:00 - 00:15 0.25 CLEAN C DECOMP PRE-JOB SAFETY MEETING 00:15 - 01:00 0.75 CLEAN C DECOMP MAKE UPBIT, BIT SUB (WITH FLOAT), CROSS OVER, DRILL COLLARS, &HWDP 01:00 - 03:30 2.50 CLEAN C DECOMP RIH FROM 832' TO 2,500' -PICKING UP 4" DP SINGLES _ 03:30 - 04:00 i 0.50 CLEAN C DECOMP RIG UP TEST EQUIPMENT 04:00 - 05:30 1.50 CLEAN C DECOMP 'RE-TEST 9-5/8" CASING AGAINST THE 4-1/2" X 7" VBR ~ - 4,000 PSI ATTEMPT 1:700 PSI LOST IN 15 MIN ATTEMPT 2: 200 PSI LOST 5 MIN ATTEMPT 3: 700 PSI LOST IN FIRST 15 MIN, 400 PSI IN SECOND 15 MIN OPEN UP OA TO CHECK PRESSURE - 825 PSI SEEN - PRESSURE ROSE TO 950 PSI IN 10 MINUTES BLEED OFF IA PRESSURE TO 0 PSI - OA PRESSURE BLEED OFF AS IA WAS BLED OFF MONITOR WELL PRIOR TO POOH. 05:30 - 07:30 2.00 CLEAN C DECOMP POOH TO TOP OF BHA AT 831'. 07:30 - 08:30 1.00 CLEAN C DECOMP STAND BACK 5" HWDP AND 6-1/4" DC. 08:30 - 09:00 0.50 ~ CLEAN C DECOMP SERVICE TOP DRIVE AND RIG. 09:00 - 09:30 0.50 CLEAN C DECOMP PICK I iP Hai I IRI IRTON RTTS TO RIG FLOOR. PRESSURE UP OA TO 2,000 PSI WITH 1.2 BBL. IMMEDIATE RETURNS TO 9-5/8" CASING CONFIRMIMNG CASING LEAK. _____ 09:30 - 10:00 _ 0.50 ~ CLEAN C DECOMP EVACUATE RIG DRILL. H2S ALARM. CREW SECURED WELL. ALL HANDS AT MUSTER __ -~ _ _ __ __ _ _ POINT IN 6 MINUTES. '~ _ 10:00 11:00 1.00 CLEAN i C DECOMP MAKE UP HALLIBURTON RTTS TESTING PACKER. RIH WITH 5" HWDP TO 572' 11:00 - 12:30 1.50 CLEAN C i DECOMP RIH 572' TO 1,143' PICK UP 18 JOINTS 4" DRILL PIPE. RIH WITH RTTS TO 2.178' WITH DRILL PIPE FROM I THE DERRICK. - 9-5/8" HALLIBURTON FULL OPENING COLLAR AT 2,099' Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page 6 ate Operation Summary Report ___ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 ~ Spud DatelTime: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (ft) __ ____ __ ____ 12:30 - 13:30 1.00 _ CLEAN C DECOMP SET RTTS AT 2,178'. PRESSURE UP 9-5/8" CASING TO 4,000 PSI. -TEST FAILED -PRESSURE DROPPED OFF 800 PSI IN 12 MINUTES. -FLUID BYPASSING RTTS ELEMENTS. NO ~ PRESSURE INCREASE ON OA. BLEED OFF PRESSURE. UNSET RTTS. 13:30 - 14:00 0.50 CLEAN _ C ___ DECOMP . RD TEST EQUIPMNET PU CROSSOVER, ELEVATORS, & 1 JOINT 5" DP - PUW -97K, SOW - 97K __ 14:00 - 14:45 0.75 CLEAN C DECOMP RIH 30' TO 2,211'. CIRCULATE AROUND RTTS TO CLEAR AROUND PACKER ELEMENTS. 14:45 - 15:45 1.00 CLEAN C DECOMP SET RTTS AT 2,211' PRESSURE UP 9-5/8" CASING TO 4,000 PSI. - PRESSURE DROPPED OFF 600 PSI IN 6 MINUTES ~ -.FLUID BYPASSING RTTS ELEMENTS. NO PRESSURE INCREASE ON OA. BLEED OFF PRESSURE. RIG DOWN LINES TO DRILL PIPE. _ 15:45 - 16:30 _ 0.75 CLEAN C DECOMP RIG UP TO PUMP DOWN KILL LINE AND DOWN 9-5/8" CASING ON TOP OF RTTS TO CHECK IF RTTS CIRCULATING VALVE IS LEAKING AND ALLOWING FLUID TO BYPASS. ~ -CIRCULATING VALVE IS CLOSED. PRESSURED UP CASING ON TOP OF RTTS TO 4,000 PSI. -T TPASSED - PRESSURE DROPPED 50 PSI IN 15 MINUTES INDICATING THAT FO COLLAR AT 2,099' IS ____ ~_ _ HOLDING. ' 16:30 17:00 0.50 CLEAN C DECOMP UNSET RTTS. RIH TO 2,365' BELOW THE 9-5/8" DV TOOL AT 2,340' 17:00 - 17:30 0.50 CLEAN C DECOMP CIRCULATE TO BALANCE BRINE AND CLEAR AROUND RTTS PACKER ELEMENTS. 17:30 - 18:15 0.75 CLEAN C DECOMP SET RTTS AT 2,365' CLOSE PIPE RAMS. PRESSURE TEST DOWN KILL I LINE ON TOP OF RTTS TO 4,000 PSI. -PRESSURE DROPPED 500 PSI IN 15 MINUTES INDICATING THAT DV AT 2,340' MAY BE LEAKING. -PRESSURE ON OA INCREASED TO 1,025 PSI ~ AND DROPPED TO 500 PSI AFTER BLEEDING OFF PRESSURE. PRESSURE TEST ABOVE TO 4,000 PSI FOR 5 MIN -FAILED Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page ~ o#~ Operation Summary Report __ _ __ __ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 ;End Date: X3-OOTW7-C (3,142,752.00 ) I Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs ~ Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:15 - 19:00 0.75 CLEAN C DECOMP RTTS AT 2,365' CHANGED LINES TO PUMP DOWN THE DRILL PIPE TO PRESSURE UP BELOW THE RTTS. PRESSURE TEST BELOW TO 4,000 PSI FOR 30 MIN -PASSED PRESSURE DROPPED 90 PSI. THIS TEST INCLUDES THE CASING TEST FROM 2,365' TO ~ THE EZSV BRIDGE PLUG AT 2,866' _ _ _ 19:00 - 20:15 1.25 CLEAN __ C DECOMP SET RTTS AT 2,305' RU TO TEST FROM BELOW. PIN ON MUD PUMP POPPED OFF REPLACE PIN PRESSURE TEST BELOW TO 4,000 PSI -TEST FAILED INDICATING DV AT 2.340' IS . LEAKING. _ 20:15 - 22:00 _ 1.75 _ CLEAN C DECOMP RTTS AT`2,305' CLOSE PIPE RAMS. PRESSURE TEST DOWN KILL ~ LINE ON TOP OF RTTS TO 4,000 PSI ~ i ' -TEST PASSED INDICATING CASING GOOD j FROM SU ACE TO 2,305 HAVE LOCATED LEAK BETWEEN 2,304' AND 2,365' - - DV AT 2,340' 22:00 - 22:15 0.25 CLEAN C_ _ DECOMP S ETY MEETING ON SLIP & CUT 22:15 - 23:00 ~ 0.75 CLEAN C DECOMP ORDER, THEN WAIT ON RBP TO GET TO LOCATION ~ SLIP & CUT DRILLING LINE j GREESE CROWN ~ SERVICE AND INSPECT TOP DRIVE _ ___ 23:00 - 00:00 1.00 CLEAN C DECOMP POOH FROM 2,305' TO 572' 5/27/2010 00:00 - 01:00 1.00 CLEAN C DECOMP POOH FROM 572' TO SURFACE - STAND BACK HWDP -LAY DOWN RTTS 01:00 - 03:45 2.75 CLEAN C DECOMP RIH FROM SURFACE TO 2,545' MD 03:45 - 04:30 0.75 CLEAN C DECOMP POSITION RBP & SET -CENTER OF ELEMENT AT 2,545.5' _ 04:30 - 04:45 0.25 CLEAN C DECOMP PRE-JOB SAFETY MEETING 04:45 - 05:15 ~ 0.50 CLEAN C DECOMP COMBO MIT IA X OA ~ - 3,500 PSI, FAILED _ __ 05:15 - 06:30 1.25 I _ CLEAN C DECOMP CALL HQ FOR ORDERS ORDER LITTLE RED HOT OIL SERVICES OUT TO PERFORM LOT IN OA WITH DIESEL. __ 06:30 - 08:30 2.00 ~ CLEAN C _ DECOMP SPOT HOT OIL PUMP TRUCK AND TANKER. RIG UP LINES FROM PUMP TRUCK TO CELLAR. HOLD PJSM WITH RIG CREW AND LITTER RED HOT OIL SERVICES Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page 8 viaa~ Operation Summary Report Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) __ _ 08:30 - 10:00 1.50 CLEAN C __ DECOMP TEST HOT OIL LINES TO 3,800 PSI. PERFORM A LOT DOWN THE 9-5/8" X 13-3/8" OA WITH DIESEL. PUMP 2.8 BBL DIESEL AT 1/2 BPM TO 3,850 PSI. NO BREAK DOWN. STOP PUMPING, ISOLATE LINES TO THE PUMP. OBSERVE BLEED BACK. PRESSURE DROPPED TO 2,380 PSI IN 45 MINUTES. BLEED PRESSURE TO 0 PSI AND FLOW BACK 1.8 BBL DIESEL. PRESSURE ON IA UP TO 150 PSI AND FELL BACK TO 25 PSI DURING BLEED OFF 10:00 - 13:30 3.50 CLEAN C DECOMP REPEAT LOT IN OA. PUMP 1.4 BBL DIESEL AT .5 BPM TO 2,500 PSL N0 BREAK DOWN. STOP PUMPING, ISOLATE LINES`TO PUMP. OBSERVE BLEED BACK. PRESSURE DROPPED TO 2,150 PSI ~ AND REMAINED FLAT FOR 45 MINUTES. BLEED ~ PRESSURE TO 0 PSI AND FLOW BACK 1.2 BBL DIESEL. PRESSURE ON IA HELD STEADY AT 20 PSI DURING LOT. 13:30 - 14:00 0.50 CLEAN C DECOMP' RIG DOWN LITTLE RED HOT OIL SERVICES. ~ BLOW DOWN LINES AND CLEAR OF DIESEL. - -- ____ 14:00 - 22:30 ~ 8.50 CLEAN C DECOMP ' RIG UP TO PERFORM A LOT DOWN THE 9-5/8" CASING. PJSM WITH CREW. PERFORM LOT WITH 9.7 PPG BRINE. PUMPED 2.3 BBL BRINE AT 1/2 BPM. PRESSURE UP CASING ~ TO 3,650 PSI. NO BREAK DOWN. ISOLATE LINES ~ TO RIG PUMP. OBSERVE BLEED OFF. FINAL IA PRESSURE = 1,945 PSI FINAL OA PRESSURE = 1,060 PSI _ 22:30 - 23:00 0.50 _ CLEAN C DECOMP DECISION MADE TO STOP TESTING. RIG DOWN AND BLOW DOWN ALL HIGH PRESSURE LINES LAY DOWN 5" DP USED FOR TESTING -CHANGE OUT HANDLING TOOLS, CONTINUE MONITIORING OA 23:00 - 23:15 0.25 CLEAN C i DECOMP MONITOR WELL ~ -STATIC _ ___ _ 23:15 - 00:00 _____ 0.75 CLEAN C __ DECOMP RIH 2 STANDS LATCH ONTO RBP -PULL FREE FLOW CHECK -STATIC CIRCULATE BOTTOMS UP i - 56 SPM, 225 PSI - NO GAS SEEN ON BOTTOMS UP 5/28/2010 00:00 - 01:30 1.50 CLEAN C DECOMP BLOW DOWN TOP DRIVE POOH FROM 2,400 TO SURFACE FLOW CHECK AT HEAVY WEIGHT (570') -STATIC 01:30 - 02:30 1.00 CLEAN C DECOMP LAY DOWN BHA &RBP 02:30 - 04:00 1.50 PULL C DECOMP CLEAR AND CLEAN RIG FLOOR MAKE ROOM FOR UPCOMING OPERATIONS Printed 6/1/2010 11:53:51AM r~ North America -ALASKA - BP Page 9aF'~f Operation Summary Report Common Wefl Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: __ Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs ! Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 ~ PULL C DECOMP RIG UP 500 BBL TANK TO OA WITH HARDLINE PU SLB E-LINE TOOLS ___ 05:00 - 05:15 0.25 PULL _ C DECOMP PRE-JOB SAFETY MEETING WITH SLB E-LINE 05:15 - 09:30 i 4.25 PULL C DECOMP RIG UP E-LINE. RUN USIT CEMENT BOND lOG FROM 2,835' TO SURFACE IN 9-5/8" CASING TO INDENTIFY TOP OF CEMENT IN 9-5/8" X 13-3/8" ANNULUS. TOP OF CEMENT AT 2,100'. -IDENTIFIED FOC AT 2,100' AND DV TOOL AT 2,335'. ' - POOR CEMENT FROM 2,100' GRADUALY INCREASING TO GOOD CEMENT TO 2,835'. 09:30 - 10:00 0.50 PULL C DECOMP` RIG DOWN SCHLUMBERGER E-LINER UNIT. 1 CLEAR RIG FLOOR. EVALUATE LOGS. 10:00 - 10:30 0.50 PULL C DECOMP MOVE 9-5/8" EZSV RETAINER AND RUNNING I TOOL TO RIG FLOOR. MAKE UP RUNNING TOOL ~ TO_EZSV. _ 10:30 - 12:30 -- 2.00 PULL C DECOMP .RIH ON.6 STANDS 5"HWDP AND 4" DRILL PIPE. ~ CIRCULATE SLOWLY. - TAG UPON EZSV BRIDGE PLUG AT 2,852'. PICK UP 2,847 12:30 - 14:00 1.50 PULL C DECOMP SET EZSV RETAINER WITH TOP AT 2,847 WITH , 35 TURNES TO THE RIGHT. i PICK UP AND OVER PULL SOK TO SHEAR OFF. -GOOD SURFACE INDICATION OF SHEAR OFF. SET DOWN 25K TO CONFIRM SET. PICK UP 5', I i TURN 25 TURNES TO THE RIGHT TO EXTEND STINGER. __ ~ _ ___ ___ __ 14:00 - 15:30 ___ 1.50 ~ PULL ~ C ~ __ DECOMP ___ STING INTO RETAINER. SET DOWN 25K. ~ i RIG UP HEAD PIN AND LINES TO DRILL PIPE. PRESSURE TEST TO 3,500 PSI AND HOLD FOR 10 MINUTES. PRESSURE DROPPING SLOWLY. BLEED OFF PRESSURE TO 0 PSI. UNSTING FROM RETAINER. STING BACK IN AND PRESSURE UP A SECOND TIME. SET DOWN 30K. HELD PRESSURE FOR 30 MINUTES. - PASSING TEST, LOST 130 PSI IN FIRST 15 MINUTES AND LOST 45 PSI IN SECOND 15 MINUTES. BLEED PRESSURE TO 0 PSI. RIG DOWN ____ ~ _ ~ __ HEAD PIN AND LINES. ___ 15:30 - 17:30 2.00 ~ PULL C DECOMP POOH WITH RUNNING TOOL. STAND BACK 5" HWDP BLOW DOWN CEMENT LINE & TOP DRIVE ~ LD RUNNING TOOL 17:30 - 18:30 1.00 PULL ~ C DECOMP CLEAR RIG FLOOR OF ALL TOOLS NOT NEED ~ FOR UPCOMING OPERATIONS PU BAKER TOOLS FOR 9-5/8" CASING CUTTER 18:30 - 19:00 0.50 PULL C DECOMP PRE-JOB SAFETY MEETING 19:00 - 19:30 0.50 PULL C DECOMP PU BAKER CASING CUTTER ASSEMBLY 19:30 - 20:30 ~ 1.00 PULL C DECOMP RIH WITH BAKER CUTTER ASSEMBLY ON 4" DP Printed 6/1/2010 11:53:51AM r1 North America -ALASKA - BP Page 10 ~ Operation Summary Report __ ----- - Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth ~ Phase Description of Operations 20:30 - 21:30 1.00 PULL C DECOMP SCREW IN PIPE W/ TOP DRIVE CIRCULATE - 3 ~ BPM, 200 PSI - 5 BPM, 600 PSI LOCATE COLLAR AT 2,026' & 2,066' MD PU TO 2,040' MD - PUW - 85K, SOW - 78K, RTW - 82K ROTATE AT 70 RPM TO MAKE CUT BRING PUMPS ON TO 3 BPM, 200 PSI STAGE UP PUMPS TO 630 PSI. CASING CUT -PRESSURE DROPPED TO 220 PSI - OA PRESSURE FROM 400 PSI INCREASE TO ~ 625'PSI 'I RACK BACK 1'STAND AND;PU 1 JOINT OF 4" DP 8A10'PUP ~ 21:30 - 22:30 01 0 PULL C DECOMP RU TO CIRCULATE, SPOT HOT OIL TRUCK 22:30 - 22:45 0.25 PULL C OECOMP PRE-JOB' SAFETY MEETING WITH ALL HANDS 22:45 - 00:00 1.25 PULL C DECOMP CIRCULATE 130 BBLS DEISEL DOWN DP INTO OA - 2 BPM, 200 PSI RD HOT OIL 5/29/2010 00:00 - 00:30 I 0.50 PULL C DECOMP LET DIESEL SOAK IN OA FOR 30 MINUTES 00:30 - 01:30 1.00 PULL... C DECOMP DISPLACE DIESEL WITH 30 BBL SAFE-SURF-O' PILL, THEN HEATED 9.8 PPG BRINE - DOWN DP, INTO OA, OUT TO SLOP TANK - 320 BBLS TOTAL PUMPED - 8.8 BPM, 1,300 PSI 01:30 - 02:30 1.00 PULL C DECOMP LD PUP JOINT & SINGLE JOINT ~ PULL 2 STANDS _ 1 02:30 - 03:00 _ 0.50 PULL C DECOMP pU RTTS PACKER W/ STORM VALVE . RIH 90 FT SET RTTS - ~ POOH & LD RUNNING TOOL 03:00 - 04:00 1.00 PULL C I DECOMP RU & TEST ON TOP OF STORM PACKER TO 4,000 PSI FOR 10 MINUTES 04:00 - 08:00 4.00 PULL _ _ C __ _ DECOMP pRE-JOB SAFETY MEETING BLOW DOWN ALL LINES NIPPLE DOWN BOP. CHOKE AND KILL LINES. REMOVE RISER NIPPLE AND FLOW LINE. STAND BOP BACK ON THE STUMP. NIPPLE DOWN SPACER SPOOL AND 13-3/8" TUBING SPOOL. 08:00 - 09:30 1.50 PULL C DECOMP INSPECT AND PREPARE 9-5/8" PRIMARY PACK OFF 8 SLIPS IN CASING HEAD. INSTALL ~ HANDLES ON PACK OFF AND SECURE TO CASING. INSPECT LOCK DOWN SCREWS AND CHANGE OUT ONE. 1 09:30 - 14:00 4.50 ~ __ PULL C DECOMP INSTALL 13-5/8" 5,000 PSI 5' SPACER SPOOL ON TOP OF CASING HEAD. NIPPLE UP BOP TO SPACER SPOOL. CONNECT KILL AND FLOW LINES. INSTALL NEW HCR VALVE ON KILL LINE. CONNECT RISER NIPPLE AND FLOW LINE. ___ _ 14:00 - 16:00 _ 2.00 PULL C DECOMP CHANGE TOP RAMS TO 9-5/8" AND LOWER I RAMS TO 2-7/8" X 5" ~~~1~ L°' Printed 6/1/2010 11:53:51AM r~ North America -ALASKA - BP Page 11 41~ Operation Summary Report __ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task ~ Code NPT NPT Depth Phase ~ Description of Operations (hr) ~ (ft) j ________ 16:00 - 16:30 0.50 PULL C DECOMP PREPARE RIG FLOOR TO RIH AND FISH THE RTTS AT 94'. i PU TOOLS AND CROSS OVERS TO RIG FLOOR . 61 30 - 17:00 0.50 PULL C DECOMP MAKE UP HALLIBURTON RTTS RUNNING/PULLING TOOL AND CROSS OVERS. RIH TO 90'. ENGAGE RTTS. PULL FREE. LAY DOWN HES RTTS STORM PACKER __________ __ 17:00 - 18:00 ~ 1.00 PULL C DECOMP POOH FROM 1,815' TO 10' -HOLE TAKING PROPPER DISPLACEMENT 18:00 - 18:30 i 0.50 PULL C DECOMP CLEAR FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS 18:30 - 18:45 0.25 PULL C DECOMP PRE-JOB SAFETY MEETING ON PU BHA 18:45 - 22:00 3.25 PULL C DECOMP MU 3 STANDS SPlRAL80LLARS, 12 JTS FLEX COLLARS, 6 STANDS-HWDP MAKE UP RTTS STORM PACKER SIMOPS: HARDLINE CREW BREAK DOWN LINE AND TAKE ~ AWAY 500 BBL TANK __ _ 22:00 - 22:30 ~ 0.50 PULL C DECOMP RU TO TEST 22:30 - 22:45 0.25 .PULL C DECOMP PRE-JOB SAFETY MEETING TESTING 22:45 - 00:00 1.25. PULL C DECOMP TEST RTTS STORM PACKER AGAINST BLIND ~ SHEARS -ALL FLANGE BREAKS AND PACKOFF TESTED - 4,000 PSI, 5 MINUTES -GOOD TEST i RD TEST EQUIPMENT 5/30/2010 00:00 - 01:30 1.50 PULL C DECOMP RU TO FUNCTION TEST 9-5/8" CASING RAMS 01:30 - 02:00 0.50 PULL C DECOMP FUNCTION TEST 9-5/8" CASING RAMS WIT 9-5/8" TEST JOINT - 2,000 PSI, 5 MIN -GOOD TEST 02:00 - 02:30 0.50 PULL C DECOMP RD TEST EQUIPMENT 8 TEST JOINT 02:30 - 03:00 0.50 PULL C DECOMP RU HES RTTS STORM PACKER RETRIEVAL TOOL WITH SAFETY VALVE ~ RIH 90' PU & POOH WITH RTTS STORM PACKER _ __ _ 03:00 - 05:00 2.00 PULL C __ _ DECOMP POOH -HWDP, NM FLEX COLLARS, SPIRAL DRILL COLLARS 05:00 - 05:30 0.50 PULL C DECOMP MAKE UP 9-5/8" FISHING SPEAR TO 4" DRILL PIPE AT RIG FLOOR RIH TO ENGAGE 9-5/8" CASING BACK OUT LOCK DOWN SCREWS. ~ PULL TO 280K CASING UNSEATED FROM i CASING HEAD. PIPE FREE _ _ 05:30 - 08:30 __ _ 3.00 PULL C _ DECOMP PUMP 30 BBL SAFE SURF O SWEEP SURFACE TO SURFACE. CIRCULATE OUT ARCTIC PACK. i ~ CIRCULATE 3 CIRCULATIONS TO CLEAR i CONTAMINATED BRINE AND ARCTIC PACK FROM WELL. `~j~~ Printed 6/1/2010 11:53:51AM r~ North America -ALASKA - BP Page 12.afr+l+t' Operation Summary Report ___ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations ___ (hr) (ft) 08:30 - 09:00 0.50 PULL C DECOMP LAY DOWN FISHING SPEAR. CLEAR FLOOR. 09:00 - 10:30 1.50 PULL C DECOMP RU DOUBLE STACK POWER TONGS, 9-5/8" ELEVATORS, CROSS OVER AND SAFETY VALVE. RU PIPE WIPERS UNDER THE RIG FLOOR TO i REMOVE EXCESS ARCTIC PACK FROM OUTSIDE __ OF CASING. 10:30 - 15:00 4.50 PULL C DECOMP 'POOH AND LAY DOWN 51 JOINTS 9-5/8" 47# L-80 BTC CASING AND CUT JOINT OF 14.30'. - CASING IN GOOD CONDITION. NO EXCESSIVE _ CORROSION OR WEAR. 15:00 - 17:00 2.00 PULL C DECOMP __ RD 9-5/8" CASING POWER TONGS AND 9-5/8" CASING HANDLING TOOLS. CLEAR AND CLEAN _ _ RIG FLOOR . 17:00 - 17:30 0.50 I CLEAN C DECOMP pU 13-3/8" RTTS PACKER __ STRAP CROSS OVERS 17:30 - 18:00 i 0.50 CLEAN C DECOMP MU 2 STAND, SPIRAL COLLARS, AND ____ _ CROSSOVERS 18:00 - 18:30 0.50 CLEAN C DECOMP' MU CROSSOVER TO TEST PLUG __ PU 10' PUP JOINT 18:30 - 18:45 0.25 CLEAN C _ DECOMP PRE-JOB SAFETY MEETING ON CHANGING OUT --- RAMS 18:45 - 20:30 1.75 CLEAN C DECOMP CHANGE OUT UPPER RAMS TO 3-1/2" X 6" VBR 20:30 - 21:00 0.50 CLEAN C DECOMP RIG UP TO TEST RAMS - TEST RAMS TO 250 PSI / 4,000 PSI - 5 MINUTES - GOOD TEST 21:00 - 21:30 0.50 CLEAN C DECOMP RD TEST EQUIPMENT BLOW DOWN CHOKE AND KILL LINE SIMOPS: CHANGE OFF BLEED OFF 2" PADDLE 8 SEAT . 21:30 - 22:00 0.50 CLEAN C _ DECOMP LD TEST PLUG AND PUP ~ 22:00 - 23:00 1.00 CLEAN C DECOMP ~ RIH WITH 4" DP FROM 213' TO 1,923' MD 23:00 - 23:30 0.50 CLEAN C DECOMP WASH DOWN FROM 1,923' TO 2,018' - 4 BPM, 100 PSI PU 2 10' PUPS ~ SET RTTS@ 2,029' (CENTER OF THE ELEMENT) _ 23:30 00:00 0.50 CLEAN C DECOMP RU TO TEST 13-3/8" CASING 5/31/2010 00:00 - 00:30 0.50 CLEAN C DECOMP CONTINUE TESTING 13-3/8", 72#, L-80, BTC ~ CASING FROM 2,030' UP - 3,500 PSI, 30 MIN _ -GOOD TEST, LOST 75 PSI IN 30 MIN 00:30 - 01:00 0.50 CLEAN C DECOMP BLOW DOWN CHOKE & KILL LINE, AND MANIFOLD __ _ _ 01:00 - 02:00 1.00 CLEAN C DECOMP POOH FROM 2,033' TO 185' i CHANGE OUT ELEVATORS STAND BACK COLLARS _ ___ __ ~_ LAY DOWN STORM PACKER ~ 02:00 - 03:00 1.00 CLEAN C DECOMP CLEAR RIG FLOOR OF ALL TOOLS NOT NEEDED FOR UPCOMING OPERATIONS Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page 13 cd~Mf Operation Summary Report Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 05:00 2.00 CLEAN C DECOMP MU 13-3/8" CLEAN OUT / 9-5/8" DRESS OFF BHA WITH TAPERED MILL, 8-1/2" WATERMELLON MILL AND 13-3/8" CASING SCRAPER. 05:00 - 06:00 1.00 CLEAN C DECOMP RIH WITH CLEAN OUT BHA -CIRCULATE EVERY 10 STANDS TO CLEAR ~ ARTIC PACK AT 4 BPM WITH 120 PSI ~ TAG UP ON 9-5/8" CASING STUB AT 2,040' _ _ __ _ 06:00 - 06:30 0.50 CLEAN C __ _ DECOMP tn/ORK MILLS THROUGH THE TOP OF THE 9-5/8" CASING STUB CIRCULATE AT 8 BPM WITH 380 PSI. 06:30 - 08:00 1.50 CLEAN C DECOMP CIRCULATE AT 8 BPM WITH 380 PSI. RECIPROCATE TOOLS 25' PUMP AROUND SAFE SURF O SWEEP FROM SURFACE TO SURFACE CLEAN WELL OF _ ARCTtG PACK. 08:00 - 08:30 0.50 CLEAN C DECOMP FLOW CHECK: BLOW DOWN TOP DRIVE. 08:30 - 11:00 2.50 CLEAN C DECOMP POOH. STAND BACK 5" HWDP AND DRILL COLLARS. 11:00 - 12:00 1.00 I CLEAN ` C DECOMP ' LAY DOWN CASING SCRAPER AND MILLS 12:00 - 12:30 0.50 BOPSUR P WEXIT RIG UP LINES TO TEST BOP 12:30 - 18:30 6.00 BOPSUR P - WEXIT - TEST BOPE -ANNULAR PREVENTOR TO 2,500 PSI HIGH, 250 PSI LOW - 4,000 PSI HIGH, 250 PSI LOW: - UPPER RAMS (3-1/2" X 6") WITH A 4" TEST JOINT -VALVES 1,2,4,5,6,7,8,9,10,11,12,13,14 -UPPER IBOP ON TOP DRIVE - CHOKE & KILL LINE, KILL LINE VALVE - LOWER RAMS (2-7/8" X 5") W/ 4" TEST JOINT - TIW DART VALVE i -ACCUMULATOR TEST TEST WITNESSED BY BP WSL DUNCAN FERGUSON, ZACH SAYERS , DOYON TP NICK MARMON, HARRY GOCHENAUER __ AOGCC WITNESS WAIVED BY CHUCK SCHEVE 18:30 - 21:30 3.00 BOPSUR N RREP WEXIT PJSM, CHANGE OUT MANUAL VALVE ON _ i ~ ( CHOKE LINE 21:30 - 22:30 _ 1.00 BOPSUR i P ~ WEXIT ~ TEST BOPE ( - 4,000 PSI HIGH, 250 PSI LOW: ~ -BLIND SHEAR RAMS - VALVE 3 I i ~ -MANUAL CHOKE TEST WITNESSED BY BP WSL DUNCAN FERGUSON, ZACH SAYERS , DOYON TP NICK MARMON, HARRY GOCHENAUER AOGCC WITNESS WAIVED BY CHUCK SCHEVE ~~~, ~~~~~~ Printed 6/1/2010 11:53:51AM North America -ALASKA - BP Page 14Z~ Operation Summary Report _ __ __ _ Common Well Name: B-13 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/23/2010 i End Date: X3-OOTW7-C (3,142,752.00 ) Project: Prudhoe Bay Site: PB B Pad Rig Name/No.: DOYON 14 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: B-13 @64.2ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (ft) 22:30 - 23:00 0.50 BOPSUR P WEXIT _ BLOW DOWN CHOKE & KILL LINE INSTALL NEW HOLE FILL LINE LIFT WEAR BUSHING TO RIG FLOOR REMOVE TEST PLUG - - _ INSTALL WEAR BUSHING 23:00 - 00:00 1.00 STWHIP P WEXIT _ LIFT BAKER TOOLS TO THE RIG FLOOR FOR UPCOMING MILLING OPERATIONS 6/1/2010 00:00 - 01:00 1.00 STWHIP , P WEXIT. MU WINDOW MILLING BHA -WHIPSTOCK & MILLS -. - - - - -- -MWD 01:00 - 01:30 0.50 STWHIP P WEXIT UPLOAD MWD 01:30 - 04:00 2.50 STWHIP P WEXIT MU 6-1/2" DC & 5" HWDP ON MILLING BHA - (9) 6-112" DC 04:00 - 06:00 2.00 STWHIP P WEXIT 1L ING BH FROM 956' TO 2. 84T - ON 4" bP -WENT THROUGH THE 9-5/8" CASING STUB @2,040'.. WITHOUT A BOBBLE ON THE WEIGHT - _ INDICATOR ' 06:00 - 06:30 0.50 STWHIP P WEXIT ATTEMPT TO ORIENT WHIPSTOCK WITH MWD -MWD NOT GETTING GRAVITY TOOLFACE __ -~ - _ BECAUSE OF SHALLOW ANDGLE 1-2? 06:30 - 06:45 0.25 STWHIP P ; WEXIT PRE-JOB SAFETY MEETING RUNNING GYRO ON 06:45 - 07:15 07:15 - 08:45 ~ 0.50 1.50 ~ STWHIP STWHIP _~ P P ~ _ _ WEXIT WEXIT E-LINE _ RU HES E-LINE RUN GYRO DATA TOOL ON E-LINE TAKE SURVEYS TO ALIGN AZIMUTH FOR _ MILLING TO 240 08:45 - 09:00 0.25 STWHIP P WEXIT SET WHIPSTOCK - ` T 50K - ~ STWHIP P WEXIT MILL WINDOW "$~l3'~ Printed 6/1/2010 11:53:51AM TREE= 7-1/16" CM/ WELLH~.4D = McEVOY ACTUATOR = BAKER C KB. ELEV = 64.16' BF. ELEV - 37.72' KOP = 3100' Max Angle = 100 @ 11235' Datum MD = 10234' Datum TV D = 8800' SS JC 20" CONDUCTOR 9-5/8" CSG STUB 2040 (05/28/10) 13-3/8" CSG, 72#, L-80, ID = 12.347" ~-~ 2688 Minimum ID = 3.725" @ 9862' 4-1/2" HES XN NIPPLE 9-5/8" CSG, 47#, L-80, BTGM, ID = 8.681" ~ 2824' 9-5/8" WHIPSTOCK (06/01/10) 2847' 9-5/8" EZSV (05/28/10) 2852' B ~ 13 B SAFETY :CHROME NIPPLES &WLEG 2099' 9 5/8" FOC 2214' 4-1/2" HES (CR) X NIP, ID = 3.813" 2340' 9 5/8" DV PKR 9-5/8" MILLOUT WINDOW (B-136) 2824' - 2841' ' ~-~4-1/2" HES X (CR) NIP, ID = 3.813" 7" X 4-1/2" HES TNT PKR, ID = 3.856" 4-1/2" HES X (CR) NIP, ID = 3.813" 4-1/2" HES XN (CR) NIP, ID = 3.725" 4-1/2" TBG, 12.8#, L-80 TCII, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80 BTGM, .0383 bpf, ID = 6.184" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: @ Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE PBTD I~ 10378' ~4-1/2" LNR, 12.6#, L-80 IBT-M, .0152 bpf, ID= 3.958" 9{ 866' I-{ 7" X 5" HRD ZXP LTP w / 5.25' I w/ 5.25" TIEBACK SLV, ID = 4.440" 9874' 4-1/2" WLEG, ID = 3.958" ELM TT NOT LOGGED 9882' 7" X 5" BKR FLEX LOCK LNR HGR, ID = 4.40" 9~ $92' 1 5" X 4-1/2" XO, ID = 3.958" DATE REV BY COMMENTS DATE REV BY COMMENTS 01/17/79 ORIGINAL COMPLETION 06/22/91 D-16 RWO 06/21/10 D-14 SIDETRACK(B-13B) 06/25/10 PJC DRLG DRAFT CORRECTIONS 07/05/10 SV CSG CORRECTION PRUDHOE BAY UNIT WELL: B-13B PERMIT No: 2100390 API No: 50-029-20341-01 SEC 31, TIIN, R14E, 1740' FNL & 1808' FEL BP Exploration (Alaska) 06/18/10 J /~ Schiumherger Alaska Data & Consulting Services 2525 Gambell Street, Suke 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # Log Description Date N0.5545 Company: State of Alaska Alaska Oil & Gas Cons Comm ANn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 BL Cotor CD E-188 BBUO-00015 STATIC BOTTOM & TEMP SURVEY 04/03/10 1 1 H-30 BCRD-00020 PRODUCTION PROFILE 05/1.0/10 / 1 P2-34 B3SG-00071 STATIC PRESSURE SURVEY 05/15/10 1 1 P2-34 B3S0.00073 (PROF WITH STATIC SURVEY 05/19/10 1 1 V-OS AWJI-00090 MEM CBL ^~ 05/24/10 1 1 P2-17 18-068 BCRC-00017 BBUO.00023 PRODUCTION PRO ICE PRODUCTION PROFILE 06/01/10 06/08/10 1 1 1 1 S-21 BBSK-00019 PRODUCTION PROFILE 06/03/10 1 1 Z-46A BAUJ-00027 MEM CBL 06/01/10 1 1 V-OS Ot-26A 8088-00016 8146-00106 MEM LDL SCMT 06/08/10 06/10/t0 1 1 1 1 B-13A 1-27/P-20 BBUO-00019 AYKP-00065 UStT RST & FL RECOR .05/28/10 08/06/10 1 / 1 1 1-27/P-20 MPF-82A AYKP-00085 BAUJ-00010 PRODUCTION PROFILE MCNL 06/06/10 04/06/10 1 1 1 1 Z-i6A BCUE-00005 CH EDIT PDC MEM CORR CATION 04/06/10 1 E-150 AWJI-00081 MCNL 04/03/10 1 1 05-19 BBKA-00013 RST - 03/14/10 1 1 F-27A AYKP-00078 RST 03/17/10 1 1 J-18A BD88-00010 MCNL 04/18/10 1 1 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. ;_.~~.4~~~ ~~ ~ t:, ( Ill;;'; Alaska Data 8 Consulting Services 2525 Gambeli Street, Su4e 400 Anchorage, AK 99503-2838 ~`~ S~hiumd~r~er ~~Y ~ ~Oli' g ~,~,~, a Alaska Data & Consulting Services f'~ '~ 6~t rya °,`~~ ' 2525 Gambell Street, Suite 400 Anchorage, AK 99b03-2838 • . ~~~ ATTN: Beth Well Job # Log Description N0.5520 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Date BL Color CD H-25 B-13A D-27A M-17A BCRD-00017 BBSK•00018 BCRD-00021 BAUJ-00020 PRODUCTION PROFILE GRAVEL PACK/TBG PUNCWMP T LDL ~ MEM PRODUCTION PRO ILE .. 05/09/10 5/06!10 05/12/10 04/10 1 1 1 1 1 1 1 1 F-12 AVYO-00069 PRODUCTION PROFILE - 05/03!10 1 1 07-328 Z-03A F-23A BBUO-00016 8088.00006 BBSK-00007 SCMT - CH EDIT PD R EM O ELATI N RST 05/04!10 03/25/10 02/17/10 1 1 1 1 1 C-13A AVYO-00060 RST - 02/16/10 1 1 E-338 AWJI-00078 MCNL ~ _ 03/25/10 1 1 PLEASE ACKNOWLEDGE REC EIPT RY cl[;tultu r; eun acre tcurur_ nuc rno.. ~.~., r.,. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2638 05/24/10 • u • • Greg Hobbs Engineering Team Leader 1 ~~, BP Exploration (Alaska), Inc. Yp~.. ~~"~'~~, ~~ ~'~~ "~ ~~ P.O. Box 196612 Anchorage, AK 99519-6612 ~ ~~ Re: Prudhoe Ba Field Prudhoe Ba Oil Pool PBU B-13A ~~ Y ~ Y Sundry Number: 310-096 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. / S ~ Chair DATED this t day of April, 2010. Encl. STATE OF ALASKA C (~~~0 ALASfU~ AND GAS CONSERVATION COMMIS~1 ~~C~'V4~,~~~ ,~~ ~~~ APPLICATION FOR SUNDRY APPROVAL -s3~'~O ~~ 20 AAC 25.280 MAR 3 ` p 2010 1. Type of Request: ~InISSt011 ~ ^ Abandon ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change ~h~~ ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ^ Development ^ Exploratory 199-057 ° 3. Address: ®Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20341-01-00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU B-13A Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028310 & 028286 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (tt): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 12245' - 8969'' 12085' 8913' 11800' 12017' Casin Len h Size MD TVD Burst Colla e Structural Conductor 11 11 ' Surface 2 6' 1 - / " 2 8 ' 2686' 4 2670 Intermediate 1 9-5/8" 1 631' 87 47 0 Production Liner 6603' 7-5/ " 3 41' - 9844' 2 ' - 4790 Liner 761' 7" 944' -.1060 ' 268' - 880 ' 1 702 Liner 2-7/ " 11 4' 1 4 Perforation Depth MD (tt): Perforation Depth TVD (tt): Tubing Size: Tubing Grade: Tubing MD (tt): 11630' - 11710' 8843' - 8849' 7, 26# x 5-1 /2", 17# x 4-1 /2", 12.6# L-80 / NT80S / L-80 10568' Packers and SSSV Type: 7-5/8" x 4-1/2" TIW 'HBBP-R' packer; Packers and SSSV 9807' / 8243'; 7" x 4-1/2" TIW'HBBP packer MD (ft) and TVD (tt): 10538' / 8757' 12. Attachments:'.. 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ^ Development ®Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 20, 2010 ^ Oil ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ WINJ ^ GINJ ^ WAG Plugged ^ SPLUG Commission Representative: ~S!/S,~ / 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bet~6eeii 8- Printed Name Greg H bbs Title Engineering Team Leader ~'f°'~'~ 4 M ~~~ va s`~-S~BG g ~`~~ Prepared By Name/Number. Si nature Phone 564-4191 Date Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness ~~ Sundry Number: vi ^ Plug Integrity LJBOP Test ^ Mechanical Integrity Test ^ Location Clearance ~35or~ ~~~~ ~oP e~~ Other. ~ ~~ ~ .~ ~ yu..~-,,) z. h h -~2.~0 /o ~'ti~(1"~' • Z. O J4/4~ Z.~J* ~ O - ~ c e e.~ L 1 ~ 2 ~ c p - S f =- S ~-i °~ ' p~ ~ u L ~ '~ Subsequent Form Required: ~ ®• / APPROVED BY ~~ 1) f Approved By: COMMISSIONER THE COMMISSION Date Forrn 10-403 Revisedr121f009 / Submit In Duplicate R6DNAS APR 0 2 2010 ~ ~ I G ~ t V ~ L ~- ~ - ~a • B-13A Well Type: Injector Current Status: The well is currently shut-in. Request: Approval is requested for the P&A of Prudhoe Bay well B-13A. B-13A is a horizontal injector drilled with CTD in 1999. It was designed to step away from suspected fault/tracture related Z3 injection issues in the parent well. It was completed as a WAG injector, started in MI service and had three MI cycles before anncomm issues in 2005 restricted it to PWI service. At this time B-13A has two known leaks in the 9 5/8 casing and a failed production packer. A RWO was initially planned but, the 7 5/8" tie- back string in the existing completion makes it difficult to satisfy well integrity requirements for a WAG injector and still maintain future ST options. The mechanical condition of the well and the pattern conformance issues make a RST the best option for this well. This RST should restore both the wellbore integrity and the pattern conformance Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA requests a variance to the provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE when existing wellhead or testing equipment prevents the testing of the lowest set of pipe rams. If the lower set of pipe rams cannot be tested during the primary BOP test, that set of rams will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the BOP stack. Scope of Work: The sidetrack plan for the B-136 (Ivishak Zone 4 injector) well includes the following: during pre-rig operations laying cement across the perforations and cutting the 5-1/2" tubing at approximately 3,170' MD right below the 5-1/2" x 7" crossover. The whipstock exit from the 9-5/8" casing is estimated at 2,870' MD and will be milled using an 8-1/2" milling assembly during rig operations. The 8- 1/2" hole will be drilled to the top of the Sag River where a 7" drilling liner will be run and cemented with a 1,000' tail of 15.8ppg class G cement. The production hole will be drilled with a 6-1/8" BHA to TD in Zone 4 A in Ivishak at 10,470' MD. The liner will be a 4-1/2" L-80, IBT-M liner and the tubing will be 4-1/2" L-80, TCII, tied into the top of the production liner. The production liner is planned to be fully cemented and perforated post-rig. MASP: 2500 psi Estimated Start Date: April 20th, 2010 ,~.. (U~ ~ Jr . 1/!(© Pre-Rig Work: ~4,~~ "/ Objective: Cut tubing shallow below the whipstock exit. Whipstock depth: 2870' MD • 1. F: Fluid pack the tubing and inner annulus w/ seawater/diesel. 2. F: P & A the perforations in the B-13A wellbore with cement from 11,710' MD up to 8,500' MD. There are no GLMs in tubing. Ensure that IA and tubing are fluid packed. Perform infectivity test. Pump cement from surface into perforations above the CIBP at 11800'. a. CEMENT CALCULATIONS i. 1549' of 2-7/8", 6.16# liner: .0058 bbls/ft = 9.0 bbls °~ ii. 466' of 4-1/2", 12.6# tubing: .01521 bbls/ft = 7.1 bbls iii. 1285' of 5-1 /2", 17# tubing: .02324 bbls/ft = ~-5-i~bls ' ~ ~" ~ n ~- s TOTAL (with 10 bbls excess) = 68 bbls .~ 3 ~~ rte. BHP (formation): 3290 psi ~'~" " BHT (formation): 200 deg F Desired TOC: 8,500' MD Min TOC: 9,785' MD Max TOC: 5,000' MD 3. S: WOC. Drift for Jet Cutter. Tag Top of cement plug.' 4. F: MIT - T to 2,500 psi for 30 minutes. 5. F: MIT - OA to 2,000 psi for 30 minutes. 6. E: Jet cut the 5-1/2" tubing just below 7" x 5-1/2" crossover at 3170' MD. `~" 7. F: CMIT - T x IA to 2,500 psi for 30 minutes. Establish LLR. 8. F: Circulate the well to 9.8 ppg brine. Note PC leak 3002' and --3700'. Freeze protect the IA and tubing with diesel to 2,200' (150 bbls). 9. D: Bleed all casing and annulus pressures to zero psi. 10. W: Function all tubing and casing LDS. Repair and replace as necessary. PPPOT-IC and PPPOT-T. 11. V: Set a BPV. Secure Well. 12. O: Remove well house and flow line. Level the pad as needed. Provide total well preparation cost on the handoverform. Rig Operations: 1. MI/RU Doyon 14. 2. Pull BPV. Circulate out freeze protection and displace well to a 9.6 ppg brine. Condition fluid as needed. 3. Set and test TWC to 1000 psi from below (rolling test due to PC leak} and above to 3500 psi. 4. Nipple down tree. Nipple up and test BOPE to 3500 psi high/ 250 psi low. Pull TWC. 5. RU and pull the 7", 26#, IJ4S x 5-1/2", 17#, NT-80S, NSCC tubing from the pre-rig jet cut at 3170' MD. Spool up the control lines (tally is not specific on the number of lines) and stainless steel bands (30 listed on tally). 6. Test the lower set of pipe rams... 7. PU 4" drillpipe and 9-5/8" clean-out assembly and clean-out well to the top of the tubing stub 3170' MD. Note: Do not run 9-5/8" casing scrapers due to the 9-5/8" FO collar at 2099'. 8. RU E-line, RIH with CCL and tag tubing stump at 3170'. POOH. 9. On E-line, run a 9-5/8" EZSV for 47# casing. Set the EZSV at 2890' MD as required to avoid cutting a casing collar while milling the window. POOH. Rig down E-line. 10. Pressure test the EZSV to 3500 psi for 10 minutes. 11. PU and RIH with 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly (to include full gauge string mills). 12. RIH to the top of the EZSV. Orient and set the whipstock. 13. Displace the well to LSND based milling fluid. Completely displace the well prior to beginning the 14. Mill a window in the 9-5/8" casing from 2870' MD' plus 20' of formation from mid-windoH PU into 9-5/8" casing. Perform a LOT. POOH for drilling BHA. 15. MU an 8-1/2" drilling BHA with DIR/GR/RES/PWD and ghost reamer behind the bit. RIH. 16. Kick off and drill 8-1/2" intermediate interval to 7" casing point at the top of the Sag River. 3j~-o~u P~ • . NOTE: The mud will need to be weighted up with spike fluid. Plan for one weight-up with the spike fluid to 10.1 ppg while drilling 1-2 stands and allow for several circulations, prior to drilling the HRZ and Kingak shale. 17. Circulate well clean, short trip to THRZ, RIH to TD, circulate wellbore clean. POOH on elevators? 18. Change to 7" casing rams and test to 250 psi low / 3500 psi high. 19. Run a 7", 26#, L-80, BTC-M drilling liner back into the 9-5/8 to 2000' (above the existing FOC at 2099'). 20. Cement 7" liner with a 1000' tail of 15.8 ppg class G cement. Displace cement with mud. 21. Set hanger and liner top packer. Circulate bottoms up, POOH, UD liner running tool (LRT). 22. Pressure test the 7" liner for 3500 psi for 30 minutes. Chart and record. 23. Remove the existing McEvoy 2 Step Tubing Spool. Change out the 9-5/8" pack-offs per Cameron. Install new McEvoy SSH Tubing Spool. 24. MU a 6-1/8" BHA with DIR/GR/RES/DEN/NEU and RIH to the 7" landing collar. 25. Drill out the 7" shoe plus 20' of formation while swapping over to new Flo-Pro drilling fluid. Perform an FIT. 26. Drill ahead per plan to TD in Ivishak Z4A. 27. CBU, trip to shoe and back to bottom, circulate until clean. MAD Pass where required. POOH. 28. RU E-line and run USIT log across cement at shoe, than GR only to surface. 29. Run a 4-1/2", 12.6#, L-80, IBT-M liner from TD to 150' liner lap inside the 7" shoe. 30. Cement the liner to the TOL with 15.8 ppg Class G Latex cement. 31. Set liner top packer. POOH, VD liner running tool (LRT). 32. RU and run 4-1/2", 12.6#, L-80, TC-II completion, tying into the 4-1/2" liner top. 33. Reverse circulate to spot corrosion inhibited seawater followed by sufficient diesel for 2200' of freeze protect. Allow diesel freeze protect to U-tube from IA to tubing. 34. Drop ball and rod. Set 4-1/2 production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. Record each test. 35. Set and test a TWC. 36. ND BOPE. NU and test the tree to 5,000 psi. 37. Pull TWC. Set a BPV 38. RDMO. D. Post-Rig Work: 1. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 2. RU E-line. Run SCMT log in production interval. 3. Perforate --100' with 3-3/8" PJ 3406 pert guns. 4. Install wellhouse and flowlines. (S-Riser work will be required.) Drilling Engineer: Maria Medvedeva (907) 564-5786 Production Engineer: AI Schmoyer (907) 564-5865 Geologist: Cole Abel (907) 564-5576 ATTACH: Current Schematic Pre-Rig Schematic TREE= 7-1/16" CIW WELLHEAD = McEVOY ACTUATOR = OTIS KB. ELEV = 64.16' BF. ELEV = 37.72' KOP = ~ 3100' Max Angle = 100 @ 11235' Datum MD = 11880' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" 7" TBG, 26 #, IJ4S, .0383 bpf, ID = 6.276" TOP 5-1 /2" TBG 3161' 3161' Minimum ID = 2.37" @ 10255' 2-7/8" ST-L LINER TOP 5-1/2" TBG, 17#, NT-80S NSCC, .02324 bpf, ID = 4.892" ~ 9785' TOP4-1l2" TBG 9785' TOP OF 7" BOT LNR HGR TIEBACK SLV ~-~ 9844' TOP OF 2 7/8" LINER, ID = 2.37" I~ 10255, 9-5/8" CSG, 47#, L-80, ID = 8.681" 10336' 4-1/2" TBG, 12#, TDS, .01521 bpf, ID = 3.958" ~~ 10567' PERFORATION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/04/99 ANGLE AT TOP PERF: 88 @ 11630' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11630 - 11650 O 09/23/00 2" 6 11690 - 11710 O 09/22/00 2" 4 11990 - 12010 C 09/09/99 2" 4 12049 - 12070 C 09/09/99 3161' ~--~ 7" U4S X 5-1/2" TC4S XO, ID = 4.892" 3241' ~~ 9 5/8"x 7 5/8" TNV LNR HGR/ TIEBACK 9785' -(5 1/2" NSCC X 4 1/2" TDS XO, ID = 3.958" 9798' 4-112" PARKER SWS NIP, ID = 3.813" 9807' 7-5/8" TNV (HBBR R) RETR PKR, ID = 3.890" 9855' 7" BOT TIEBACK SEAL ASSY 10251' ~-~ 3.75" BKR LNR DEPLOY SLV, ID = 3.00" 10538' -17' TNV (HBBP) PKR, ID = 4.00" 10548' 4-1/2" PARKER SWS NIP, ID = 3.813" 10559' 4-1/2" PARKER SWS NIP, ID = 3.813" 10568' 4-1/2" TUBING TAIL WLEG 10565' ELM TUBING TAIL 7" MILLOUT WINDOW 10605' - 10612' 10601' TOP OF WHIPSTOCK 11800' CIBP (09/19/01) 12017' FISH -CIBP REMNANTS PBTD ~ 12085' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" (-j 11032' 2-7/8" LNR, 6.16#, L-80, SL-T, .0058 bpf, ID = 2.37"" ~-~ 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 01/17/79 ORIGINAL COMPLETION 08/24/06 COMITL WANERSAFETY NOTE 06/22/91 RWO 09!18/06 DRF/TLH LTTP PULLED 09/09/99 CTD SIDETRACK (B-13A) 09/19/01 DBM/KK CIBP & FISH 11/27/02 JW/KAK CLOSE PERFS 12/14/05 DAV/PJC SSSVN GO PRUDHOE BAY UNIT WELL: B-13A PERMtT No: 1990570 API No: 50-029-20341- 1 SEC 31, TIIN, R14E, 1740' SNL & 16 8' WEL BP Exploration (Alaska B-13A SAFETY NOTES: TIW PKRS IN WELL MAY FAIL IF 2100 PSI DIFFEREWTI IS IXCEEDm. WELL > 70 DEG @ 10770' AND GOES HOR~AL @ 10860'. ""`PROD CSG LEAK OPERATING MITS: MAX IAP = 500 PSI, MAX OAP =1000 PSI, WATER INJECTION ONLY (05/17/06 WAIVER)"'"' 2099' 9 5/8" FOC 2112' 7" OTIS SSSVN, ID = 3.813" (W/INSERT) 2340' 9 5/8" DV PKR = 7- VVE_LLHEAD, ACTUATOR = McEVOY OTIS KB. ELEV = 64.16' _ BF. ELEV = 37.72' KOP = 3100' Max Angle = ~0 @ 11235' Datum MD = 11880' Datum TV D = 8800' SS B-13A ire-Rig ~13-318" CSG, 72#, L-80, ID= 12.347" ~--~ 2686' 7" TBG, 26 #, IJ4S, .0383 bpf, ID = 6.276" 3161' ~~12~~~ JET CUT 3400' Planned TOC 8500 TBG, 17#, NT-80S NSCC, .02324 bpf, ID = 4.892" TOP4-1/2" TBG -{ 9785' ITOP OF 7" BOT LNR HGR TIEBACK SLV ~ 9844' Minimum ID = 2.37" @ 10255' 2-7/8" ST-L LINER TOP TOP OF 2 7/8" LINER, ID = 2.37" ~ 10255' 5/8° CSG, a7#, L-ao, ID = a.ss1° 10336' 4-112" TBG, 12#, Tt~S, .01521 bpf, ID = 3.958" ~~ 10567' PERFORATION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/04/99 ANGLE AT TOP PERF: 88 @ 11630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11630 - 11650 O 09/23/00 2" 6 11690 - 11710 O 09/22/00 2" 4 11990 - 12010 C 09/09/99 2" 4 12049 - 12070 C 09/09/99 SAFETY NOTES: TIW PKRS IN WELL MAY FAIL IF 2100 PSI DIFFERBYTI EXCE®®. WELL > 70 DEG @ 10770' AND GOES HORI AL @ 10860'. "'PROD CSG LEAK OPERATING LIMITS: MAX IAP = 500 PSI, MAX OAP = 1000 PSI, WATER INJECTION ONLY (05/17106 WAIV ER~*" 2099' 9 5/8" FOC 2112' 7° OTIS SSSVN, ID = 3.813" (W/INSERT) 234 9 5/8" DV PKR 3161' ~7" U4S X 5-1/2" TC4S XO, ID = 4.892" 3241' ~ 9 5/8"x 7 5!8" TNV LNR HGR/ TIEBACK 9785' -15 112" NSCC X 4 1/2" TDS XO, ID = 3.958" 9798' 4-1/2" PARKER SWS NIP, ID = 3.813" 9807' 7-5/8" TM/ (HBBR-R) RETR PKR, ID = 3.890" 9855' 7" BOT TIEBACK SEAL ASSY 10251' ~-i3.75" BKR LNR DEPLOY SLV, ID= 3.00" 10538' -~7' TM! (HBBP) PKR, ID = 4.00" 10548' 4-112" PARKER SWS NIP, ID = 3.813" 10659' 4-1 /2" PARKER SWS NIP, ID= 3.813" 10568' - 4-1/2" TUBING TAIL WLEG 10565' ELM TUBING TAIL 7" MILLOUT WINDOW 10605' - 10612' 10601' TOP OF WHIPSTOCK 11800' CIBP (09/19/01) 12017' FISH -CIBP REMNANTS PBTD 12085' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~ 11032' 2-7/8" LNR, 6.16#, L-80, SL-T, .0058 bpf, ID = 2.37"" 12118' DATE REV BY COMMENTS DATE REV BY COMMENTS 01/17/79 ORIGINAL COMPLETION 08/24/06 COM/TLH WAIVER SAFETY NOTE 06!22/91 RWO 09/18/06 DRF/TLH LTTP PULLED 09/09/99 CTD SIDETRACK (B-13A) 03/23/10 MLM B-13A Pre-Rig Proposed 09/19/01 DBM/KK CIBP & FISH 11 /27/02 JW/KAK CLOSE PERFS 12/14!05 DAV/PJC SSSVN GO PRUDHOE BAY UNIT WELL: B-13A PERMIT No: 1990570 API No: 50-029-20341-01 SEC 31, TIIN, R14E, 1740' SNL & 1608' WEL BP Exploration (Alaska) WEtLHEq,D ~ __ McEVOY ACTUATOR = 0715 KB. ELEV = 64.16' _ BF. ELEV = 37.72' K OP = 31_00' _ Max Angle = ~0 @ 11235' Datum MD = __ 11880' -. _ Datum TVD = 8800' SS B-136 ~oposed Minimum ID = 2.37" @ 10255' 2-7/8" ST-L LINER TOP 13-3/8" CSG, 72#, L-80, ID = 12.347" 268 ~r.]/S~VWI~O~C IJ 9 5/8" EZSV 2890' 9 5/8" x 7 518" TNV LNR HGR/ TIEBACK 3241' JET CUT 3400' Planned TOC 8500' 5 1/2" TBG, 17#, NT-80S NSCC, ID 4.892" 9785 4 1/2" PARKER SWS NIP, ID = 3.813" 9798 7 5/8" TIW (HBBR-R) RETR PKR, ID 3.890" 9807 TOP OF 7" BOT LNR HGR TIEBACK SLV 9844' I9-5/8° csG, a7#, L-so, ID = 8.681° ~ 10336' 1/2" TBG, 12#, TDS, .01521 bpf, ID = 3.958" 10567' 7" TNV (HBBP) PKR, ID = 4.00" 1 0538 PERFORATION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/04/99 A NGLE AT TOP PERF: 88 @ 11630' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11630 - 11650 O 09/23/00 2" 6 11690 - 11710 O 09!22/00 2" 4 11990 - 12010 C 09/09/99 2" 4 12049 - 12070 C 09/09/99 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" ~-{ 11032' +~ i J ,. 1~ 1~ e SAFETY NOTES: TIW PKRS IN WELL MAY FAIL IF 2100 PSI DIFFERENTIA IXCEEDED. WELL > 70 DEG @ 10770' AND GOES HORI AL @ 10860'. "*"PROD CSG LEAK OPERATING LIMITS: MAX IAP = 500 PSI, MAX OAP = 1000 PSI, WATER INJECTION ONLY (05/17/06 WAIVER)"' 2000' H7" LINER HANGER /LTP 2099' s s/s° Foc 2200' 4 112" X NIP 2340' ~ 9 5/8" DV PKR 9037' HPlanned TOC 9747' 4-1 /2" OTIS X NIP, ID = 3.813" gjjf' 7'x412'i$1NfR~ 412~~XND~~~~~~ 9$77' 4-1/2" OTIS XN NIP, ID = 3.725" 9887' 4-1/2", 12.6#, L-80, TC-II, .0152 bpf, ID= 3.958" 9887' 4-112" Hanger /LTP DATE REV BY COMMENTS DATE REV BY COMMENTS 01/1789 ORIGINAL COMPLETION 08/24/06 COMrTLH WAVER SAFETY NOTE 06/22/91 RWO 09/18/06 DRFITCH LTTP PULLED 09/09/99 CTD SIDETRACK (B-13A) 03/23/10 MLM B-13B Proposed 09/19/01 DBNVKK CIBP & FISH 11 /27/02 JW/KA K CLOSE PERFS 12/14/05 DAV/PJC SSSVNC/O 10037' 7", 26#, L-80, BTC-M, 0.0383 bpf, ID = 6.276" PBTD I-~ 103 ~4-1/2", 12.6#, L-80, IBT-M, ID=3.958" ~ PRUDHOE BAY UNIT WELL: B-136 PERMfT No: 1990570 API No: 50-029-20341-02 SEC 31, TIIN, R14E, 1740' SNL & 1608' WEL BP Exploration (Alaska) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 _. Post Office Box 196612 Anchorage, Alaska 99519-6612 Dec 11, 2009 {^ ~,~~~, ~~I,; ~. ~~' Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corroslon Inhlbltor Treatments of GPB Pad B ~~~-®~3 Dear Mr. Maunder, ~~~ ~-~ ~~ ~ ~a3~~ • `_p ~`r~ ~_,, lq~-~s7 _~-r3~ Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad B 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, at 659-5102. Sincerely, 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) Date: 12/11/09 Well Name PTD # API # Initial to 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 B-01 1700080 50029200590000 Sealed Conductor NA NA NA NA NA 8-02 1961110 50029200660100 Sealed Conductor NA NA NA NA NA B-03A 1870480 50029203060100 NA 0.5 NA 3.40 8/20/2009 B-04 1700320 50029200720000 Sealed Conductor NA NA NA NA NA B-058 2010680 50029202760200 NA 1.8 NA 13.60 8/22/2009 B-O6 1770740 50029202790000 NA 1 NA 5.10 8/20/2009 B-07 1780020 50029202850000 NA 1 NA 5.10 8/20/2009 B-08 1780410 50029203140000 NA 1 NA 6.80 8/20/2009 B-09 1780490 50029203160000 NA 0.5 NA 3.40 8/20/2009 B-10A 2082050 500292032101 ~ Cellar liner welded to casin NA NA NA NA NA B-11 1780690 50029203310000 NA 0.5 NA 3.40 8/20/2009 &12 8-13 8-14 1970090 1990570 2090590 50029203320100 50029203410100 50029203490000 NA NA NA 0.6 0.4 0.4 NA NA NA 3.40 1.70 1.70 8/22/2009 8/20/2009 8/20/2009 B-15 1790190 50029203600000 NA 0.1 NA 1.70 8/20/2009 B-16 1790250 50029203650000 NA 0.8 NA 5.10 8/21/2009 B-17 1790280 50029203680000 NA 0.1 NA 1.70 8/20/2009 B-18 1820020 50029207020000 NA 1.5 NA 15.30 8/21/2009 B-19 2001610 50029207030100 NA 0.1 NA 1.70 8/21/2009 B-20 1821680 50029208420000 NA 0.5 NA 3.40 8/21/2009 B-21 1821760 50029208500000 25 4.5 BBLs 0.1 11/30/2009 1.70 12/3/2009 B-22A 2001570 50029207590100 34 6.5 BBLs 0.2 11/30/2009 1.70 12/3/2009 B-23 1970590 50029207790100 12 2.2 BBLs 3.2 11/30/2009 10.20 12/4/2009 B-24 1821400 50029208150000 NA 3 NA 22.10 8/21/2009 B-25 1821510 50029208260000 NA 0.25 NA 1.70 8/13/2009 B-26 2000570 50029209760200 NA 0.3 NA 1.70 8/21/2009 B-27 1961010 50029214710100 Sealed Conductor NA NA NA NA NA B-28 1853030 50029215100000 NA 1.1 NA 6.80 8/22/2009 B-29 2002090 50029215230100 NA 0.7 NA 6.80 8/21/2009 B-30 2011050 50029215420100 NA 0.2 NA 1.70 8/21/2009 B-31 1910460 50029221520000 NA 0.3 NA 1.70 8/20/2009 B-32 1991180 50029221650100 NA 0.3 NA 1.70 8/20/2009 B-33 1931450 50029223390100 NA 1.2 NA 8.50 8/21/2009 B-34 1930370 50029223520000 NA 1.2 NA 10.20 8/21/2009 B-35 1931460 50029224060000 NA 0.3 NA 1.70 8/20/2009 B-36 1960650 50029226670000 NA 0.3 NA 1.70 8/21/2009 B-37 2071450 50029233750000 Sealed Conductor NA NA NA NA NA B-13A (PTD #1990570) Internal~iver Cancellation -Not Operable Well Page 1 of 1 Re James B DOA • 99, ( ) From: Lau, John, Jack [IaujjO@BP.com} on behalf of NSU, ADW Well Integrity Engineer ~~ +~~?~~~ [NSUADWWeIIlntegrityEngineer@BP.com] )1 Sent: Monday, December 31, 2007 9:13 AM To: NSU, ADW Well Operations Supervisor; Rossberg, R Steven; GPB, GC3 Wellpad Lead; GPB, Area Mgr Central (GC1/3/FS3); GPB, GC3 OTL; GPB, Wells Opt Eng; GPB, Optimization Engr; Engel, Harry R; Regg, James B (DOA); Maunder, Thomas E (DOA); GPB, Prod Controllers Cc: Subekti, Herry; Schmoyer, AI; NSU, ADW Well Integrity Engineer; NSU, ADW WI Tech; Lau, John, Jack; Holt, Ryan P (ASRC); Dahlem, Jason E; Culpepper, Jerry K. (Orbis); Boyles, Gerald J Subject: B-13A (PTD #1990570) Internal Waiver Cancellation -Not Operable Well All, An internal waiver was issued for a Production Casing leak on produced water injector B-13A (PTD #1990570) on 05/17!06. The dispensation from the Well Integrity System Policy for this well has expired. Please ensure the well has been shut-in by the end of today and arrangements have been made to freeze protect the well. The well has been reclassified as Not Operable. A secure program will be sent shortly. Please remove all Waivered well signs and the laminated copy of the waiver from the wellhouse. A letter requesting cancellation of the corresponding AOGCC Administrative Approval 3.008 will be signed and mailed this '~ week. Please calf if you have any questions. Thank you, Jack Lau (for Anna Dube) Well Integrity Coordinator Office: (907) 659-5102 Pager: (907) 659-5100 x1154 ~°~ JAN ~ 4 200$ 1 i 17/2008 MEMORANDUM . TO: Jim Regg D l ( P.I. Supervisor ".t!fq .~. z, 01 FROM: Lou Grimaldi Petroleum Inspector Well Name: PRUDHOE BAY UNIT B-13A Insp Num: mitLG070130]90016 ReI Insp Num State of Alaska . Reviewed By: P.I. Suprv .::fß.e-- Comm API Well Number 50-029-20341-01-00 Permit Number: 199-057-0 Inspector Name: Lou Grimaldi Inspection Date: 1/30/2007 Notes Standing valve set at ]0251 (WLM) for reg compliance Tubing test. A::r-o 300 1S - Alaska Oil and Gas Conservation Commission DATE: Wednesday, January 31, 2007 SUBJECT: Mechanical Integrity Tests BP EXPLORA nON (ALASKA) INC B-I3A PRUDHOE BA Y UNIT B-I3A Src: Inspector NON-CONFIDENTIAL Å:.t\^w&. /vU.;rr M.vro k ) Wednesday, January 31,2007 scANNED FES 0 7 2007 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 8243 IA 10 10 10 10 P.T. 2500 OA 10 10 10 10 2490 2410 2380 Page I of I e 1fi%1fŒ (ID~ ~~~~æ~ e AI/ASIiA OIL A1Q) 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 ADMINISTRATIVE APPROVAL AIO 3.008 Mr. Steve Rossberg Wells Manager BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 t( RE: PBU B-13A (PTD 199-057) Request for Administrative Approval Dear Mr. Rossberg: In accordance with Rule 9 of Area Injection Order ("AIO") 003.000, the Alaska Oil and Gas Conservation Commission ("AOGCC" or "Commission") hereby grants BP Explora- tion (Alaska) Inc. ("BPXA")'s request for administrative approval to continue water in- jection in the subject well. AOGCC finds that BPXA has elected to perform no corrective action at this time on PBU B-13A. The Commission further finds that, based upon reported results of BPXA's diag- nostic procedures, PBU B-13A exhibits two competent barriers to release of well pres- sure. Accordingly, the Commission believes that the well's condition does not compro- mise overall well integrity so as to threaten the environment or human safety. AOGCC's administrative approval to continue water injection in PBU B-13A is condi- tioned upon the following: 1. BPXA shall record wellhead pressures and injection rate daily; 2. BPXA shall submit to the AOGCC a monthly report of well pressures and injec- tion rates; 3. BPXA shall perform an annual MIT - OA to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; 4. BPXA shall perform an annual MIT - T to 1.2 times the maximum anticipated well pressure, the anniversary date of which shall be this approval's effective date; ... e e Mr. Steve Rossberg March 31, 2006 Page 2 of2 5. BPXA shall limit the well's OA pressure to 1000 psi; 6. BPXA shall immediately shut in the well and notify the AOGCC if there is any change in the well's mechanical condition; and 7. after well shut in due to a change in the well's mechanical condition, AOGCC ap- proval shall be required to restart injection. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is consid- ered 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. ge, Alaska and dated March 31, 2006 ~ Commissioner 1/7 f ' I 1; ~. ~\ \ \, " BP Exploration (Alaska) Inc. _ Steve Rossberg, Wells Manager- Post Office Box 196612 Anchorage, Alaska 9951 9-661 2 e Mr. John Norman, Chairman Alaska Oil and Gas Conservation Commission 333 West ih Avenue Anchorage, Alaska 99501 RECEIVED March 16,2006 !itiJ 2 0 '1·006 ¡VIMI\ o. Subject: Alaska Oi! & Gas Cons. Commission Prudhoe Bay Unit B-13A (PTD 1990570) . . Anchorage Request for Administrative Approval to Continue Water nJection Operations Dear Mr. Norman, BP Exploration (Alaska) Inc. requests approval to continue water injection operations into well B-13A. Well B-13A has a production casing leak as indicated by a failed MITIA conducted on 11/04/05. However, two competent barriers have been established and thus it is BP's contention that the well can be safely operated. These barriers are competent production tubing and surface casing that have passed pressure tests to 1.2 times the maximum anticipated injection pressure. Observed annulus operating pressures do not exceed 45% of the casing's rated burst pressure. The proposed operating and monitoring plan (attached) includes the following: 1. Daily recording of surface pressure and injection rate 2. Mechanical integrity testing on an increased frequency 3. Increased reporting to the AOGCC through the Monthly Injection Report If one of the competent barriers should become compromised, the well will be shut in, the Commission notified and physical corrective options will be evaluated. The proposed operating and monitoring plan is based on sound engineering and operating practices, and is consistent with Area Injection Order 3, Rule 9. In addition, there is no source of underground drinking water; therefore, no USDW is endangered. It is BP's contention that approval of this request will provide safe operating conditions, is in the best interests of the GPB working owners and the State of Alaska. If you require any additional information, please contact me at 564-5637 or Joe Anders / Anna Dube at 659-5102. Sincerely, Attachments Technical Justification for Administrative Approval Request Wellbore Schematic TIO Plot ORiGINAl e e Prudhoe Bay Unit B-13A Technical Justification for Administrative Approval Request March 16, 2006 Well History and Status Prudhoe Bay Unit well B-13A (PTD 1990570) is a produced water injection well with a production casing leak. An MIT-IA failed on 11/04/05, leak rate of 5 bpm @ 2250 psi. A MIT-T passed to 2500 psi on 12/24/05 and an MIT-OA passed to 2500 psi on 02/26/06. These passing MIT's demonstrate competent tubing and surface casing. Recent Well Events: - 11/04/05: MITIA Failed - 12/24/05: MIT-T Passed to 2500 psi. - 01/29/06: LDL finds possible holes @ 3002' & 3700', LLR = 5 bpm @ 2250 psi - 02/26/06: MIT-OA Passed to 2500 psi. Barrier and Hazard Evaluation The well has two competent well barrier systems to prevent the atmospheric release of fluids and to safely operate the well. The primary barrier is the production tubing. In the event of a leak, the secondary well barrier system composed of the surface casing will contain any pressure. Both of these systems have been pressure tested to at least 1 .2 times the maximum anticipated injection pressure to ensure competency. Barrier competency is monitored using wellhead pressure plots (TIO plot), Pressure / Rate plots and periodic pressure tests to 1.2 times the maximum anticipated injection pressure. Primary Well Barrier System: Production tubing competency is demonstrated by the passing MIT-T to 2500 psi on 12/24/05. Primary well barrier system competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor pressure trends and by conducting an annual MIT-T. In the event of a production tubing leak, IA pressure would increase to the injection pressure, providing notification of a compromised primary well barrier and initiating a well review. Secondary Well Barrier System: Surface casing competency is demonstrated by the passing MIT-OA to 2500 psi on 02/26/06. Competency will be monitored by daily annulus pressure observations, by frequent review of a TIO plot to monitor trends and by conducting an annual MIT -OA. Thermal Overpressure of the OA: Maximum allowable OA pressure will remain at 1000 psi. In the event of a shallow production casing leak, an OA pressure increase would be observed by the Operators conducting daily well inspections and the well would be shut- in. Injection fluid temperatures are warmer than the we II bore temperatures to the depth of the surface casing shoe. This results in the well cooling off when shut-in, preventing thermal overpressure. e e Mechanical Condition: The production casing is not considered a component in the wel barrier systems. The production tubing and surface casing are the 2 competent well barrier systems and have been confirmed. The well will be shut-in at any indication of barrier competency loss. Proposed Operating and Monitoring Plan 1 Initiate water injection. 2 Record wellhead pressures and injection rate daily. 3 Submit a report monthly of well pressures and injection rates to the AOGCC. 4 Perform an annual MIT-T to 1.2 times maximum anticipated injection pressure. 5 Perform an annual MIT-OA to 1.2 times maximum anticipated injection pressure 6 Notify the AOGCC if there is any indication of a change in well mechanical condition Ii I: TREE = 7-1/16" CWV I.' WELLHEAD = McEVOY . ACTUA TOR = OTIS KB. ELEV = 64.16' SF. El..E'i;" 37.72' KOP= 3100' Max Angle = 100 @ 11235' Datum MD = 11880' Datum lVD = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" I 17" TBG, 26 #, IJ4S, .0383 bpf, ID = 6.276" I ITOP 5-1/2" TBG I Minimum 10 = 2,37" @ 10255' 2-7/8" ST-L LINER TOP j .j :IL5;1/2" TBG, 17#, NT-80S NSCC, .02324 bpf, ID = 4.892" -i 9785' I ! TOP4-1/2" TBG I 9785' I TOP OF 7" BOT LNR HGR TIEBACK SL V I 9844' , 1 ¡ f í [ l.- I:, ,. ~:~,- I ¡ B-13A SAF NOTES: TWV PKRS IN WELL MAY FAIL IF 2100 PSI DIFFERENTIAL IS EXCEEDED. WELL> 70 DEG @ 10770' AND GOES HORIZONTAL @ 10860'. -19 5/8" FOC I -i 7" OTIS SSSVN, ID = 3.813" (W/INSERT) I -i 9 518" DV PKR , - 7" U4S X 5-1/2" TC4S XO, ID = 4.892" I 3241' - 9 5/8"x 7 5/8" TWV LNR HGRI TIEBACK I I - - 5 1/2" NSCC X 41/2" TDS XO, ID = 3.958" 9798' -i4-1/2" PARKERSWSNIP, ID=3.813" I 9807' -i 7-518" TWV (HBBR-R) REm PKR, ID = 3.890" 9855' -7" BOT TIEBACK SEAL ASSY I 10251' - 3.75" BKR LNR DEPLOY SL V, ID = 3.00" I TOP OF 27/8" LINER, ID = 2.37" I 19-5/8" CSG, 47#, L-80, ID = 8.681" I DATE REV BY COMMENTS 12/14/05 DAV/PJC SSSVNC/O 14-1/2" TBG, 12#, TDS, .01521 bpf, ID = 3.958" I ÆRFORA TION SUMMARY REF LOG: PDS MEMORY INDUCTION ON 09/04/99 ANGLEATTOPÆRF: 88 @ 11630' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2" 6 11630 - 11650 0 09/23/00 2" 6 11690 - 11710 0 09/22/00 2" 4 11990 - 12010 C 09/09/99 2" 4 12049 - 12070 C 09/09/99 17" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I 11032' DATE 01/17179 06/22/91 09/09/99 07/22/01 09/19/01 11/27102 REV BY COMMENTS ORIGINAL COMPLETION RWO CTDSIDETRACK (B-13A) CHlTP CORRECTIONS DBM/KK CIBP & FISH JW/KAK CLOSE ÆRFS 10538' - 7' TWV (HBBP) PKR, ID = 4.00" I 10548' -14-1/2" PARKER SWS NIP, ID = 3.813" 10559' -4-1/2" PARKER SWS NIP, ID = 3.813" 10568' -14-1/2"TUBINGTAIL WLEG I 10565' -I ELM TUBING TAIL I 7" MILLOUT WINDOW 10605' - 10612' 2-7/8" LNR, 6.16#, L-80, SL- T, .0058 bpf, ID = 2.37"" - 12118' I PRUDHOE BA Y UNrr WELL: B-13A ÆRMrr No: "1990570 API No: 50-029-20341-01 SEC 31, TUN, R14E, 1740' SNL & 1608' WEL BP Exploration (Alaska) , . r e e B-13 TIO Plot 4,000 _u___n_n___ T o 3/16/2005 7/16/2005 9/16/2005 .. Tbg ·.IA .;~J {-': ~~ i 1/ i~ [J Schlumberger FEB 22 tN:6 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth -.. ,JV:i_. ---·¡Ji~~:n~:j.S!aL A:1c~{)ragc Well Job# Log Description Date BL 13-31A ":;>05- i~D 11162828 MEM JEWELRY & PRESSURE SURVEY 01/07/06 1 DS 18-03B ~03 ~Of'.("" 11057071 SBHP SURVEY 12102/05 1 NK-43 rQ61-CO 10987562 SBHP W/SPINNER PASSES 01/07/06 1 B-13A /0/7' - 05] 11183463 LEAK DETECTION LOG 01/28/06 1 DS 06-22A ¡q ?X-C 5 7 N/A SENSAlMEM LDL 01/28/06 1 DS 11-26 Iß(o'~ 134- 11183462 INJECTION PROFILE 01128/06 1 P1-09 J 9~·, is 1- 11098756 PROD PROFILE W/DEFT & GHOST 01/30/06 1 L5-05 Jr.7-C(cC¡· 11058541 RST 11/11/05 1 Z-29 i e;q -C(ðÇ' 11051081 RST 08/10/05 1 L5-09 IC¡C -/~ 11090725 RST 11/11/05 1 15-44 ,qú - II ð 11194155 RST 01/15/06 1 C-20B ..;(01-1 /4- 11075913 MCNL 08/29/05 1 02-14A Q03 ~ 1~5 11075901 MCNL 07/29/05 1 Z-21A -901- ìO f 11076449 RST 06/30/05 1 F -27 A c205-/a4- 10928641 MCNL 09/01/05 1 MPH-15 ~?cr:5 - 15'1 11076486 USIT 12/15/05 13-31A -::)C5-IIßÖ 11133211 SCMT 12/23/05 WGI-04 J 71 - o5t-") 11183461 USIT 01/26/06 WGI-04 /'7 q - c· .s?). 11211566 USIT 02/03/06 WGI-08 14e--- 044 10987559 USIT 01/02/06 WGI-08 ;C,O-C49 11058259 USIT 01/12/06 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 f" = &~ .1.·.·,. ~ 2. G G ß ~ì E . F bJj :~ 'J 5Ci~Nè~:"'~; . Date Delivered: .?,} ,)7 ( 0 Lr I 02/09/06 NO. 3677 Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color CD ~ 1 1 1 1 1 1 1 1 1 1 1 1 1 1 '-" Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Î" ~"\ Received by: t~QQ() ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska) Inc. Prudhoe Bay / PBU / B 07/05/03 Pat Lattner John Crisp WelI IB-13A P.T.D. I1990570 Notes: P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: WellI P.T.D.I Notes: Type Inj. Type Inj. Type Type Inj Type Inj Packer Depths (ft.) Pretest Initial 15Min. 30 Min. Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 5CANNEE;;' SEF 0,9 2003 2003-0705._MIT_PBU_B-13.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner THRU: Jim Regg /~L¢~Cl P.I. Supervisor FROM: DATE: July 5, 2003 --\~'"~,\'1'\~'-~ SUBJECT: Mechanical Integrity Tests BPX Prudhoe Bay Field B Pad John Crisp Petroleum Inspector NON- CONFIDENTIAL Prudhoe Bay Field Packer Depth Pretest Initial 15 Min. 30 Min. I We,,IB-13AITypelnj.IS I T.V.D. I Tubingl6ooI I I IIntervall4 I P.T.D.I 1990570 ITypetestl P ITestpsil 2000 I Casingl 30 I 2460 I 2420 I 2380 I P/FI PI Notes: CA psi. 120 4.9 BBL. Pumped IA pressure stabilized from 2380 to 2360 after 45 minutes. - ~ We,I I TypeInj. P.T.D. I Type test Notes: WoIII I Type Inj. P.T.D. I Type test Notes: WellI I Type Inj. P.T.D. I Type test Notes: Notes: Type Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R- Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) M.I.T.'s performed: 1 Attachments: Number of Failures: 0 Total Time during tests: 1.5 hrs. MIT report form 5/12/00 L.G. ;CANNED,', AUG 0 & 2003 2003-0705_M IT_PB U_B- 13A_jc.xls 7/17/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ CIBP Pull tubing _ Alter casing _ Repair well _ Other_X CIBP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 5. Type of Well: Development __ Explorato~__ Stratigraphic__ Service__X 4. Location of well at surface 1740' FNL, 1608' FEL, Sec. 31, T11N, R14E, UM At top of productive interval 3869' FNL, 870' FEL,'Sec. 36, T11N, R13E, UM At effective depth 3746' FNL, 292' FEL, Sec. 36, T11N, R13E, UM At total depth 5103' FNL, 321' FEL, Sec. 36, T11N, R13E, UM (asp's 671351, 5975592) (asp's n/a) (asp's 674415, 5981287) (asp's 674755, 5981642) 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" x 30" Surface 2660' 13-3/8" Intermediate 10310' 9-5/8" Tieback Liner 1074' 7-5/8" Liner 761' 7" Side Track Liner 1866' 2-7-8" 12245 feet Plugs (measured) 8960 feet 11800 feet Junk (measured) 8913 feet Cemented 454 c.f. Permafrost 5766 c.f. Permafrost 1062 cf 'G', 365 cf PFC 230 c.f. Class 'G' 517 c.f. Class 'G' 6. Datum elevation (DF or KB feet) RKB 64 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number B- 13Ai 9. Permit number / approval number 50-029-20341-01 11. Field / Pool Prudhoe Bay Oil Pool ClBP set @ 11800'(09/20/2001) Measured Depth True VerticalDepth 136' 136' 2686' 2686' 10336' 8633' 3241'-9855' 3235'-8268' 9844'-10605' 8268'-8805' 10251'-12117' 8550'-8923' Perforation depth: measured Open Perfs 11990'- 12010', 12049'- 12070' true vertical Open Perfs 8884' - 8890', 8901' - 8908' Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 7", 26#, L-80 TBG to 3162'; 7" x 5-1/2" @ 3162'; 5-1/2" 17#, NT-80S,3162' - 9787'; 4-1/2" 12.6#, L-80, 9787'- 10567'. 7-5/8" x 4-1/2" TIW HBBP-R Packer @ 9807'; 7" x 4-1/2" TIW HB-BP Packer @ 10538'; 7" Otis 'RPB' BVN @ 2112'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation 09/09/2001 09/23/2001 OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl 4673 3609 Casing Pressure Tubing Pressure 744 724 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil __ Gas __ Suspended __ Service Water & Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. R. Andy Parker Form 10-404 Rev 06/15/88 · Title: B Pad Surveillance Enginee~ September 24, 2001 Prepared b~/DeWayne R. Schnorr 564-5174 "~'.;;;;:~' ~l ;:]: t ;;;;;; .;,;.;?:.', SUBMIT IN DUPLICATE 09/11/2001 09/11/2001 09/12/2001 09/13/2001 09/17/2001 09/18/2001 09/19/2001 09/11/01 09/11/01 09/1 2/01 09/13/01 09/17/01 09/18/01 B-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS INFLATABLE BRI INFLATABLE BRI INFLATABLE BRI INFLATABLE BRI INFLATABLE BRI INFLATABLE BRI INFLATABLE BRI DGE PLUGS: DGE PLUGS: DGE PLUGS: DGE PLUGS: DGE PLUGS: DGE PLUGS: DGE PLUGS: PULL 4 1/2" MCX AND DRIFT DRIFT LINER, RUN CIBP - DAY 1 DRIFT LINER, RUN CIBP - DAY 2 MILL CIBP / SET CIBP MILL CIBP/SET CIBP MILL CIBP, PUSH TO BOTTOM, RUN CIBP MILL CIBP, PUSH TO BOTTOM, RUN CIBP EVENT SUMMARY PULL MCX (SERIAL # M-35) FROM BVN @ 2086' WLM -- DRIFT W/3' 2 1/8" STEM TO 10236' WLM, HUNG UP, BROKE FREE (HAD 3 CHUNKS OF METAL APPROX. 1" SQUARE & 3/8" THICK INSIDE MCX SSSV) MIRU CTU #3. RIH W/2.25" JSN TO DRIFT LINER. TAG UP ON OBSTRUCTION IN 2-7/8" LINER AT 11079' CTM. COME ON LINE W/SLK 1% KCL AND JET/PUSH OBSTRUCTION DOWNHOLE. TRYING TO GET DRIFT NOZZLE PAST 11657' CTM AT END OF REPORT. [Plug-Abandon Perfs] WORK 2.25" DRIFT NOZZLE TO 11830' CTM. POOH. RIH W/2.2" CIBP. WORK INTO LINER TOP W/SLIGHT BOBBLE. SD IN LINER AT 10895', PUH, REPEAT TAG. PUH TO 10880'. FLUID PACK COIL W/SLK 1% KCL. ACCIDENTAL SET OF CIBP. POOH TO CHECK TOOLS. NO ABNORMAL DEBRIS IN TOOL. RIH W/1.69" WEATHERFORD MOTOR & 2.25" MILL. MILL & CHASE CIBP DOWNHOLE. [Plug- Abandon Perfs] MILL/PUSH CIBP REMNANTS TO 11290'. UNABLE TO MOVE PLUG FURTHER DOWNHOLE. POOH TO CHECK TOOLS. MILL WORN WITH MISSING CUTRIGHT. FREEZE PROTECT TUBING. [MILL] MIRU CTU #3. CUT 210' CT. WELD ON CT CONNECTOR. MU BAKER TS: 2 1/8" MOTOR/2.25" JUNK MILL. RIH. TAG FISH @ 11287'. ATTEMPT TO ESTABLISH PATTERN. BLEED WHP TO O PSI. ATTEMPT TO MILL AHEAD W/2.25" MILL ON 2-1/8" MOTOR. MULTIPLE STALLS AND OVER-PULLS. POOH, LD MILL, RIH WNENTURI BASKET AND 2.22" BURN SHOE ON 2-1/8" MOTOR. WORK VENTURI DOWN TO 11,848' CTDM, SLIGHT OVERPULL OFF BTTM. POOH MAINTAINING 1.4 BPM. RECOVER CIBP SLIPS. RIH W/CIBP. UNABLE TO GET INTO 2-7/8" LINER. POOH W/CIBP - DAMAGE TO BTTM OF PLUG, LEFT SLIPS AND ELEMENT IN HOLE. RIH WNENTURI BASKET. Page I 09/19/01 B-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS VENTURI WAS FULL, CONTAINED ALL PIECES TO CIBP PACKER RUBBER AND 9 SLIPS. MU CIBP SETTING TS W/HYD CENTRALIZER. RIH W/CIBP. PARK @ 11805', DROP 0.5" BALL. PULL TO 11800'. SET CIBP @ 11800'. TAG TO VERIFY SET. POOH. PUMP DOWN COIL/TBG IA - ESTABLISH INJECTIVITY @ 4.5 BPM - 700 PSI. RDMO. **NOTIFY DSO TO PUT BACK ON INJECTION.** FLUIDS PUMPED BBLS I PRESSURE TEST LUBRICATOR WI1 BBL OF DIESEL, (1 TESTS) 80 METHANOL 10 GEL 942 1% KCL W/J-313 267 1% KCL WATER W/SLICK 110 1.5# BIOZAN W/1% KCL 1437 TOTAL Page 2 199-057-0 PRUDHOE BAY UNIT Roll #1: Start: Stop Roll #2: MD 12245 TVD 08960' Completion Date: B-13A 50- 029-20341-01 BP EXPLORATION (A~LASKA) mC Start.. Stop /-~~7/99 Completed Status: WAG1N Current: T Name C 9884 D 9548 D 9549 L IL~ L NGP-MD NGP-MD L NGP-TVD NGP-TVD Interval ~-FINAL 10294-11987 Digital Data 1-6 SPERRY GR SPERRY GR PB1 FINAL 10450-12234 FINAL 10601-12245 FINAL 10601-10828 PB1 FINAL 8738-8905 FINAL 8738-8831 PB1 L WFL/Bomx/PSPIPROF'C~'F~XL 10200-12004 BL, Sepia R SRVY LSTNG~ BHI 10500-12245. R SRVY RPT-J' SPERRY 10500-12245. Sent Received T/C/I) · CH 2/7/01 2/14/01 OH 5/11/00 5/16/00 OH 5/11/00 5/16/00 OH 9/9/99 9/9/99 D OH 2/5 5/11/00 5/16/00 OH 2/5 5/11/00 5/16/00 OH 2/5 5/11/00 5/16/00 OH 2/5 5/11/00 5/16/00 CH 5 2/7/01 2/14/01 OH 10/6/99 10/6/99 OH 10/6/99 10/6/99 Wednesday, June 20, 2001 Page 1 of 1 · STATE OF ALASKA ALASK,~¢~IL AND GAS CONSERVATION C~-MMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown []Stimulate [] Plugging [] Perforate [] Pull Tubing [] Alter Casing [] Repair Well []Other Schmoo B Gone 2. Name of Operator 15. Type well: 6. I-afl Development BP Exploration (Alaska)Inc. i [] Exploratory 3. Address [] Stratigraphic 7. P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Service 4. Location of well at surface 8. 1740' SNL, 1608' WEL, SEC. 31, T11N, R14E, UM 9. At top of productive interval 3869' SNL, 870' WEL, SEC. 36, T11N, R13E, UM 10. At effective depth 3746' SNL, 292' WEL, SEC. 36, T11N, R13E, UM 11. At total depth 5103' SNL, 321' WEL, SEC. 36, T11N, R13E, UM Datum Elevation (DF or KB) KBE = 64.16' AMSL Unit or Property Name Prudhoe Bay Unit Well Number B-13Ai Permit Number / Approval No. 199-057 APl Number 50-029-20341-01 Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 12245 feet true vertical 8960 feet Effective depth: measured 12085 feet true vertical 8913 feet Casing Length Size Structural Conductor 84' 20"x 30" Surface 2660' 13-3/8" Intermediate 10340' 9-5/8" Production Liner 761' 7" Tieback Liner 6603' 7~5/8" Side Track Liner 1866 2-7/8" Plugs (measured) Junk (measured) Original 7" liner was permanently abandoned below 10605'. Cemented MD TVD 454 cu ft Permafrost 110' 5766 cuft Permafrost 2686' 1062 cu ft Class 'G', 365 cu ft PF 'C' 10366' 517 cu ft Class 'G' 230 cu ft Class 'G' 110' 2686' 8633' 9844'-10605' 8268'-8805' 3241'-9844' 3235'-8268' 10251'o12117' 8550'-8923' Perforation depth: measured true vertical Open Perfs 11990' - 12010', 12049' - 12070' Open Perfs 8884' - 8890', 8901' - 8908' Tubing (size, grade, and measured depth) 7", 26#, L-80 to 3162'; 5-1/2", 17#, NT-80S, 3162' - 9787'; 4-1/2", 12.6#, L-80, 9787' o 10567' . Packers and SSSV (type and measured depth) 7-5/8" TIW HBBP-R retrievable packer at 9807'; 7" TIW HB-BP packer @ 10538'; 7" Otis 'RPB' BVN at 2112' 13. Stimulation or cement squeeze summary See Attachment Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil [] Gas [] Suspended Service Water & Gas Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed .~,,~ Scott LaVoie ~------~ ~'"~ Title Technical Assistant Prepared By Name/Number: Date ~"/f,,~ /' OeWay,,e .¢ckn/orr 56;~-5 ~ Z4 Form 10~404 Rev. 06/15/88 Submit In Duplicate B-13A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 01/20/2001 SCHMOO B GONE: SCHMOOBGONE TREATMENT 02/25/2001 SSSV C/O OR STROKE: SET ISSSV SUMMARY 01/20/01 PUMP SCHMOOBGONE TREATMENT ON TUBING. F/P TBG & LATERAL. TURNED OVER TO PAD OPERATOR 02/25/2001 R.I.H. W/6.0 G.R. TO 2083 {SLM} AND SAT ISSSV. Fluids Pumped BBLS. Description 29O SCHMOO 86 MEOH 376 TOTAL WELL LOG TRANSMITFAL To-. State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs May 11, 2000 B-13APB1, AK-MW-90135 1 LDWG formatted Disc with verification listing. API#: 50-029-20341-70 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO Ting ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 RECEIVED Date: MAY 1 & 2000 Alaska Oil & Gas Cons. Commission Anchorage Signed: 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company EIRI LLI I~1 B C;ERVIEEc; To: WEI,I, LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs: B-13A B-13APB1 May 11, 2000 AK-MW-90150 AK-MW-90135 B-13A: 2" x 5"MD Gamma Ray Logs: 50-029-20341-01 2"x 5" TVD Gamma Ray Logs: 50-029-20341-01 B-13A PBI: 2" x 5" MD Gamma Ray Logs: 50-029-20341-70 2" x 5" TVD Gamma Ray Logs: 50-029-20341-70 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia 1 Blueline 1 Rolled Sepia PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING THE ATYACHED COPIES OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Atto: Jim Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 RECEIVED Daisy ~ g 90130 '$'l'!f'~ I ',,' --- - - ~aska 0ii & Gas Cons. ~0mm~smr. ' Anchorage BP Exploration (Alaska) Inc. Petro-technical Data Cerner, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 . ) Sign 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax' 907-273-3535 a Halliburton company DRILLING =; E R~../I C E E~ WELL LOG TRANSMll3'AL To.- State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 PorCUpine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs B-13A, AK-MW-90150 1 LDWG formatted Disc with verification listing. APl#: 50-029-20341-01 May 11, 2000 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO ~ ATIlgNTION OF: Sperry-Sun Drilling Services Attn: JLrn Galvin 5631 Silverado Way, Suite G. Anchorage, Alaska 99518 Date: ~A¥ 1 6 ?.000 Alaska Oil & Gas Cons. commission Anchorago BP Exploration (Alaska) Inc. Petro-Technical Data Center, MB3-3 900 E. Benson Blvd. Anchorage, Alaska 99519-6612 Sign 5631 Silverado Way, Suite G · Anchorage, AK 99518 · 907-273-3500 · Fax: 907-273-3535 a Halliburton company STATE OF ALASKA ...... ALASKA ~IL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ~1 Oil I--1 Gas [] Suspended l--IAbandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska)Inc. 99-057 399-168 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 .~ 50-029-20341-01 4. Location of well at surface r. -. ................ "'..,~'! 9. Unit or Lease Name 1740' SNL, 1608' WEb, SEC. 31, T11N, R14E, UM I r~?J!'~'~!"~-~-:~'{i; Prudhoe Bay Unit Attop of productive intervali~~'~'' '- !~/4,~/~; 10. Well Number 3869' SNL, 870' WEb, SEC. 36, T11N, R13E, UM B-13Ai Attotal depth i .~~ ~ - 11. Field and Pool 5103' SNL, 321' WEb, SEC. 36, T11N, R13E, UM i.. ..... ................... Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE -- 64.16' AMSLI ADb 028286 7/8/99 9/4/99 9/9/99 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+T VD)II9. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 12245 8960 FT 12085 8913 FTI []Yes I--INoI (Nipple) 2112' MDI 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, POP, Memory Induction 23. CASING~ LINER AND CEMENTING RECORD CASING SETrlNG DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO-I-rOM SIZE CEMENTING RECORD AMOUNT PULLED 30"x 20" Insulated Conductor Surface 110' 36" 454 cu ft Permafrost 13-3/8" 72# L-80 Surface 2686' 17-1/2" 5766 cuft Permafrost II 9-5/8" 47# L-80 Surface 10366' 12-1/4" 1062 cuft Class 'G', 300 cuft PF 'C' 7-5/8" 29.7# NT-80S 3241' 9844' 8-1/2" 230 cuft Class 'G' (Tieback) 7" 29# L-80 9844' 10605' 8-1/2" 517 cuft Class 'G' 2-7/8" 6.16# L-80 10251' 12118' 3-3/4" 393 cu ft Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 4 spf 7"x 5-1/2", 17#, NT-80S 9787' 10538' MD TVD MD TVD 4-1/2", 12.6#, L-80 9787' - 10567' 9807' 11990' - 12010' 8884' - 8890' 12049' - 12070' 8901' - 8908' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 1500' Freeze Protect with 35 Bbls MeOH Date First Production JMethod of Operation (Flowing, gas lift, etc.) tl ~l~f,~ ¢,- ,i~.~i:';" September 15, 1999I Water & Gas Injector,-.,,-,-- 0ii & Gas, _ _~C°ns', _..~ ..omfr ........ Date of Test Hours Tested PRODUCTION FOR OIL-BBb GAS-MCF WATER-BBb CHOKE SIZE /~I~'-~E- RATIO TEST PERIOD ! Flow Tubing Casing Pressure CALCULATED OIL-BBb GAS-MCF WATER-BBb O~L GRAWTY-API (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sadlerochit 10600' 8801' 45N 10632' 8823' 45P 10636' 8826' 44N 10729' 8878' 44P 10734' 8880' 43N 10792' 8901' 43P 10798' 8902' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is ~ue and correct to the best of my knowledge Terrie Hubble _ Title Technical Assistant III Date B-13Ai 99-057 399-168 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5; Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). IT£M 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 2?: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 Well: B-13Ai 1st Accept: 07/05/99 2® Accept: 08/28/99 Field: Prudhoe Bay 1st Spud: 07/08/99 APl: 50-029-20341-01 1 st Release: 07/14/99 2® Release: 09/09/99 Permit: 99-057 CTD Unit: Nordic #1 iDate .....,.. 07/06/99 I 10450' MIRU equipment. N/U BOP stack. Install injector head. 07/07/99 2 10401' Stab CT into injector. Perform initial BOPE test. MU BHA. MU CTC. Fill CT with SW. Work on drilling monitor electronics. RIH with BHA #1 to clean out cement before starting window. Tag first cement at 10401' 07/08/99 3 10406' Drilled cement stringers at 10,401 and 10449 ft. Drilled firm cement from 10450 - 10601 ft. Stalled 3 times at top of whipstock at 10,601 ft. Flag CT and POOH. M/U BHA #2 with flex joint and 3.80" Concave Diamond Mill #1. Attempt to repair DS drilling screen information. No success. RIH with BHA #2. Mill cement to 10605' and window to 10609' where progress stopped. POOH to check mill. Found mill had cut about ~,~ of window. RIH with BHA #3 (3.80" dimple mill with 3.80" string reamer). Open window from 10605'. 07/09/99 4 10850' Reamed window from 10605 - 10608 ft. Continue milling window with 3.80" dimple mill and string reamer from 10608 - 10612 ft. Circulated in new FIoPro mud system. Reamer exited window at 10612 ft bit depth. Drilled 3.80" hole from 10612 -10618 ft. Reamed window area several times. RIH through window with no pump. Window is clean. POOH. Repaired DS drilling information package while POOH. Lay out milling BHA. M/U Drilling BHA with 2.75 deg bent motor and M09 Bit #1. RIH with BHA #4 thru window, clean. Drill ahead building angle and turning left from 10618-684'. Backream to window and tie-in to BHCS at 10604' (add 4.0'). Drill ahead building angle and turning left from 10684-850'. Landed at 90 deg at 8832' TVD. POOH for horizontal drilling assy. 07/10/99 5 11100' Finish POOH for horizontal drilling assembly. M/U 1.0 deg. motor and DS49 bit. RIH with BHA #5. Correct depth to flag. RIH thru window easily. RIH to TD. Orient TF to 90L. Drill horizontal hole from 10850 - 10982 ft. Short trip due to stacking weight. RIH and drill horizontal hole from 10982 - 11040 ft. Lost all returns at 11040 ft. Drilled 60 ft. to 11,100 ft with no returns. POOH. Lay out drilling BHA. M/U Jetting nozzle to place DS Instanseal LCM product. RIH with BHA #6. Correct to flag at 10,500' EOP. RIH thru window to TD at 11100'. PUH and park at window. DS mix and pump 25 bbls InstasealTM. RIH with CT to PBD and displace with rig mud while laying in at zone of loss. Pull into casing. Fill hole with 150 bbls fluid and had no returns. RIH to PBD to check hole condition, clean. DS mix 45 bbls InstasealTM. Displace with rig mud at zone of loss. Pull into casing. Fill hole down backside with 55 bbls of fluid and had 1/1 returns. Swap to CT and had no returns. POOH for cementing nozzle. B-13Ai, Coil Tubing Drilli%__ Page 2 07/11/99 6 11110' POOH for cementing nozzle. M/U cementing BHA. RIH with BHA #7. Tag TD at 11,101 ft. Pull to window. R/U cementers. Held Safety Meeting. Mix 29 BBL of 8% Bentonite / 6i cement slurry with 17 PPB aggregate. Cement at wt at 11:00 hrs. Pump 29 BBLS of 13.5 PPG Cmt and displace with rig pumps. Lay in cement from 11080 - 10650 ft. POOH to safety with no pump. POOH pumping 0.3 BPM. L/O cementing BHA. M/U Drilling BHA #8. Wait on cement for 1 hour. DS lab sample at 190 PSI. RIH with BHA#8. RIH thru window. Precautionary ream to TD. Recovered partial returns just above zone of loss. Drilled 10' of new hole to 11110' with 2.5 bpm in and 0.3 bpm out. Backream to window. POOH for cementing assy. LD drilling BHA. MU cementing BHA. RIH with BHA CF3 to TD. Hole is clean. PUH to window. Mix cement. 07/12/99 7 11110' Held Safety Meeting. Mixed Cement. Staged 26 BBL, 8% Bentonite / G Cmt with 18 PPB Aggregate at 13.8 PPG. Displaced cement with FIoPro. Lay in cement from 11,090 - 10,650 ft, at 1.5 - 1.0 BPM. No returns during cement job. POOH to 8000' with no pump. POOH to surface with 0.3 BPM. L/O Cmtg BHA. M/U drilling BHA #10. RIH. Shallow test MWD, OK. RIH with full returns below 3000 ft. Found top of CMT plug at 10700'. Drilled cement to 10750 ft and WOC one hour. Held Weekly Safety Meeting with crew. Oriented TF and RIH. Drilled cement from 10750 - 11080 ft with full returns. Lost 1.1 BPM at 2.6 BPM pump rate drilling at 11085 ft. Drilled to TD of 11,110 ft. Reamed hole from 11,000 - 11,110 ft. Mud loss steady at 1.1 BPM. POOH for cementing assy. LD drilling assy. MU cementing BHA. RIH with BHA #11 to TD losing 1/2 returns. DS mix and pump 26 bbls of same cement as above. Displace with rig mud and lay in over zone of loss. Returns were nearly 1/1. POOH for drilling BHA. LD cementing BHA. MU drilling BHA. RIH with BHA #12 getting full returns. Tag at 10630'. Drill firm cement at 4'/min with full returns to 10850'. 07/13/99 8 11140' Continue drilling firm cement from 10850' with full returns until 11041'. Cleanout to TD at 11110' losing 0.2 BPM. Orient to drill ahead. Drill from 11110-140' and losses slowly increased to 0.7 bpm at rate. POOH for cementing BHA. LD drilling BHA. Cut off 300' CT. MU cementing BHA. RIH with BHA #13 to TD getting 3,4 returns. DS mix and pump 26 bbls 13.9 ppg Class G cement with 8% bentonite and 18 ppb Perfect Seal. Displace with rig mud to zone of loss and had full returns. POOH. LD cementing BHA. Perform weekly BOP test. MU drilling BHA. RIH with BHA #14. 07/14/99 9 11295' RIH with drilling BHA #14 to clean out cement. Tag top of CMT plug at 10750 ft. Drill CMT at 5 FPM. Held rig H2S Evacuation drill. All Personnel accounted for. Drill out cement to 11050 ft. with full returns. Add LubeTex to mud. Drilled to 11124 ft with full returns [84 ft past first fault] and lost 0.5 BPM. Drilled 11124 - 11224 ft with 0.5 BPM losses. Drilled 11224 - 11253 ft with 2.0 BPM losses. Drilled 11253 - 11280 ft with no returns. POOH. Decision to plug well and move off. TIH w/cement BHA and spot cement (3 bbl Neat, 20 bbl w/18 ppb aggregate, 3 bbl Neat). No returns while pumping cement, partial returns after 10 bbl cement out nozzle. Full returns ant end of job. Displace FIo-Pro w/seawater, POOH 07/15/99 10 Freeze protect tubing w/MeOH. Purge CT w/N2. Clean pits, ND BOP. Release Rig 18:00 Hrs. 7-14-99 B-13Ai, Coil Tubing Drilli% .... Page 3 08/29/99 1 10600' Complete derrick down rig move from F Pad to B Pad. Remove Booster wheels, Raise mast, raise wind walls and install BOP stack. Back over well. Accept rig on B-13ai at 08:00 hrs 08/28/99. NU BOPE and test same 250/4000 psi - no failures. Chuck Scheve - AOGCC witnessed test. P/U injector head, install guide arch. Held Safety Meeting. Pull new CT off reel and stab into injector head. Change out pack-off. M/U CT connector and pull test. Pump dart thru new CT. Press test hardline, CT and lubricator. M/U drilling BHA #1 with straight motor and used PDC bit. RIH with BHA #1. Tag cement at 9798 ft BKB. Drill cement plug left in tubing and liner from 9798 - 10,600 ft BKB. 08/30/99 2 10827' Drill cement to top of whipstock at 10,601 ft. Unable to drill past top of whipstock with straight motor. Ream up to top of cement and back to 10,601 ft. Circulate well to used FIoPro mud. POOH. L/O straight motor and bit. M/U directional drilling BHA #2 with 3.1 deg bent motor and M09BQPS Bit #2. RIH with BHA #2. Tag top of whipstock and correct depth to 10,601 ft. Ream cement sheath in 7" liner above whipstock. Orient TF. Drill from 10601' - 10686 ft. Orient TF. Unable to orient in open hole. Pull above whipstock and orient. RIH and drill 10686 - 10770 ft. Orient TF above whipstock. RIH and drill 10770 - 10827 ft. POOH for a new bit. 08/31/99 3 11194' POH. Change bit & motor. RIH with bit #3. Tag bottom. Orient - no go. Pull up hole to just below window to get orienter to work. Got TF 15L. RIH and toolface changed to 60L on bottom. Drill ahead to 10880'- TF at 71L. Slow ROP last 10'. ROP improved to 100+ fph. Drill to 10905'. Pull up and orient to stop build. RIH. Drill to 10910 ft. Pull to window and Orient. RIH. Drill to 10942'. Pull to window and orient. Drill to 10960'. Pull to window and Orient. Drill to 10981 ft. Pull to window and orient. RIH and drill to 10994 ft. Pull to window and orient. Drill to 11025 ft. Ream 200 ft off bottom. Drill to 11194 ft with no mud losses. This is about 90 ft past the projected fault. POOH for bent motor change. 09/01/99 4 11445' POH for bit & BHA change. LD motor and shock sub - non-operational. MU bit #4 1.8 deg motor. Run DDS sub for vibration monitoring. Cut 350' coil to move fatigue point. MU CT connector. RIH with BHA #4. Tie-in to GR marker. Work thru tite spots at 10800', 10948' and 11032'. Have trouble orienting. Drill from 11194-285' building angle to 99° and turning right. Differentially stuck BHA at 11285'. Pump dead crude and came free. Backream to window. Drill from 11285-393' and begin planned drop at 11350'. POOH for smaller bend motor. LD DDS, MU SS. Change motor bend. RIH with BHA#5 (1.1 deg motor) to TD. Drill from 11393- 11445' 09/02/99 5 11879' Drill from 11445 - 11524 ft. Made wiper trip to window and tied-in with GR. Added 7.5 ft to CTD. RIH and drilled from 11524 - 11710 ft. Made wiper trip to window. Clean hole. RIH. Orient TF to right. Drilled from 11710 - 11824 ft. Lost returns at 11,824 ft. [2.5 BPM in / 0.7 BPM out]. Made wiper trip to window. Tied-in with GR, added 4.5 ft to CTD. RIH and tagged TD [2.5 BPM in/0.8 BPM out]. Drilled from 11,828- 875' and lost nearly full returns (2.5/0.1) at 11858'. Backream to window while wait on cementers. Check static loss at 2.1 bpm. DS batch mix and load CT with 60 bbls InstasealTM (IS) while RIH. Displace with rig mud at 1.5-2.8 bpm while reciprocating over zone of loss. Pull into casing leaving IS in openhole. WOIS 90 minutes w/o circ and SI @ choke. Fill hole with 20 bbls mud and check static loss at 0.1 bpm. RIH to TD cleaning out IS. Losses (at rate) improved from 2.3/0.6 bpm at 11300' to 2.3/1.1 bpm at TD. Backream to window. POOH for cementing BHA. B-13Ai, Coil Tubing Drilli% Page 4 09/03/99 6 11951' Held Well Kick Drill. L/D directional drilling BHA. RIH with cementing BHA #6. Tagged TD at 11875 ft. Held Safety Meeting. Pumped 25 BBLS, 13.8 PPG cement slurry with 8% Bentonite and 18 PPB Perfect Seal in 15 bbls. Squeezed 13 bbls to fault and laid in 12 bbls in open hole. Estimated top of Cement plug at 11,100 ft. POOH with no pump to 5 ~" tubing. Pumped 50% displacement to surface. Lay out cementing BHA. WOC. M/U drilling BHA #7. RIH. Shallow test MWD tools - OK. RIH with full returns. Drill firm cement from 10880-11760'. Backream to window. Drill firm cement from 11760' to TD with full returns. Swapped to new mud due to sticky hole. Began losing 0.7 bpm while logging to get on depth. Drilled new hole from corrected TD of 11890' to 11951 '. Losses increased from 0.6 bpm at 11900' to 2.5 bpm at 11930'. Backream to window. Fill hole over the top losing 0.4 bpm while wo cementers. 09/04/99 7 12004' Fill hole while waiting on cementers to rig up. RIH with drilling BHA to TD of 11951 ft. Drill to 11976 ft. Held Safety Meeting with all personnel. Stage 5 BBL Fresh water spacer, Stage 63 BBL Instaseal, Stage 5 BBL fresh water spacer. Displace Instaseal to fault with FIoPro at 3.0 - 3.3 BPM. Hesitate for 20 min. after pumping 48 BBLS out bit. Displace last 15 BBLS at 3.3 BPM. POOH to window with no pump. Wait on Instaseal to set for 1 hour. RIH and drill out Instaseal. First returns seen while RIH at 11500 ft, pumping 2.2 BPM / 0.2 BPM returns. RIH to TD. Returns of 0.1 BPM at TD. POOH. Lay out drilling BHA. RIH with cementing BHA to TD. R/U DS cementers. Load CT w/25 bbls 8% bentonite/Class G cement with 18#/bbl Perfect Seal. Displace with rig mud and squeeze 18 bbls away at max 30 psi. POOH to window and had full returns. Reduce to partial fill while POOH. Standback cementing assy. Perform weekly BOPE test. Well on vac. MU and RIH with drilling BHA #9 (1.1° motor). Tag hard cement at 11790'. Drill firm cement at 2.5/2.1 in/out bpm to TD. Drill new hole from 11976-12004' at 2.6/1.5 bpm. 09/05/99 8 12240' Drill ahead turning right and dropping from 12004 - 12153 ft with 1/2 returns. Short trip to window. Hole was clean. Tied-in with BHCS/GR at 10604 ft. Added 10 ft to CTD. RIH. Drilled to 12177 ft. Stalled twice. Lost full returns. Drill with no returns to 12,245 ft BKB. POOH for Memory logs. Hole is clean. L/O drilling BHA. M/U PDS Memory Induction / GR logging BHA #10. RIH with logging BHA. Log from 10450' to TD at 12246'. POOH with logging tools. Download data, fax log. WOO. WO Baker OH IBP. Note: Will use PDS Induction Log as reference log. Revised TD is 12240'. 09/06/99 9 12117' WO Baker Equipment. M/U Baker CT Connector. M/U 3 1,~ Jts of 2 3/8" PH6 Tubing for space out below IBP. M/U 2 1/2" IBP and running tools. RIH with Baker IBP. Correct to flag at 10500'. RIH to TD. Tag TD of 12,240 ft BKB. Pump 30 BBL hot 186 deg F. 2% KCL water, drop 5/8" ball and displace with 20 BBL hot water. Switch to FIoPro and displace ball. Ball on seat at 51.9 bbls. Inflate IBP element slowly. Disconnect at 2480 psi. Test for returns. Good results, 2.6 BPM with 1.1 BPM returns, the same while drilling before crossing fault. POOH with IBP running tools. L/O running tools. Held Safety Meeting. MU 60 jts 2-7/8" 6.16# L-80 STL liner. Install CTLRT. RIH on 2-3/8 CT to 12030' and set down in shale. Unable to work deeper. Need to set shoe on top of IBP at 12117' to allow room for bottom perfs. POOH with liner. Standback in doubles. MU drilling BHA. RIH with BHA #12 (1.1° motor). B-13Ai, Coil Tubing Drilli%_ ~ Page 5 09/07/99 10 RIH with drilling BHA. Correct depth at flag. RIH and ream shale at 12,020 ft. RIH easy to PBTD of 12, 117 ft BKB. Back ream to window. Hole is clean. Tie-in to BHCS/GR, add 2 ft to CTD. Flag CT. POOH. Lay down drilling BHA. Held Safety Meeting. RIH with 60 its of 2 7/8", STL Liner in doubles. M/U Baker CTLRT. RIH with liner on CT. Correct CTD at flag. RIH and sat down at shales at 12,030 ft. Work Liner to PBTD of 12, 117 ft BKB. Drop 5/8" steel ball and disconnect from liner. Displace well to 2 % KCL water with 1.1 BPM returns. Held Safety Meeting. DS mix and load CT with 34 bbls (250% excess) 15.8 ppg Class G cement. Load wiper dart. Displace with rig KCI water to liner wiper plug. Displace LWP to latch collar at calc displ (got 1/2 returns after cement around shoe). Floats held. PUH above WCTOC with stinger. Load CT with 27 bbls contaminate and still losing fluid (2.3/2.0 bpm). WOC I hr. RIH and contaminate to 300' above TOL with no sign of cement. POOH. LD CTLRT. MU 2.25" mill and motor. MU 60 jts 1-1/4 CSH workstring. RIH on CT to PBD @ 12085' (1.5/1.2 in/out bpm). POOH. 09/08/99 11 POOH with CT. Stand back CSH workstring. L/O motor and mill. M/U Baker seal assembly and RIH. Sting into liner top at 10,251 ft. Press test liner shoe to 2250 psi for 30 min. no leak. Pull CT to 10,000 ft. Bullhead 220 BBL Diesel into CT annulus to lower fluid gradient. Attempt to pump down CT. No luck. BHA plugged. POOH to clear plug in BHA. Clear cement solids from CT. Make up cement BHA, TIH. Establish injection rate at 10,000' of 3.0 bpm w/1500 psi WHP and 2450 CTP. Pull uphole to 9850' and pump 35 bbl cement, displace to end of CT. Wellhead pressure increased 200 psi w/cement past liner top. POOH keeping backside filled w/diesel. OOH, clear diesel form CT and surface lines. WOC. UTA cement compressive strength 1250 psi at 05:00. Pressure test cement to 1000 psi. Lost 44 psi ion 20 minutes. PU cement clean-out BHA. 09/09/99 12 Continue RIH with 3.75" bit/motor. Precautionary ream 4-1/2" tubing to TOL at 10251' and found no cement. POOH. LD BHA. MU 2.25" mill/motor and RIH on 30 workstring doubles. RIH on CT to TOL. Drill a few cement stringers in first 20' then RIH to PBD at 12085'. POOH to TOL leaving fresh 2% KCL water in liner. Drop ball to open circ sub. Pump 50 bbls Biozan and chase OOH with KCL water while POOH. Stand back workstring doubles. Hold Safety Meeting, PU perf guns and 1 ~,~" CS Hydril. TIH, Tag up and position bottom shot at 12070'. Drop 5/8" Firing Ball and displace w/2% KCI. Did not see ball on seat. Surge and attempt to seat ball, no progress. Increase pump rate to 3.0 bpm. Saw pressure drop and weight increase, lost 1-2 bbl fluid, indicate guns fired. POOH, LD 1 ~,~" CS Hydril. 09/10/99 13 Finish LD CSH workstring. LD perf guns-all shots fired. Perf Intervals: 11,990'-12,010'/ 12,049'-12,070'. Freeze protect wellbore from 1500' with 35 bbls MeOH. Secure tree. Blowdown CT with N2. Vac pits. ND hardline to green tank. ND BOPE. Install tree cap and test to 5000 psi. Rig Released at 1200 hrs 9/9/99. Move off well. LD windwalls. LD derrick. Move to D-09. B.P. Exploration (True) Structure : Pad B Field : Prudhoe Bay Well : B-15AI, 50-029-20541-01 Location : North Slope. Alaska <- West (feet) Brij Potnis Dote plotted : 29-Scp-1999 Plot Refeccnce [s B-1.~AJ. Coerdinetel are in feet reference B-I:~. True Vertical D~pths ore reference RKB - ~SL = 64..I ft. --- t~okar Hughm% INT[O --- 5400 5200 5000 4800 4600 4400 4200 4000 5800 3600 5400 3200 5000 2800 { I I I I I I I I I I I I I ~ I I I I I I I I I I I I Projected to TD ORIGINAL 8400 8500 8600 -~ ~ 8~oo Tie-in Point. Projected to TD I B-13N Plan Cese2OI I 1800 '2000 22OO ~ ,, 2400 2600 2800"- 5000 3200. 3400 Azimuth 165.26 with reference 2117.07 S, 4193.51 W from B-15 8800 ___~-~'"-~ Proiected to T TD I-- 8900 TD ' 1 .-~ .,0. co,~o~ I V 9°°°1,, ! ............. , ............................ 200 100 0 I00 200 500 400 500 600 700 800 900 1000 11 O0 1200 1500 1400 1500 1600 1700 1800 1900 2000 Vertical Section (feet) -> 4000 3800 B.P. Exploration (True) Pad B B-13AI B-13 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : B-13AI Our ref : svy225 License : 50-029-20341-01 Date printed : 29-Sep-1999 Date created : 29-Sep-1999 Last revised : 29-Sep-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665614.201,5950684.689,999.00000,N Slot location is nT0 16 0.344,w148 40 24.346 Slot Grid coordinates are N 5948910.000, E 664051.000 Slot local coordinates are 1739.98 S 1601.99 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad B,B-13AI Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 1 Your ref : B-13AI Last revised : 29-Sep-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 00 R D S Depth Degrees Degrees Depth C O 0 R D I N A T E S Deg/100ft Sect Easting Northing. 10500.00 44.02 259.20 8665.17 2117.07S 4193.51W 0.67 0.00 659905.38 5946701.31 10550.00 44.02 258.95 8701.12 2123.66S 4227.62W 0.35 -3.52 659871.42 5946693.98 10575.00 44.03 258.82 8719.10 2127.01S 4244.67W 0.36 -5.22 659854.45 5946690.26 10601.00 43.99 258.70 8737.80 2130.53S 4262.39W 0.36 -6.95 659836.82 5946686.35 10642.50 49.66 244.76 8766.26 2140.13S 4290.92w 27.99 -5.98 659808.50 5946676.12 10676.83 55.28 233.76 8787.20 2154.09S 4314.20W 30.19 0.68 659785.54 5946661.66 10707.18 59.24 223.76 8803.64 2170.91S 4333.32W 30.61 11.29 659766.79 5946644.41 10729.48 62.89 216.46 8814.44 2185.84S 4345.86W 32.98 21.97 659754.58 5946629.22 10758.43 67.68 206.30 8826.57 2208.27S 4359.49W 35.90 39.52 659741.45 5946606.50 10780.60 72.51 199.09 8834.12 2227.48S 4367.51W 37.53 55.62 659733.86 5946587.11 10817.75 84.37 191.34 8841.56 2262.53S 4376.98W 37.88 86.44 659725.16 5946551.87 10850.00 88.42 184.67 8843.59 2294.37S 4381.46W 24.16 115.65 659721.39 5946519.93 10875.05 93.63 177.05 8843.14 2319.39S 4381.83W 36.84 139.50 659721.56 5946494.91 10907.72 97.56 161.65 8839.94 2351.24S 4375.86W 48.42 171.73 659728.24 5946463.20 10939.50 95.98 150.40 8836.18 2380.03S 4363.05W 35.50 202.98 659741.67 5946434.71 10963.85 93.51 140.90 8834.16 2400.04S 4349.38W 40.18 226.08 659755.79 5946415.01 10995.17 94.31 125.26 8832.01 2421.31S 4326.63W 49.88 253.01 659779.00 5946394.24 11036.55 96.01 114.22 8828.28 2441.73S 4290.90W 26.89 282.85 659815.16 5946374.61 11099.10 97.65 114.89 8820.84 2467.54S 4234.41W 2.83 323.83 659872.20 5946350.06 11123.92 97.21 113.31 8817.63 2477.59S 4211.95W 6.56 339.92 659894.88 5946340.51 11164.37 97.56 109.44 8812.43 2492.20S 4174.60W 9.53 364.68 659932.54 5946326.71 11198.92 97.82 107.15 8807.81 2502.95S 4142.09W 6.61 384.34 659965.27 5946316.68 11234.60 99.84 112.43 8802.33 2514.88S 4108.93W 15.68 405.31 659998.68 5946305.49 11263.60 99.40 119.28 8797.48 2527.34S 4083.22W 23.34 424.65 660024.66 5946293.60 11299.65 96.94 126.12 8792.35 2546.61S 4053.21W 19.98 451.75 660055.08 5946274.99 11328.88 97.86 132.69 8788.58 2565.00S 4030.83W 22.51 475.80 660077.86 5946257.10 11359.50 97.21 138.80 8784.56 2586.73S 4009.66W 19.90 502.71 660099.51 5946235.84 11389.87 96.06 144.42 8781.05 2610.37S 3990.93W 18.77 530.74 660118.75 5946212.63 11419.50 95.27 147.41 8778.12 2634.78S 3974.41W 10.39 558.88 660135.80 5946188.58 11455.25 93.51 151.45 8775.38 2665.47S 3956.29W 12.30 593.48 660154.59 5946158.31 11487.25 90.44 156.90 8774.28 2694.24S 3942.36W 19.54 625.05 660169.15 5946129.85 11523.07 88.33 156.90 8774.67 2727.19S 3928.31W 5.89 660.64 660183.92 5946097.22 11558.24 87.10 153.56 8776.07 2759.09S 3913.59W 10.11 695.43 660199.34 5946065.65 11588.37 87.80 149.52 8777.41 2785.55S 3899.25W 13.60 724.90 660214.26 5946039.52 11622.54 88.15 145.65 8778.62 2814.37S 3880.95W 11.36 757.77 660233.19 5946011.11 11661.67 86.57 141.61 8780.42 2845.84S 3857.78W 11.08 794.58 660257.04 5945980.16 11688.74 84.64 141.08 8782.49 2866.91S 3840.92W 7.39 819.62 660274.36 5945959.46 11725.62 84.73 141.43 8785.91 2895.55S 3817.93W 0.98 853.67 660297.97 5945931.34 11758.29 85.87 144.95 8788.59 2921.62S 3798.43W 11.29 884.24 660318.04 5945905.71 11792.75 85.60 148.46 8791.15 2950.34S 3779.57W 10.19 917.18 660337.53 5945877.42 11820.29 84.73 151.63 8793.47 2974.11S 3765.87W 11.90 943.89 660351.75 5945853.95 11850.49 82.97 153.74 8796.71 3000.78S 3752.09W 9.07 973.40 660366.11 5945827.59 11880.42 84.17 156.12 8800.06 3027.72S 3739.49W 8.86 1002.83 660379.30 5945800.94 11924.59 80.68 159.36 8805.89 3068.23S 3722.90w 10.74 1046.40 660396.77 5945760.81 11958.37 76.82 160.94 8812.47 3099.38S 3711.65W 12.31 1079.47 660408.70 5945729.91 11990.33 74.53 163.40 8820.38 3128.86S 3702.17w 10.34 1110.43 660418.83 5945700.65 12035.53 72.60 170.96 8833.19 3171.09S 3692.54w 16.60 1153.64 660429.38 5945658.65 12072.88 71.28 176.59 8844.77 3206.37S 3688.69W 14.76 1188.54 660434.01 5945623.46 12105.38 70.58 181.33 8855.40 3237.07S 3688.13W 13.95 1218.10 660435.25 5945592.78 12151.55 69.96 189.07 8871.01 3280.31S 3692.06W 15.84 1258.38 660432.27 5945549.47 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from B-13 and SSTVD from RKB - MSL = 64.1 ft. Bottom hole distance is 5010.31 on azimuth 227.81 degrees from wellhead. Vertical section is from tie at S 2117.07 W 4193.51 on azimuth 163.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad B,B-13AI Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : B-13AI Last revised : 29-Sep-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Vert G R I D C 0 0 R D S Depth Degrees Degrees Depth C 00 R D I N A T E S Deg/100ft Sect Easting Northing. 12182.17 69.78 190.83 8881.54 3308.63S 3697.03W 5.43 1284.06 660427.93 5945521.05 12220.47 66.80 197.51 8895.72 3343.11S 3705.71W 17.97 1314.58 660420.00 5945486.39 12245.00 66.80 197.51 8905.39 3364.61S 3712.49w 0.00 1333.21 660413.70 5945464.75 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from B-13 and SSTVD from RKB - MSL = 64.1 ft. Bottom hole distance is 5010.31 on azimuth 227.81 degrees from wellhead. Vertical section is from tie at S 2117.07 W 4193.51 on azimuth 163.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad B,B-13AI Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 3 Your ref : B-13AI Last revised : 29-Sep-1999 MD SSTVD 10500.00 8665.17 12245.00 8905.39 Comments in wellpath Rectangular Coords. Comment 2117.07S 4193.51W Tie-in Point 3364.61S 3712.49W Projected to TD NO Targets associated with this wellpath B.P. Exploration (True) Pad B B-13AIPB1 B-13 Prudhoe Bay North Slope, Alaska SURVEY LISTING by Baker Hughes INTEQ Your ref : B-13AIPB1 Our ref : svy185 License : 50-029-20341-70 Date printed : 29-Sep-1999 Date created : 14-Ju1-1999 Last revised : 29-Sep-1999 Field is centred on 708179.340,5930615.440,999.00000,N Structure is centred on 665614.201,5950684.689,999.00000,N Slot location is n70 16 0.344,w148 40 24.346 Slot Grid coordinates are N 5948910.000, E 664051.000 Slot local coordinates are 1739.98 S 1601.99 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North B.P. Exploration (True) Pad B,B-13AIPB1 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page Your ref : B-13AIPB1 Last revised : 29-Sep-1999 Measured Inclin Azimuth Subsea R E C T A N G U L A R Dogleg Depth Degrees Degrees Depth C O O R D I N A T E S Deg/100ft Vert G R I D C 0 0 R D S Sect Easting Northing. 10500,00 44.02 259.20 8665.17 2117.07S 4193.51W 0.67 0.00 659905.38 5946701.31 10601,00 43.99 258.71 8737.81 2130.51S 4262.37W 0.34 -6.96 659836.83 5946686.36 10631,29 48.52 250.15 8758.77 2136.43S 4283.39W 25.28 -7.35 659815.95 5946679.98 10662,20 54.05 241.42 8778.12 2146.37S 4305.31w 28.36 -4.15 659794.26 5946669.56 10726.59 66.41 223.23 8810.23 2180.68S 4348.85W 31.05 16.17 659751.49 5946634.30 10765.92 74.97 213.55 8823.25 2209.76S 4371.78w 31.81 37.41 659729.20 5946604.73 10796.79 82.44 205.47 8829.31 2236.08S 4386.64W 35.26 58.33 659714.92 5946578.10 10824.79 89.30 201.42 8831.32 2261.68S 4397.74W 28.43 79.65 659704.39 5946552.26 10853.80 94.22 193.16 8830.43 2289.33S 4406.35W 33.12 103.65 659696.39 5946524.42 10890.80 92.55 188.24 8828.24 2325.61S 4413.21W 14.02 136.42 659690.34 5946488.00 10924.80 93.25 184.90 8826.52 2359.34S 4417.09W 10.02 167.60 659687.20 5946454.20 10961.75 93.87 180.33 8824.23 2396.17S 4418.77W 12.46 202.39 659686.32 5946417~34 11006.00 93.34 176.46 8821.44 2440.31S 4417.54W 8.81 245.01 659688.53 5946373.25 11030.20 94.16 172.21 8819.86 2464.33S 44t5.15W 17.85 268.70 659691.44 5946349.28 11059.72 94.13 168.73 8817.73 2493.36S 4410.28W 11.76 297.91 659696.95 5946320.37 11077.17 94.39 165.74 8816.43 2510.33S 4406.44W 17.15 315.27 659701.17 5946303.49 11111.21 95.45 159.41 8813.51 2542.68S 4396.29W 18.79 349.16 659712.03 5946271.38 11139.69 95.98 159.24 8810.67 2569.19S 4386.28W 1.95 377.43 659722.61 5946245.10 11164.77 97.73 162.93 8807.68 2592.74S 4378.21w 16.19 402.31 659731.20 5946221.73 11195.32 99.58 168.90 8803.08 2622.02S 4370.86W 20.25 432.46 659739.19 5946192.62 11243.37 99.51 177.83 8795.09 2669.03S 4365.39W 18.33 479.06 659745.70 5946145.74 11274.76 98.18 176.95 8790.27 2700.02S 4363.98W 5.06 509.14 659747.79 5946114.80 11295.00 98.18 176.95 8787.39 2720.02S 4362.91W 0.00 528.61 659749.30 5946094.82 Ail data in feet unless otherwise stated, Calculation uses minimum curvature method. Coordinates from B-13 and SSTVD from RKB - MSL = 64.1 ft. Bottom hole distance is 5141.36 on azimuth 238.06 degrees from wellhead. Vertical section is from tie at S 2117.07 W 4193.51 on azimuth 163.26 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ B.P. Exploration (True) Pad B,B-13AIPB1 Prudhoe Bay,North Slope, Alaska SURVEY LISTING Page 2 Your ref : B-13AIPB1 Last revised : 29-Sep-1999 Comments in wellpath MD SSTVD Rectangular Coords. comment 10500.00 8665.17 2117.07S 4193.51W Tie-in Point 11295.00 8787.39 2720.02S 4362.91W Projected to TD NO Targets associated with this wellpath Prudhoe Bay Unit Alaska State Plane Zone 4 PBU_ WOA B Pad, Slot B-13 B-13A Job No. AKMW90150, Surveyed: 9 April, 1999 SURVEY REPORT 10 September, 1999 ORIGINAL Your Reft A P1-500292034101 Surface Coordinates: 5948909.05 N, 664050.83 E (70° 16' 00.3351" N, 148° 40' 24.3515" W) Kelly Bushing: 64.16ft above Mean Sea Level DRILL, I I~11~ SERV,,IEES SurveyRef:svy9193 A HALLIBURTO~ COMPANY Sperry-Sun Drilling Services Survey Report for B-13A Your Ref: API-500292034101 ~,. Job No. AKMW90150, Surveyed: 9 April?19.99''~ Prudhoe Bay Unit Measured Depth (ft) Incl. Sub-Sea Depth (ft) Vertical Depth (ft) 10500.00 44.020 259.215 8665.11 8729.27 10601.00 43.990 258.700 8737.75 8801.91 10642.50 49.660 244.760 8766.21 8830.37 10676.83 55.280 233.760 8787.16 8851.32 10707.18 59.240 223.760 8803.60 8867.76 10729.48 62.890 216.460 8814.40 8878.56 10758.43 67.680 206.300 8826.52 8890.68 10780.60 72.510 199.090 8834.08 8898.24 10817,75 84.370 191,340 8841.52 8905.68 10850.00 88.420 184.670 8843.55 8907.71 10875.05 93.630 177.050 8843.10 8907.26 10907.72 97.560 161.650 8839.90 8904,06 10939.50 95.980 150.400 8836.14 8900.30 10963.85 93.510 140.900 8834.12 8898,28 10995.17 94.310 125.260 8831.97 8896.13 11036.55 96.010 114.220 8828.24 8892.40 11099.10 97.650 114.890 8820.80 8884.96 11123,92 97.210 113.310 8817.59 8881.75 11164.37 97.560 109.440 8812.39 8876.55 11198.92 97,820 107.150 8807.77 8871.93 11234.60 99.840 112.430 8802.28 8866.44 11263.60 99.400 119.280 8797.43 8861.59 11299.65 96,940 126.140 8792.30 8856.46 11328.88 97.860 132.690 8788.54 8852.70 11359.50 97.210 138.800 8784.52 8848.68 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2115.95 S 4194.07w 5946702.21 N 659903.86 E 2129.39 S 4262.94W 5946687.27 N 659835.30 E 2138.99 S 4291.48W 5946677.05 N 659806.98 E 2152.95 S 4314.75W 5946662.59 N 659784.02 E 2169.77 S 4333.87W 5946645.35 N 659765,27 E 2184.70 S 4346.42W 5946630.15 N 659753.05 E 2207.13 S 4360.04W 5946607.43 N 659739.92 E 2226.34 S 4368.06W 5946588.04 N 659732.32 E 2261.39 S 4377.54W 5946552.80 N 659723.61 E 2293.24 S 4382.01W 5946520.87 N 659719.83 E 2318.25 S 4382,39W 5946495,85 N 659720.00 E 2350.10 $ 4376.41W 5946464.13 N 659726.67 E 2378.89 $ 4363.61W 5946435.63 N 659740.10 E 2398.90 S 4349.93W 5946415.93 N 659754.21E 2420.17 S 4327.18W 5946395.15 N 659777.42 E 2440.59 S 4291.45W 5946375.52 N 659813.58 E 2466.40 S 4234.97W 5946350.95 N 659870.61 E 2476.45 S 4212.50W 5946341.39 N 659893.29 E 2491.06 S 4175.15W 5946327.59 N 659930.95 E 2501,81S 4142.65W 5946317.55 N 659963.68 E 2513.74 S 4109.48W 5946306.35 N 659997.10 E 2526.20 S 4083.77W 5946294.45 N 660023.08 E 2545.48 S 4053.77W 5946275.84 N 660053.49 E 2563.87 S 4031.39W 5946257.94 N 660076.27 E 2585.60 S 4010.22W 5946236.67 N 660097.91 E Alaska State Plane Zone 4 PBU_WOA B Pad Dogleg Rate (°/lOOft) Vertical Section (ft) Comment 0.356 27.992 3o.191 3o.612 32.983 35.898 37.534 37.884 24.158 36.837 48.421 35.5Ol 4o.179 49.884 26.886 2.829 6.557 9.527 6.611 15.68o 23.337 20.032 22.443 19.895 4528.93 4588.99 4616.58 4643.21 4668.67 4687.99 4713.15 4731.99 4762.54 4787.24 48o4.31 4821.27 4831.1o 4834.40 4831.82 4819.o5 4794.51 4784.61 4766,74 4749.87 4733.30 4722.60 4713.31 4709.07 4707.97 TIE ON SURVEY WINDOW POINT Continued... 10 September, 1999 - 10:35 - 2 - DrillQuest Sperry-Sun Drilling Services Survey Report for B-13A Your Ref: API-500292034101 ~,. ,~ Job No. AKMW90150, Surveyed: 9 April;~t9.99~ Prudhoe Bay Unit Measured Depth (ft) Incl. Azim. Sub-Sea Depth (ft) Vertical Depth (ft) 11389.87 96.060 144.420 8781.00 8845.16 11419.50 95.270 147.410 8778.08 8842.24 11455.25 93.510 151.450 8775.34 8839.50 11487.25 90.440 156.900 8774.24 8838.40 11523.07 88.330 156.900 8774.62 8838.78 11558.24 87.100 153.560 8776.03 8840.19 11588.24 87.800 149.520 8777.36 8841.52 11622.54 88.150 145.650 8778.57 8842.73 11661.67 86.570 141.610 8780.38 8844.54 11688.74 84.640 141.080 8782.45 8846.61 11725.62 84.730 141.430 8785.87 8850.03 11758.29 85.870 144.950 8788.54 8852.70 11792.75 85.600 148.460 8791.11 8855.27 11820.29 84.730 151.630 8793.43 8857.59 11850.49 82.970 153.740 8796.67 8860.83 11880.42 84.170 156.120 8800.02 8864.18 11924.59 80.680 159.360 8805.84 8870.00 11958.37 76.820 160.940 8812.43 8876.59 11990.33 74.530 163.400 8820.34 8884.50 12035.53 72.600 170.960 8833.14 8897.30 12072.88 71.280 176.590 8844.73 8908.89 12105.38 70.580 181.330 8855.35 8919.51 12151.55 69.960 189.070 8870.96 8935.12 12182.10 69.780 190.830 8881.48 8945.64 12220.47 66.800 197.510 8895.68 8959.84 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 2609.24 S 3991.49W 5946213.45 N 660117.14 E 2633.65 S 3974.97W 5946189.40 N 660134.19 E 2664.34 $ 3956.85W 5946159.12 N 660152.98 E 2693.11 S 3942.92W 5946130.65 N 660167.53 E 2726.06 S 3928.87W 5946098.02 N 660182.29 E 2757.96 S 3914.15W 5946066.45 N 660197.71 E 2784.30 $ 3899.87W 5946040.42 N 660212.56 E 2813.23 $ 3881.50W 5946011.90 N 660231.56 E 2844.70 S 3858.33W 5945980.94 N 660255.41 E 2865.78 S 3841.47W 5945960.24 N 660272.72 E 2894.42 S 3818.49W 5945932.11 N 660296.32 E 2920.48 S 3798.98W 5945906.47 N 660316.39 E 2949.20 S 3780.12W 5945878.17 N ~660335.87 E 2972.97 S 3766.42W 5945854.70 N 660350.09 E 2999.65 $ 3752.64W 5945828.33 N 660364.45 E 3026.59 S 3740.04W 5945801.68 N 660377.63 E 3067.10 S 3723.45W 5945761.54 N 660395.09 E 3098.25 S 3712.20W 5945730.64 N 660407.02 E 3127.72 S 3702.72W 5945701.38 N 660417.14 E 3169.95 S 3693.10W 5945659.37 N 660427.69 E 3205.24 S 3689.24W 5945624.18 N 660432.31 E 3235.94 S 3688.68W 5945593.50 N 660433.54 E 3279.18 S 3692.61W 5945550.18 N 660430.55 E 3307.43 S 3697.57W 5945521.83 N 660426.21 E 3341.97 $ 3706.26W 5945487.11 N 660418.27 E Alaska State Plane Zone 4 PBU_WOA B Pad Dogleg Vertical Rate Section (°/100fi) (ft) Comment 18.767 4709.96 10.390 4714.11 12.296 4721.28 19.537 4730.27 5.891 4741.98 10.113 4752.49 13.654 4759.59 11.322 4765.40 11.076 4769.35 7.392 4771.00 0.976 4773.20 11.291 4776.24 10.188 4781.54 11.897 4787.35 9.067 4795.05 8.861 4803.79 10.737 4818.69 12.313 4831.27 10.342 4844.03 16.599 4865.25 14.759 4886.08 13.951 4906.28 15.836 4938.22 5.441 4960.86 17.939 4990.49 Continued... 10 September, 1999 - 10:35 - 3 - DrillQuest Sperry-Sun Drilling Services Survey Report for B-13A Your Ref: API-500292034101 ~. .... ~ Job No. AKMW90150, Surveyed: 9 April, s1999 '. Prudhoe Bay Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth Depth (ft) (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 12245.00 66.800 197.510 8905.35 8969.51 3363.47 S 3713.05 w 5945465.46 N All data is in feet 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. 660411.96 E Alaska State Plane Zone 4 PBU_WOA B Pad Dogleg Vertical Rate Section (°/100fi) (ft) Comment 0.000 5009.96 PROJECTED SURVEY The Dogleg Severity is in Degrees per 100ft. Vertical Section is from Well Reference and calculated along an Azimuth of 227.828° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 12245.00ft., The Bottom Hole Displacement is 5009.96ft., in the Direction of 227.828° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings Comment (ft) (ft) (ft) (ft) 10500.00 8729.27 2115.95 S 4194.07 W TIE ON SURVEY 10601.00 8801.91 2129.39 S 4262.94 W WINDOW POINT 12245.00 8969.51 3363.47 S 3713.05 W PROJECTED SURVEY 10 September, 1999 - 10:35 - 4 - DrillQuest H/ELL LOG FIANSMITTAL ~ .Active Diagnostic Services, Inc. To: State of Alaska AOGCC Lori Taylor 3001 Porcupine St. Anchorage, Alaska 99501 RE: Distribution- Final Print(s) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of: Robert Richey PDS, Inc. Mail Pouch 340112 Prudhoe Bay, AK 99734 BP Exploration (Alaska), Inc. Petro-Technical Data Center, MB 3-3 900 E. Benson Blvd. Anchorage, Alaska 99508 LOG DIGITAL MYLAR / BLUE LINE WELL DATE TYPE DATA SEPIA FILM PRINT(S) B-13Ai 9-4-99 Open Hole I I 1 qfl,o '-/ :m_fi' o! Res. Eval. CH I I I Signed: Print Name: Date: ProActive Diagnostic Services, Inc., Pouch 340112, Prudhoe Bay, AK 99734 Phone:(907)659-2307 Fax: (907)659-2314 E-mail: pdsprudhoe@NA800.net Website: www.memorylog.com C:hMy Documents'xExcel_Word_DocumentsXDistribution_FormsXBp_pb_form.do~ MEMORANDUM TO: Robert Christenson,~ Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: August 28, 1999 THRU: FILE NO: Blair Wondzell, P. I. Supervisor FROM' Chuck Scheve,~(~,,, ~ SUBJECT: Petroleum Inspector ahzkh2gf. DOC BOPE Test Nordic 1 PBU B-13A PTD 99-57 Saturday, August 28,1999: I traveled to BPXs PBU B Pad to witness the initial BOPE test on Well B-13A being drilled by the Dowell Schulumberger / Nordic 1 coil tubing drilling unit. As the attached AOGCC Test Report indicates the test lasted 2.5 hours and there were no failures. The testing went very well with good test procedures being employed by the Nordic crew. The Rig was clean and all related equipment appeared to be in good condition. SUMMARY: I witnessed the initial BOPE test on Nordic Rig 1 drilling BPXs B-13A Well. Nordic 1, 8128199, Test Time 2.5 hours, 0 Failures Attachments: ahzkbh2gf, xls X Unclassified Classified Unclassified with Document Removed STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: Test: Initial X Workover: DS / Nordic Rig No. SSD B-13A Set @ Weekly Other 1 PTD # Rep.: Rig Rep.: Location: Sec. DATE: 8/28/99 99-57 Rig Ph,# 659-4434 Dick Maskel Shawn McKeirman 3,/ T. ,/ ,/ N R. ,/ 4E Meridian UM TEST DATA BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln, Valves HCR Valves Kill Line Valves Test Quan, Pressure P/F 200/4000 P 200/4000 P 1 1 200/3000 P 1 200/4000 P 1 200/4000 P 1 200/4000 P 2 200/4000 P CHOKE MANIFOLD: No, Valves No. Flanges Manual Chokes Hydraulic Chokes Test Quan, Pressure P/F 15 200/4000 P 30 200/4000 ,/ ACCUM U LATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3@2200 P Functioned P Functioned P MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank OK OK Location Gen.: OK Pit Level Indicators OK OK Housekeeping: OK Meth Gas Detector OK OK Permit to drill: Yes H2S Gas Detector OK OK Standing Order Posted Yes 3100 I 2000 minutes '/5 sec. minutes 55 sec. OK Remote: OK Psig. Well Sign OK Drl. Rig OK Hazard Sec. Yes TEST RESULTS;:: Number of Failures: 0 ,Test Time: 2.5 Hours. Number of valves tested 2'/ Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good Test Distribution: orig-Well File c- Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve Form Revised 2~20~97 L.G. ahzkh2gf.xls 9/1/99 STATE OF ALASKA '--"~ ALASKA (~-.:::' AND GAS CONSERVATION corvh~d'SSION APPLICATION FOR SUNDRY APPROVAL I1. Type of Request: [] Abandon [] Suspend [] Plugging [] Time Extension [] Perforate [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1740' SNL, 1608' WEL, SEC. 31, T11N, R14E, UM At top of productive interval 3871' SNL, 872' WEL, SEC. 36, T11N, R13E, UM At effective depth 3746' SNL, 292' WEL, SEC. 36, T11N, R13E, UM At total depth 4460' SNL, 971' WEL, SEC. 36, T11N, R13E, UM 5. Type of well: I--] Development ]~ Exploratory I~ Stratigraphic []Service Datum Elevation (DF or KB) KBE = 64.16' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-13Ai 9. Permit Number 99-057 / 399-123 10. APl Number 50-029-20341-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11295 feet true vertical 8852 feet Effective depth: measured 9772 feet true vertical 8219 feet Casing Length Size Structural Conductor 110' Surface 2686' Intermediate 10366' Production Liner 1188' 7" Tieback Liner 6603' 7-5/8" Plugs (measured) Junk (measured) Cemented 20"x30" 454cuff Permafrost ~' ...... ~o~.0~t~, 110' 110' 13-3/8" 5766 cuff Permafrost 2686' 2686' 9-5/8" 1062 cuff Class 'G', 365 ouff PF 'C' 10366' 8633' 517 cu ft Class 'G' 230 cu ft Class 'G' TVD 9844'-10605' 8268'-8805' 3241'-9844' 3235'-8268' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) Packers and SSSV (type and measured depth) ORIGINAL 7", 26#, L-80 to 3162'; 5-1/2", 17#, NT-80S, 3162' - 9787'; 4-1/2", 12.6#, L-80, 9787' - 10567' 7" TIW HB-BP packer at 10538'; 7-5/8" TIW HBBP-R retrievable packer at 9807'; 7" Otis 'RPB' BVN at 2112' 13. Attachments [] Description summary of proposal [] Detailed operations program [] BOP sketch 4. Estimated date for commencing operation August 28, 1999 16. If proposal was verbally approved Name of approver Contact Engineer Name/Number: Ted Stagg, 564-4694 Date approved 15. Status of well classifications as: [] Oil [] Gas [] Suspended Service Prepared By NamelNumben Terrie Hubble, 564-4628 17. I hereby certify that the fore¢oing is true and correct to the best of my knowledge Signed ,~j_.~/~/~~~.¢' ~ Ted Stagg Title CT Drilling Engineer Commission Use Only Date Conditions of Approval: Notify Commission so representative may witness Plug integrity__ BOP Test ~ Location clearance~ Mechanical Integrity Test __ Subsequent form required 10- t~O "~ ORIGINAL SIGNED BY Approved by order of the Commission Robert N. Chdstenson ~'_'"..~?~'~,.. ,,,. Commissioner Form 10-403 Rev. 06/15/88 A . k eared '- rvices rilling Date:August'25,1999 roi Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re: Well B- 13 ai Operations were shut down on B-13ai on 7/14/99 due to fault related lost circulation. We are now planning to resume drilling operations on August 28 or 29, 1999. The well target is unchanged from the one permitted under Permit Number 99-57. The directional path to be followed in drilling to this target has been changed to avoid a fault. A copy of the new directional plan is attached. The existing window will be utilized after milling out cement used in abandoning the previously drilled hole, B-13ai PB 1. The proposed B-13ai well path will deviate from PB 1 soon after exiting the window. Please contact me at 564-4694 if further information is needed. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center Fault B-13 -4,500 -4,000 500 B-13ai Case 201 7/30/99 Fault X distance from Sfc Loc -3,000 -2,000- -2,500 -3,000 -3,500 -4,000 -4,500 IWell Name B- 13 I CLOSURE IDistance 5,160 ft I Az 225 de~l NEW HOLE E/W (X) N/S (Y) Kick Off -4,220 -2,224 TD -3,672 -3,625 State Plane 660,379 5,945,285 Surface Loc 664,051 5,948,910 DLS de~l/100 Tool Face Lenc~th Curve 1 6 0 Curve 2 36 -55 240 Curve 3 36 -90 239 Curve 4 10 90 230 Curve 5 10 107 339 Curve 6 10 107 399 Curve 7 10 -90 399 1,866 Drawn: 8/25/1999 12:52 Plan,Name: Case 201 I Section 500 WLEG ~. -..8;-782. .... 8.970 Path Distance (Feet) 1,000 1,500 2,000 I I 2,500 3,000 IB-13ai Case 201 7/30/99 Angle @ K.O.= 44 deg MD:10608 I~'96 deg. Tot Drld:1866 ft 12474 TD Marker Depths ~:)ri~l Wellbore I 8,6 61 D 8,8391 8,8391ft TVD TSAD I 8,741 Irt TVD 8,7821 8,7821~r IKick Off I 8,743 ft TVD 10,608 ff MD IDeprtr @KO 4,785 ft I MD KO Pt 10,608 MD New Hole 1866 Total MD _ 1~ TVD TD 8,970 DLS de~l/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 36 -55 240 Curve 3 36 -90 239 Curve 4 10 90 230 Curve 5 10 107 339 Curve 6 10 107 399 Curve 7 10 -90 399 1,866 Drawn: 8/25/1999 12:52 Plan Name: Case 201 STATE OF ALASKA ALASKA'oiL AND GAS CONSERVATION COJ~YMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 [] Operation Shutdown [] Stimulate [] Plugging [] Perforate [] Pull Tubing [~]Alter Casing [~ Repair Well [~ OtherSuspend Well Type of well: 6. Datum Elevation (DF or KB) KBE = 64.16' AMSL 7. Unit or Property Name Prudhoe Bay Unit 5. [] Development [] Exploratory I--~ Stratigraphic I~ Service 4. Location of well at surface 1740' SNL, 1608' WEL, SEC. 31, T11 N, R14E, UM At top of productive interval 3871' SNL, 872' WEL, SEC. 36, T11N, R13E, UM At effective depth 3746' SNL, 292' WEL, SEC. 36, T11N, R13E, UM At total depth 4460' SNL, 971' WEL, SEC. 36, T11N, R13E, UM 8. Well Number B-13Al 9. Permit Number / Approval No. 99-057 399-123 10. APl Number 50-029-20341-01 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11295 feet true vertical 8852 feet Effective depth: measured 9772 feet true vertical 8219 feet Casing Length Size Structural Conductor 110' 20"x 30" Surface 2686' 13-3/8" Intermediate 10366' 9-5/8" Production Liner 1188' 7" Tieback Liner 6603' 7-5/8" Plugs (measured) Junk (measured) Cemented MD TVD 454 cu ft Permafrost 110' 5766 cu ft Permafrost 2686' 1062 cu ft Class 'G', 365 cu ft PF 'C' 10366' 517 cuft Class 'G' 230 cuft Class 'G' 110' 2686' 8633' 9844'-10605' 8268'-8805' 3241'-9844' 3235'-8268' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) 7", 26#, L-80 to 3162'; 5-1/2", 17#, NT-80S, 3162' - 9787'; 4-1/2", 12.6#, L-80, 9787' - 10567' Packers and SSSV (type and measured depth) 7" TIW HB-BP packer at 10538'; 7-5/8" TIW HBBP-R retrievable packer at 9807'; 7" Otis 'RPB' BVN at 2112' 13. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 5. Attachments E] Copies of Logs and Surveys run [] Daily Report of Well Operations 16. Status of well classifications as: [] Oil I~ Gas [] Suspended Service 17. I hereby certify that the fgregoing is true and correct to the best of my knowledge Signed ~/~ (p~~ Terrie Hubble v ,¢~ _. Title Technical Assistant III Prepared By Name/Number: Terrie Hubble,s;6~;~SDuplicate~.L~ Form 10-404 Rev. 06/15/88 Well: Field: APl: Permit: .Date B- 13Al Accept: 07/05/99 Prudhoe Bay Spud: 07/08/99 50-029-20341-01 Release: 07/14/99 99-057 CTD Unit: Nordic #1 07/06/99 1 10450' MIRU equipment. N/U BOP stack. Install injector head. 07/07/99 2 10401' Stab CT into injector. Perform initial DOPE test. MU BHA. MU CTC. Fill CT with SW. Work on drilling monitor electronics. RIH with BHA #1 to clean out cement before starting window. Tag first cement at 10401 '. 07/08/99 3 10406' Drilled cement stringers at 10,401 and 10449 ft. Drilled firm cement from 10450- 10601 ft. Stalled 3 times at top of whipstock at 10,601 ft. Flag CT and POOH. M/U BHA #2 with flex joint and 3.80" Concave Diamond Mill #1. Attempt to repair DS drilling screen information. No success. RIH with BHA #2. Mill cement to 10605' and window to 10609' where progress stopped. POOH to check mill. Found mill had cut about 1~ of window. RIH with BHA #3 (3.80" dimple mill with 3.80" string reamer). Open window from 10605'. 07/09/99 4 10850' Reamed window from 10605 - 10608 ft. Continue milling window with 3.80" dimple mill and string reamer from 10608 - 10612 ft. Circulated in new FIoPro mud system. Reamer exited window at 10612 ft bit depth. Drilled 3.80" hole from 10612 -10618 ft. Reamed window area several times. RIH through window with no pump. Window is clean. POOH. Repaired DS drilling information package while POOH. Lay out milling BHA. M/U Drilling BHA with 2.75 deg bent motor and M09 Bit #1. RIH with BHA #4 thru window, clean. Drill ahead building angle and turning left from 10618-684'. Backream to window and tie-in to BHCS at 10604' (add 4.0'). Drill ahead building angle and turning left from 10684-850'. Landed at 90 deg at 8832' TVD. POOH for horizontal drilling assy.. 07/10/99 5 11100' Finish POOH for horizontal drilling assembly. M/U 1.0 deg. motor and DS49 bit. RIH with BHA #5. Correct depth to flag. RIH thru window easily. RIH to TD. Orient TF to 90L. Drill horizontal hole from 10850 - 10982 ft. Short trip due to stacking weight. RIH and drill horizontal hole from 10982 - 11040 ft. Lost all returns at 11040 ft. Drilled 60 ft. to 11,100 ft with no returns. POOH. Lay out drilling BHA. M/U Jetting nozzle to place DS Instanseal LCM product. RIH with BHA #6. Correct to flag at 10,500' EOP. RIH thru window to TD at 11100'. PUH and park at window. DS mix and pump 25 bbls InstaseaFu. RIH with CT to PBD and displace with rig mud while laying in at zone of loss. Pull into casing. Fill hole with 150 bbls fluid and had no returns. RIH to PBD to check hole condition, clean. DS mix 45 bbls InstasealTM. Displace with rig mud at zone of loss. Pull into casing. Fill hole down backside with 55 bbls of fluid and had 1/1 returns. Swap to CT and had no returns. POOH for cementing nozzle. B-13Ai, Coil Tubing Drilling Page 2 07/11/99 6 11110' POOH for cementing nozzle. M/U cementing BHA. RIH with BHA #7. Tag TD at 11,101 ft. Pull to window. R/U cementers. Held Safety Meeting. Mix 29 BBL of 8% Bentonite / G cement slurry with 17 PPB aggregate. Cement at wt at 11:00 hrs. Pump 29 BBLS of 13.5 PPG Cmt and displace with rig pumps. Lay in cement from 11080 - 10650 ft. POOH to safety with no pump. POOH pumping 0.3 BPM. L/O cementing BHA. M/U Drilling BHA #8. Wait on cement for I hour. DS lab sample at 190 PSI. RIH with BHA #8. RIH thru window. Precautionary ream to TD. Recovered partial returns just above zone of loss. Drilled 10' of new hole to 11110' with 2.5 bpm in and 0.3 bpm out. Backream to window. POOH for cementing assy. LD drilling BHA. MU cementing BHA. RIH with BHA #9 to TD. Hole is clean. PUH to window. Mix cement. 07/12/99 7 11110' Held Safety Meeting. Mixed Cement. Staged 26 BBL, 8% Bentonite / G Cmt with 18 PPB Aggregate at 13.8 PPG. Displaced cement with FIoPro. Lay in cement from 11,090 - 10,650 ft, at 1.5 - 1.0 BPM. No returns during cement job. POOH to 8000' with no pump. POOH to surface with 0.3 BPM. L/O Cmtg BHA. M/U drilling BHA #10. RIH. Shallow test MWD, OK. RIH with full returns below 3000 ft. Found top of CMT plug at 10700'. Drilled cement to 10750 ft and WOC one hour. Held Weekly Safety Meeting with crew. Oriented TF and RIH. Drilled cement from 10750 - 11080 ft with full returns. Lost 1.1 BPM at 2.6 BPM pump rate drilling at 11085 ft. Drilled to TD of 11,110 ft. Reamed hole from 11,000 - 11,110 ft. Mud loss steady at 1.1 BPM. POOH for cementing assy. LD drilling assy. MU cementing BHA. RIH with BHA #11 to TD losing 1/2 returns. DS mix and pump 26 bbls of same cement as above. Displace with rig mud and lay in over zone of loss. Returns were nearly 1/1. POOH for drilling BHA. LD cementing BHA. MU drilling BHA. RIH with BHA #12 getting full returns. Tag at 10630'. Drill firm cement at 4'/min with full returns to 10850'. 07/13/99 8 11140' Continue drilling firm cement from 10850' with full returns until 11041' Cleanout to TD at 11110' losing 0.2 BPM. Orient to drill ahead. Drill from 11110-140' and losses slowly increased to 0.7 bpm at rate. POOH for cementing BHA. LD drilling BHA. Cut off 300' CT. MU cementing BHA. RIH with BHA #13 to TD getting 3A returns. DS mix and pump 26 bbls 13.9 ppg Class G cement with 8% bentonite and 18 ppb Perfect Seal. Displace with rig mud to zone of loss and had full returns. POOH. LD cementing BHA. Perform weekly BOP test. MU drilling BHA. RIH with BHA #14. 07/14/99 9 11295' RIH with drilling BHA #14 to clean out cement. Tag top of CMT plug at 10750 ft. Drill CMT at 5 FPM. Held rig H2S Evacuation drill. All Personnel accounted for. Drill out cement to 11050 ft. with full returns. Add LubeTex to mud. Drilled to 11124 ft with full returns [84 ft past first fault] and lost 0.5 BPM. Drilled 11124 - 11224 ft with 0.5 BPM losses. Drilled 11224 - 11253 ft with 2.0 BPM losses. Drilled 11253 - 11280 ft with no returns. POOH. Decision to plug well and move off. TIH w/cement BHA and spot cement (3 bbl Neat, 20 bbl w/18 ppb aggregate, 3 bbl Neat). No returns while pumping cement, partial returns after 10 bbl cement out nozzle. Full returns ant end of job. Displace FIo-Pro w/seawater, POOH 07/15~99 10 9772' Freeze protect tubing w/MeOH. Purge CT w/N2. Clean pits, ND BOP. Release Rig 18:00 Hrs. 7-14-99 STATE OF ALASKA ALASKA'OIL AND GAS CONSERVATION COM-iVllSSION APPLICATION FOR SUNDRY APPROVAL il. Type of Request: [] Abandon [] Suspend [] Plugging []Time Extension [] Perforate ' [] Alter Casing [] Repair Well [] Pull Tubing [] Variance [] Other [] Change Approved Program [] Operation Shutdown [] Re-Enter Suspended Well [] Stimulate 2. Name of Operator BP Exploration (Alaska)Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1740' SNL, 1608' WEL, SEC. 31, T11 N, R14E, UM At top of productive interval 1398' NSL, 918' WEL, SEC. 36, T11N, R13E, UM At effective depth At total depth 4555' SNL, 912' WEL, SEC. 36, T10N, R13E, UM 5. Type of well: I--I Development I--I Exploratory [] Stratigraphic [~ Service 6. Datum Elevation (DF or KB) KBE = 64.16' AMSL 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number B-13Ai 9. Permit Number 99-057 10. APl Number 50-029-20341-01 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 11295 true vertical 8851 Effective depth: measured 10100 true vertical 8445 Casing Length Structural Conductor 110' Surface 2686' Intermediate 10366' Production Liner 1188' Tieback Liner 6603' feet feet feet feet Size 20"x 30" 13-3/8" 9-5/8" u 7-5/8" Plugs (measured) Junk (measured) Cemented 454 cu ft Permafrost 5766 cu ft Permafrost 1062 cu ft Class 'G', 365 cu ft PF 'C' 517 cu ft Class 'G' 230 cu ft Class 'G' MD TVD 110' 110' 2686' 2686' 10366' 8633' 9844'-10605' 8268'-8805' 3241'-9844' 3235'-8268' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth) None Packers and SSSV (type and measured depth) None RECEIVED Ala~k~ 0it & 6as C0r~, O0m~issl0r~, Anchorago 13. Attachments [~ Description summary of proposal [] Detailed operations program E] BOP sketch 4. Estimated date for commencing operation July 14, 1999 16. If proposal was verbally approved Blair Wondzell Name of approver contact Engineer Name/Number: Ted Stagg, 564-4694 7/14/99 Date approved 15. Status of well classifications as: I--~ Oil [--I Gas [~ Suspended Service Prepared By Name/Number: Terrie Hubble, 564-4628 17. I hereby certify that the foregoi.n,g is true and correct to the best of my knowledge Signed ~__/~ Ted Stagg ,,' Title CT Drilling Engineer Commission Use Only Conditions of Approval' Notify Commission so representative may witness I Approval No~ .~¢--/2~ Plug integrity __ BOP Test __ Location clearance __ Mechanical Integrity Test Subsequent form requi[@d 10- ~o~ gbr~ ORIGINAL SIGNED-By ...,-"~'et.~O~~ ~/Co m m ,ss ion er Date Approved by order of the Commission Robe~ ~ Form 10-403 Rev. 06/15/88 ..... ,,,o~F~l ~9- Submit In Triplicate _ hared %_ervices r illi n g Alaska ~ Date: July 14,1999 To.' Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Blair Wondzell Sr. Petroleum Engineer Re: Well B- 13ai Suspension A coil sidetrack of well B-13 commenced on 7/5/99. A series of lost circulation zones were encountered while drilling. The initial loss zones were successfully plugged with lost circulation treatments but additional loss zones were encountered. The extent of the fractured interval reduced the feasibility of the project and a decision was made to suspend the sidetrack for further evaluation. This morning 25 bbls of 13.8 ppg cement were layed in the open hole from 11,040' MD to above the window. Full returns were achieved after placing the cement. The AOGCC field inspector waived witnessing the cement job. A pressure test and tag of the suspension plug will be carried out on 7/15/99 or 7/16/99 with the opportunity for AOGCC witness of that operation. We are requesting that B-13ai be placed on suspended status pending evalu~~ sidetrack options. Ted Stagg CT Drilling Engineer cc: Well File Petrotechnical Data Center MEMORANDUM TO: State of Alaska Alaska Oil and Gas Conservation Commission Robert Christensor~ DATE: July 6, 1999 Chairman THRU' Blair Wondzell, ~.~~,~]~ ? P. I. Supervisor FROM: Lawrence M aV~~de SUBJECT: Petroleum Inspector FILE NO: ajzggfgf. DOC BOP Test DS/Nordic 1 PBU DS B-13AI PTD 99-57 July 6,1999: I went to witness a BOP test on Nordic 1, a coil tubing drilling rig. It has been down 3 weeks for summer maintenance. They sent their BOP stack and derrick to town to be tested and repaired along with a lot of other rig parts. We started at 9:30 AM and found the ram seals leaking on the 2 7/8' combination rams. Replaced the door seal and couldn't get the rams to hold. Changed out the rams and found a leak on the bonnet on the manual valve on the kill line side. Also found a flange leak on the stack. All the stack bolts were hammered up and the rest of the testing went well. SUMMARY: Witnessed a BOP test on Nordic 1, 2 failures, 9 % hour test Attachments: ajzggfgf, xls cc; NON-CONFIDENTIAL STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Workover: ~ Drlg Contractor: DS/NORDIC Rig No. Operator: BP EXPLORATION Well Name: B-13AI Casing Size: 7" Set @ 11,032 Test: Initial X Weekly Other DATE: 7/6/99 1 PTD # 99-57 Rig Ph.# 907- 659-4434 Rep.: RICK WHITLOW Rig Rep.: DOUG YESSAK Location: Sec. 31 T. 11N R. 14E Meridian UM BOP STACK: Coil Tubing Unit: Pipe/Slip Rams Pipe/Slip Rams Blind/Shear Rams =,eel Isolation Valve Deployment: Annular Preventer Slip Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Quan. Pressure P/F 250-4000 N/A N/A 1 250-4000 P 1 250-40O0 P P 250-2500 N/A N/A 1 250-4000 P N/A N/A 250-4000 250-4000 250-4000 Test CHOKE MANIFOLD: Quan. Pressure No. Valves 15 1250-4000 No. Flanges 321250-4000 Manual Chokes 1 I Functioned Hydraulic Chokes 1 I Functioned P/F P ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure ~ System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 3000 I 1900 minutes 25 2 minutes 10 YES Remote: 2300-2200-2000 Psig. sec. sec. YES 1 1 2 MUD SYSTEM: Visual Alarm Trip Tank YES YES Pit Level Indicators YES YES Meth Gas Detector YES YES H2S Gas Detector YES YES MISC. INSPECTIONS: Location Gen.: GOOD Housekeeping: GOOD Permit to drill: YES Standing Order Posted YES Well Sign YES Drl. Rig GOOD Hazard Sec. YES Number of Failures: 2 ,Test Time: c~/".z. Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: MANUAL HCR - TESTED GOO[. D RETIGHTEN ALL FLANGES, TESTED GOOD CHANGED 2 3/8" COMBINATION RAM SEALS- TESTED GOOD. CHANGED BONNET SEAL ON 3" Distribution: orig-Well File c - Oper./Rig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES XX NO 24 HOUR NOTICE GIVEN YES XX NO Waived By: Witnessed By: LARRY WADE Form Revised '116/97 DA. ctboptst TONY KNO WL ES, (30 VEFINOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 June 24. 1999 Ted Stagg CT Drilling Engineer BP Exploration (Alaska) Inc. POBox 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bav Unit B-13Ai BP Exploration (Alaska) Inc. Permit No: 99-57 Sur. Loc. 1740'SNL. 1608~WEL. Sec. 31. TllN. R14E, UM Btmhole Loc. 5211'NSL 356'WEL. Sec. 01, T10N, R13E, UM Dear Mr. Stagg: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmcntal agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035: and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test prior to drilling new hole must be given so that a representative of thc Commission may witness the tests. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. rlstenson. P.E.' Chairman BY ORDER OF THE COMMISSION dlffEnclosure CC: Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASKA ,~IL AND GAS CONSERVATION COI~11VilSSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work [-I Drill [] Redrill Ilb. Type of well [] Exploratory I--I Stratigraphic Test [] Development Oil [] Re-Entry [] DeepenI [] Service [] Development Gas []Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 64.16' AMSL Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 047472 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 1740' SNL, 1608' WEL, SEC. 31, T11N, R14E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number 2S100302630-277 1398' NSL, 918' WEL, SEC. 36, T11N, R13E, UM B-13Ai At total depth 9. Approximate spud date Amount $200,000.00 5211' NSL, 356' WEL, SEC. 01, T10N, R13E, UM 06/25/99 'i'2. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028286, 69'I No Close Approach 2560 12422' MD / 8851' i'6. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)} Kick Off Depth 10610' Maximum HoleAn,qle 96° Maximum surface 3300 psig, At total depth (TVD) 8800'/4390 psig 18. Casing Program Setting Depth Size Specifications Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 3-3/4" 2-7/8" 6.16# L-80 ST-L 2172' 10250' 8485' 12422' 8851' i112 cuft Class 'G' .... i9. To be completed for Redrill, Re-entry, and Deepen OperationS.Present well condition summary ~AL Total depth: measured 11032 feet Plugs (measured) dUN 7 4 999 true vertical 9114 feet Effective depth: measured 10940 feet Junk (measured) Junk from three EZ drills to 109~c~8~0]~ true vertical 9048 feet Anchc°~'or~n= C0r~mj Casing Length Size Cemented MD Structural Conductor 110' 20"x 30" 454 cu ft Permafrost 110' 110' Surface 2686' 13-3/8" 5766 cu ft Permafrost 2686' 2686' Intermediate 10366' 9-5/8" 1062 cu ft Class 'G', 365 cu ft PF 'C' 10366' 8633' Production Liner 1188' 7" 517 cu ft Class 'G' 9844' - 11032' 8268' - 9115' Tieback Liner 6603' 7-5/8" 230 cu ft Class 'G' 3241' - 9844' 3235' - 8268' Perforation depth: measured 10608' - 10675'; Straddled: 10484' - 10502' true vertical 8807' - 8855'; Straddled: 8718' - 8731' 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program []Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Ted Stagg, 564-4694 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that ~.~e fo~~is true and correct to the best of my knowledge Signed ,., Ted Stagg ~//,.../"~"~'? ~' Title CT Drilling Engineer Date , . f / / Commission Use Only /~:~? ,,~7 50-029-20341-01 ~.~,_~,;~.~,¢'_.~: See cover letter - for other requirements Conditions of Approval: Samples Required []Yes ~r'No Mud Log Required []Yes [~]'No Hydrogen Sulfide Measures ~lYes"l~'No Directional Survey Required ~[Yes'[~No Required Working Pressure for BOPE ' 1'-I2K; [~,3K; 1-14K; [] 5K; [] 10K; I--I 15K Other: ORIGINAL SIGNED'BY by order of ~Approved By Robert N. Christerlsorl Commissioner the commission Date Form 10-401 Rev. 12-01-85 Submit In Triplicate BPX B-13ai Sidetrack Summary of Operations: B-13 has been a water injector since 1985. The sidetrack, B-13ai, will relocate injection to better flood upper Zone 4. This sidetrack will be conducted in two phases. Phase 1: Set whipstock, squeeze cement: Planned for June 19, 1999. · A Mechanical Integrity Test has been performed. A Kinley caliper has been run over the tubing and liner. · A permanent whipstock will be set on ELine at approximately 10,600' MD and Ivishak perfs will be cement squeezed. Phase 2: Mill Window and Drill Directional Hole: Planned for June 25, 1999. Directional drilling coiled tubing equipment will be rigged up and utilized to mill the window and drill the directional hole as per attached plan to planned TD of 12,422' MD (8,851' TVDss). Mud Program: - Phase 1: Seawater · Phase 2: Seawater and FIo-Pro (8.7 - 8.8 ppg) Disposal: - No annular injection on this well. - All drilling and completion fluids and all other Class II wastes will go to CC-2a for injection. - All Class I wastes will go to Pad 3 for disposal. Casing Program: - 2 7/8", 6.16#, L-80, ST-L liner will be run from TD to approx. 10,250' MD and cemented with approx. 20 bbls. cement to bring cement 350 ft above the window. The well will then be perforated with coiled tubing conveyed guns. Well Control: - BOP diagram is attached. - Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 4000 psi. - The annular preventer will be tested to 400 psi and 2000 psi. Directional - See attachments. - Kick Off: 10,610' MD (8,744' TVD ss) - TD: 12,422' MD (8,851' TVD ss) - Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · A Gamma Ray log will be run over all of the open hole section. · Memory Induction Log Section Path Distance (Feet) 500 1,000 1,500 2,000 2,500 3,000 W,EG ¢~ I ~lFadt I ....... 8;-7'7 ...................................................................... Drld:1812 ft 12422 TD Marker Depths ~tOrig Wellbore I 8,8301 8,8301~t TVD TSAD I 8,7411ft 1¥D I MD KO Pt lO,61oI MD New Hole 1812I I Total MD 12,422I TVD TD 8,8511 DLS deg/100 Tool Face Length Curve 1 6 0 ~0 Curve 2 36 -50 215 Curve 3 10 -90 549 Curve 4 8 180 130 Curve 5 8 90 299 Curve 6 8 -90 599 1,812 Drawn: 6/14/99 15:01 Plan Name: Case 101 · . '~ KB. ELEV = 64.16' B-13ai Proposed Complet,on TREE: 7-1/16" 5M CIW BF. ELEV = 37.72' WELLHEAD: 13-5/8" 5M McEvoy Cony. ACTUATOR: OTIS 7" OTIS LANDING NIPPLE FOC I13-3/8'' 72# L'8° 2686' BUTT, CSG. 3241' I 7-5/8"TIW LINER HANGER 7-5/8" 29.7# NT-80S FL4S TIEBACK W/INSERT, ID= 3.813" W/O,INSERT, ID= 5.962" 2112' Crossover, 7" IJ4S X 5-1/2" NSCC I3161' KOP: 2800 MAX ANGLE: 48° @ 6900' 5.5" 17# NT-80S NSCC TUBING, ID= 4.892" CAP=0.02324. BBLS/FT TAILPIPE 4.5" 12#/FT, TDS TUBING, ID= 3.958" CAP= 0.01521. BBLS/FT I 7" BOTTIEBACK 9844' RECEPTACLE I I 9-5/8" 47# L-80 10366' BUTT,CSG. 2 7/8" cemented liner PERFORATION SUMMARY ELF LOG: SWS- BHCS- 1-10-79 SlZFI SPF I INTERVAL )PEN/SQZ'D 3 3/8"I 6 10484'- 10502' STRDLD/8-2-87 4 OPEN/11-11-84 2 7/8 I 10608' - 10675' 3 3/8I 6 I 10675'- 10685' OPEN/8-2-87 4" I 10685'- 10704' OPEN/7-14-89 4" I 10714' - 10734 ..... 4" I 10744' - 10822 ..... 3 3/8"I 4 10844' - 10876' OPEN/8-2-87 3 3/8"I 1 10876' - 10896 ..... IWhipstock ~ · Crossover, 5-1/2" NSCCX 4-1/2" TDS 4.5" PARKER-SWS-NIPPLE ID= 3.813" 5/8" TIW(HBBR-R ) RETR. PACKER ID= 3.890" 9785' 9798' 9807' Caution' the TIW packers in this well may fail if more than 2100 psi differential pressure is exceeded. ,7" TIW (HBBP) Packer I ID= 4.00" I 10538' 4.5" PARKER-SWS-NIPPLE I ID= 3.813" 10548' 4.5" PARKER-SWS-NIPPLEiD= 3.813" I 10559' WLEG I 10567' ELMD I 10565' IAbandonment Cement 10948' I PBTD 7",29#/ff, L-80, 11032' I BUTT, CSG. NOTE: JUNK FROM 3 E-Z DRILLS WELL PERMIT CHECKLIST WELLNAMF~ ~"-".,,Z~-~.~' PROGRAM:exp dev ~ GEOL AREA FIELD & POOL ADMINISTRATION APPR-- DATE INIT CLASS /- ENGINEERING APPR-~ DATE 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in ddlling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N Y N N 14. Conductor string provided ................... /f"Y~ N 15. Surface casing protects all known USDWs ........... ~ N 16. CMT vol adequate to circulate on conductor & surf csg ..... N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... %~, N 19. Casing designs adequate for C, T, B & permafrost ....... ~ N 20. Adequate tankage or reserve pit ................. ~ N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~) N / 23. If diverter required, does it meet regulations .......... 24. Drilling fluid program schematic & equip list adequate ..... 25. BOPEs, do they meet regulation ................ /~ N 26. BOPE press rating appropriate; test to _.~O (3(:~ psig. /Y(,¥,) N 27. Choke manifold complies w/APl. RP-53 (May 84) ........ /~ N 28. Work will occur without operation shutdown ........... (~ N redrll serv ~ wellbore seg __ UNIT# ann. disposal para req __ ON/OFF SHORE GEOLOGY 29. Is presence of H2s gas probable ................. (~) N 30. Permit can be issued w/o hydrogen sulfide measures ..... ~Y N / 31. Data presented on potential overpressure zones ....... Y/~/ 32. Seismic analysis of shallow gas zones ............. ,~y ~ . _ 33. Seabed condition survey (if off-shore) ............. / 34. Contact name/phone for weekly progress reports [exploratory,,~ily] Y N _A N_ _NU__L. A__R_ D_ I_s__P_0...SA.L. APPR DATE 35. With proper cementing records, this pla, p~~ (A) will contain waste in a suitable re, c~iving zone; ....... Y N (B) will not contaminat~shwat~, or cause drilling waste. ~. Y N to surface;/' (C) will not ~an~l integrity of the well u~ed'for disposal; Y N (D) will ~ro~cing formation or inlp~r recovery from a Y N pool4~nd (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N ENGINEERING: ~.~. COMMISSION: BEW(~ ~ ~'('~ DW~~'~ JDH ' ~ RNC' CO Ez:) 6,/! ~ I,~ '~ Comments/Instructions: c:\msoffice\wordian\diana\checklist Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun~ .Jilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Tue May 09 12:26:45 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/09 Origin ................... STS Reel Name ................ UNK/qOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/05/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MW- 90135 BLID JA/4_N WHITLOW/SEVC RECEIVED 1 6 .000 Alaska 0il & Gas COns, CommissJor, B - 13 APB 1 Anchorage 500292034170 BP Exploration (Alaska) , Inc. Sperry Sun 24 -APR- 00 MWD RUN 2 MWD RUN 3 AK-MW- 90135 AK-MW- 90135 BUD JA_HN BUD JA}{N WHITLOW/SEVC WHITLOW/SEVC JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 5 AK-MW- 90135 BUD JA}{N WHITLOW/SEVC MWD RUN 6 AK-MW- 90135 BUD JA}IN WHITLOW/SEVC 31 liN 014 1740 1608 64 . 16 .00 .00 OPEN HOLE CASING DRILLERS BI_ JIZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 10601.0 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 - 6 ARE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. NO FOOTTAGE DRILLED ON MWD RUN 400 DUE TO LOSS OF RETURNS. 4. DEPTH SHIFING / CORRECTION OF MWD DATA IS WAIVED DUE TO LACK OF OVERLAP WITH PUC LOG OF 9/4/99 (PUS GR) . WELL B-13A IS THE ACTIVE WELL. KICKOFF POINT FOR THIS WELLBORE IS 10601' MD, 8738' SSTVD (TOP OF WHIPSTOCK). 5. MWD RUN 1 - 6 REPRESENT WELL B-13APB1 WITH API 50-029-20341-70. THIS WELL REACHED A TOTAL DEPTH OF 11295' MD, 8787' SSTVD. SGRD = SMOOTHED GAMMA RAY SROP = SMOOTHED P~ATE OF PENETRATION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NIIMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10601.5 11266.0 ROP 10631.0 11295.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 10601.5 10850.0 2 10850.5 11100.0 3 11100.5 11110.0 5 11110.5 11138.0 6 11138.5 11295.0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10601.5 11295 10948.3 1388 ROP MWD FT/H 1.12 1876.95 109.748 1329 GR MWD API 23.22 202.34 43.3894 1330 First Reading 10601.5 10631 10601.5 Last Reading 11295 11295 11266 First Reading For Entire File .......... 10601.5 Last Reading For Entire File ........... 11295 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 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 ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10601.5 10820.5 ROP $ LOG HEADER DATA 106~_-.0 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: 10850.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 TEMPEP~ATURE (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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 09-JUL-99 Insite 7.74 Memory 10850.0 44.0 89.3 TOOL NUMBER 002 3.750 FLOPRO 8.55 56.0 10.5 22600 7.7 .000 .000 .000 .000 .0 124.8 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max DEPT FT 10601.5 10850 ROP MWD010 FT/H 1.12 1876.95 GR MWD010 API 25.18 202.34 Mean Nsam 10725.8 498 100.592 439 50.1384 439 First Reading 10601.5 10631 10601.5 Last Reading 10850 10850 10820.5 First Reading For Entire File .......... 10601.5 Last Reading For Entire File ........... 10850 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 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 ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10821.0 11071.0 ROP 10850.5 11100.0 $ LOG HEADER DATA DATE LOGGED: 09-JUL-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11100.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 92.6 MAXIMUM ANGLE: 94.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA TOOL NUMBER 001 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 3.750 FLOPRO 8.55 56.0 9.5 25000 7.8 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 .0 91.1 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 10821 11100 10960.5 559 ROP MWD020 FT/H 57 261.48 125.287 500 GR MWD020 API 23.72 109.62 39.9841 501 First Reading 10821 10850.5 10821 Last Reading 11100 11100 11071 First Reading For Entire File .......... 10821 Last Reading For Entire File ........... 11100 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 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 ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11071.5 11080.5 ROP 11100.5 11110.0 $ LOG HEADER DATA DATE LOGGED: ll-JI3L-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11110.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 94.5 MAXIMUM ANGLE: 94.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NI/MBER 002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 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: FLOPRO 8.55 65.0 9.5 23000 18.8 .000 .000 .000 .000 .0 120.6 .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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11071.5 11110 11090.8 78 ROP MWD030 FT/H 34 86 48.55 20 GR MWD030 API 30.07 32.69 31.7968 19 First Reading 11071.5 11100.5 11071.5 Last Reading 11110 11110 11080.5 First Reading For Entire File .......... 11071.5 Last Reading For Entire File ........... 11110 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 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 ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11081.0 ROP 11110.5 STOP DEPTH 11108.5 11138.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 12 -JUL- 99 Insite 7.74 Memory 11138.0 94.4 95.5 TOOL NUMBER 002 3.750 FLOPRO 8.60 63.0 10.0 23500 14.4 .000 .000 .000 .000 .0 144 . 0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit Min Max DEPT FT 11081 11138 ROP MWD050 FT/H 41 260 GR MWD050 API 30.44 44.64 First Mean Nsam ..... Reading 11109.5 115 11081 94.9821 56 11110.5 35.0843 56 11081 Last Reading 11138 11138 11108.5 First Reading For Entire File .......... 11081 Last Reading For Entire File ........... 11138 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NLTMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11109.0 11266.0 ROP 11138.5 11295.0 $ LOG HEADER DATA DATE LOGGED: 13-JUL-99 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11295.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 96.0 MAXIMUM ANGLE: 98.2 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): TOOL NLTMBER 0O2 3 .750 DRILLER'S CASING L_~TH (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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 FLOPRO 8.60 56.0 10.5 22600 21.2 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 .0 124.8 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11109 11295 11202 373 ROP MWD060 FT/H 37 938 104.338 314 GR MWD060 API 23.22 136.32 41.5755 315 First Reading 11109 11138.5 11109 Last Reading 11295 11295 11266 First Reading For Entire File .......... 11109 Last Reading For Entire File ........... 11295 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/09 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/09 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/05/09 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File Sperry-Sun .~lling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon May 08 10:33:52 2000 Reel Header Service name ............. LISTPE Date ..................... 00/05/08 Origin ................... STS Reel Name ................ UNKI~OWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 00/05/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: B-13A 500292034101 BP Exploration Sperry Sun 08-MAY-00 MWD RUN 1 MWD RUN 2 AK-MW-90150 AK-MW-90150 S. LATZ S. LATZ WHITLOW/MASK WHITLOW/MASK RECEIVED ! 6 2000 Alaska 0il & Gas Cons. Commission Anchorage (Alaska) Inc. MWD RUN 3 AK-MW-90150 S. LATZ WHITLOW/MASK JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RA/qGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 4 AK-MW-90150 S, LATZ WHITLOW/SEVC MWD RUN 5 AK-MW-90150 B. JAHN WHITLOQ/SEVI 31 liN 14E 1740 1608 64 . 16 .00 37 .72 OPEN HOLE CASING DRILLERS MWD RUN 6 AK-MW-90150 B. JA_HN WHITLOW/SEVC 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING RENLARKS: BI'. IiZE (IN) SIZE (IN) DEPTH (FT) 3.750 7.000 10601.0 3.750 3.750 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUN 1 - 6 ~RE DIRECTIONAL WITH NATURAL GAMMA PROBE (NGP) UTILIZING A SCINTILLATION DETECTOR. 3. DIGITAL DATA ONLY IS DEPTH CORRECTED TO THE PDC LOG OF 9/4/99 (PDS GR) WITH A KBE OF 64.16' AMSL. KICKOFF POINT FOR THIS WELLBORE IS AT 10601' MD, 8738' SSTVD (TOP OF WHIPSTOCK). 4. MWD RUN 1 - 6 REPRESENT WELL B-13A WITH API ~ 50-029-20341-01. THIS WELL REACHED A TOTAL DEPTH OF 12245' MD, 8905' SSTVD. SGRD = SMOOTHED GAMMA R3kY SROP = SMOOTHED R3kTE OF PENETR3kTION $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 10572.5 12213.5 ROP 10603.0 12239.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH 10572 5 10582 10583 10586 10587 10590 10604 10607 10627 10636 10644 10646 10648 GR 10570.5 10580.0 10582.5 10585.0 10586.0 10589.0 10602.5 10605 5 10625 5 10634 5 10643 0 10644 5 10647 0 EQUIVALENT UNSHIFTED DEPTH 10653 10658 10663 10669 10685 10693 10699 10707 10734 10740 10745 10752 10754 10758 10761 10790 10792 10798 10801 10807 10821 10864 10872 10873 10874 10880 10881 10911 10919 10921 10923 10929 10930 10933 10934 10939 10941 10944 10948 10959 10962 10970 10973 10984 10988 10990 10992 10996 11002 11006 11011 11029 11034 11038 11044 11045 11047 11049 11054 11059 11064 11069 11074 11081 11086 11089 11091 11098 106[ .0 10656 5 10661 0 10667 5 10683 0 10690 5 10696 5 10705 0 10731 5 10737 5 10742 5 10749 0 10751 0 10754 5 10757 5 10786 10790 10795 10797 10803 10814 10858 10866 10867 10868 10871 10873 10899 10908 10911 10912 10918 10919 10923 10924 10928 10930 10932 10936 10948 10951 10958 10961 10970 10975 10977 10978 10984 10989 10993 10999 11016 11020 11025 11030 11031 11033 11035 11040 11045 11050 11054 11059 11066 11070 11072 11074 11083 11102 0 11105 5 11107 0 11116 5 11123 0 11140 5 11143 5 11146 5 11147 5 11158 5 11160 0 11170 5 11179 5 11184 0 11191 0 11204 5 11221 5 11227 5 11255 5 11335 5 11339 5 11345 5 11382 0 11397 5 11401 5 11407 0 11409 0 11414 5 11416 0 11472 0 11494 5 11500 5 11506 0 11512 0 11520 5 11522 5 11528 5 11723 0 11727 0 11734 5 11789 5 11795 5 11815 0 11845 0 11848 5 11851 0 11856 0 11878 5 11898 5 11903 5 11913 0 11917 0 11924 0 11933 5 11939 0 11941 5 11972 5 11984 0 11994 5 12000 5 12025 0 12040 5 12059 5 12070 5 12078 0 12081 0 12083 . 5 12088.0 110~ _3 11090 5 11092 0 11101 5 11107 5 11125 0 11128 5 11131 5 11133 0 11143 5 11145 5 11161 0 11178 5 11183 5 11189 5 11204 0 11221 0 11228 0 11255 5 11332 11336 11342 11378 11393 11397 11403 11405 11410 11413 11469 11497 11504 11509 11514 11522 11524 11529 11723 11729 11736 11791 11797 11816 11845 11849 11852 11858 11881 11901 11905 11915 11919 11924 11934 11939 11942 11979 11990 12002 12008 12034 12049 12069 12079 12089 12092 12097 12100 12094 0 12111 12137 12148 12185 12201 12205 12239 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: 121t 3 12125.5 12143.0 12154.0 12192.0 12208.0 12210.5 12245.0 BIT RUN NO MERGE TOP 1 10570.5 2 10827.5 3 11195.5 4 11393.5 5 11879.5 6 11976.5 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 MERGE BASE 10827 0 11195 0 11393 0 11879 0 11976 0 12245 0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10572.5 12239.5 11406 3335 ROP MWD FT/H 5.3 1436.6 92.6551 3274 GR MWD API 17.83 252.42 45.5602 3283 First Reading 10572.5 10603 10572.5 Last Reading 12239.5 12239.5 12213.5 First Reading For Entire File .......... 10572.5 Last Reading For Entire File ........... 12239.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 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 ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10570.5 10796.5 ROP 10601.5 10827.0 $ LOG HEADER DATA DATE LOGGED: 04-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 10827.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 49.6 MAXIMUM ANGLE: 72.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ TOOL NUMBER 002 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.750 10601.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: FLOPRO 8.70 65.0 .0 22000 7.6 .000 .000 .000 .000 .0 133.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specificatio~ ._ecord Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 10570.5 10827 10698.8 514 ROP MWD010 FT/H 10.1 146.1 53.6392 452 GR MWD010 API 24.31 252.42 55.7527 453 First Reading 10570.5 10601.5 10570.5 Last Reading 10827 10827 10796.5 First Reading For Entire File .......... 10570.5 Last Reading For Entire File ........... 10827 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 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 ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10797.0 11163.5 ROP 10827.5 11195.0 $ LOG HEADER DATA DATE LOGGED: 04-MAY-00 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 NGP NATURAL GAMMA PROBE $ 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 TERMPEP~ATURE: 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 7.74 Memory 11195.0 88.4 97.6 TOOL NUMBER 002 3.750 10601.0 FLOPRO 8.70 65.0 10.2 22000 7.4 .000 .000 .000 .000 .0 137.0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 Name Service Unit DEPT FT ROP MWD020 FT/H Min Max Mean Nsam 10797 11195 10996 797 16.9 422.5 95.1818 736 First Reading 10797 10827.5 Last Reading 11195 11195 OR MWD020 API 2_ ~8 168.56 58.9204 73 10797 11163.5 First Reading For Entire File .......... 10797 Last Reading For Entire File ........... 11195 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 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 ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11164.0 11366.5 ROP 11195.5 11393.0 $ LOG HEADER DATA DATE LOGGED: 04-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11393.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 97.2 MAXIMUM ANGLE: 99.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (iN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: TOOL NUMBER 42 3.750 10601.0 FLOPRO MUD DENSITY (LB/G). . MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEPJtTURE (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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 8.70 65.0 10.2 22000 7.4 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 .0 142.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11164 11393 11278.5 459 ROP MWD030 FT/H 58.5 1436.6 131.37 396 GR MWD030 API 23.21 151.22 38.8542 406 First Reading 11164 11195.5 11164 Last Reading 11393 11393 11366.5 First Reading For Entire File .......... 11164 Last Reading For Entire File ........... 11393 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 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 ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11367.0 11848.0 ROP 11393.5 11879.0 $ LOG HEADER DATA DATE LOGGED: 01-JAN-70 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 11879.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 82.9 MAXIMUM ANGLE: 95.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ 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 NUMBER. 002 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 3.750 10601.0 REMARKS: $ Data Format Specification Record FLOPRO 8.70 65.0 9.3 21500 7.2 .000 .000 .000 .000 .0 142.0 .0 .0 Data Record Type ................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined AlDsent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11367 11879 11623 1025 ROP MWD040 FT/H 31.8 487 87.5534 972 GR MWD040 API 21.89 168.66 34.4592 963 First Reading 11367 11393.5 11367 Last Reading 11879 11879 11848 First Reading For Entire File .......... 11367 Last Reading For Entire File ........... 11879 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11848.5 11945.0 ROP 11879.5 11976.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE V~ .~ION: 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 NGP NATURAL GAMMA PROBE $ 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Insite 7.74 Memory 11976.0 80.7 84.2 TOOL NUMBER 002 3.750 10601.0 FLOPRO 8.7O 65.0 10.6 22000 6.8 .000 .000 .000 .000 .0 142 . 0 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 Name Service Unit Min Max Mean Nsam DEPT FT 11848.5 11976 11912.3 256 ROP MWD050 FT/H 77 194.8 115.078 194 GR MWD050 API 28.47 96.95 47.0819 194 First Reading 11848.5 11879.5 11848.5 Last Reading 11976 11976 11945 First Reading For Entire File .......... 11848.5 Last Reading For Entire File ........... 11976 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE N-UMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN N-gMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11945.5 12219.0 ROP 11976.5 12245.0 $ LOG HEADER DATA DATE LOGGED: 04-MAY-00 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 7.74 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT) : 12245.0 TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM A/~GLE: 66.8 MAXIMUM ANGLE: 80.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): TOOL NUMBER O02 3.750 10601.0 FLOPR0 8.65 MUD VISCOSITY (S) :. MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPEP~ATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPEP~ATURE: 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 ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 65.0 9.3 22000 7.6 .000 .000 .000 .000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 .0 209.0 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 11945.5 12245 12095.3 600 ROP MWD060 FT/H 5.2 199.7 94.8124 538 GR MWD060 API 17.83 171.7 39.7458 548 First Reading 11945.5 11976.5 11945.5 Last Reading 12245 12245 12219 First Reading For Entire File .......... 11945.5 Last Reading For Entire File ........... 12245 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 00/05/08 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 00/05/08 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 00/05/08 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Scientific Technical Services Technical Services Physical EOF Physical EOF End Of LIS File