Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
205-018
· . Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~ 0 5 - 0 L <6 Well History File Identifier Production Scanning Stage 1 Page Count from Scanned File: -..!J..L (Count does include cover sheet) VYES Organizing (done) o Two-sided 11111111I1111111111 RES CAN \Ø'f:,olor Items: ¡GreYSCale Items: \ ~ o Poor Quality Originals: DIGITAL DATA ~skettes, No. d- O Other, NolType: o Other: NOTES: Date S/ d-.I.f I Qb I I Date s/;}-.lf} D(P I ~ BY: ~ Project Proofing BY: ~ Scanning Preparation BY: Date: Page Count Matches Number in Scanning preraration: ~ Date:5/d-Lt/Db Stage 1 If NO in stage 1, page(s) discrepancies were found: BY: BY: Maria Date: Scanning is complete at this point unless rescanning is required. o Rescan Needed 1111111111111111111 OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) o Logs of various kinds: o Other:: VVLP 11I1111111111/ 11111 '~ + I () = TOTAL PAGES 70 (Count does not include cover Sheet) 151 151 151 11111111111I11 "'II NO YES 151 mr NO 151 11111111I11I11 1111I ReScanned BY: Maria Date: 151 Comments about this file: 11111111111I1111111 Quality Checked 111111111111111111I 10/6/2005 Well History File Cover Page.doc • tali,4::: 4;..Ni Y g ,,,,..s, STATE OF ALASKA .. ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG(;.)GC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other IS Abandoned 0 Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero 0 Development ®Service • 2. Operator Name: 5.Date Comp.,Susp.,or Abend.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 2/20/2014 205-018 313-584 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 _ 3/14/2005 50-029-21142-02-00 • 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 3/20/2005 PBU 03-33B 215 FSL,821'FWL, Sec. 11,T10N, R15E, UM Top of Productive Horizon: 8. KB(ft above MSL): 56.39' 15. Field/Pool(s) 2470'FSL, 5191'FWL, Sec. 11,T1 ON, R15E, UM GL(ft above MSL): 27.89' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 4405 FSL, 773'FWL, Sec. 12,T10N, R15E, UM 10935' 8932' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 714114 y- 5936278 Zone- ASP4 13072' 8917' ADL 028327 TPI: x- 718416 y- 5938658 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 719220 Y- 5940617 Zone- ASP4 None 18. Directional Surve : 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): Y ❑Yes ®No N/A ft MSL 1900'(Approx. A (Submit electronic and printed information per 20 AAC 25.050) PP ) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD DIR/GR/PWD, MWD DIR/GR/RES/ABI, USIT 9594' 8004' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 110' Surface 110' 30" 1910#Poleset 13-3/8" 72# L-80 Surface 2506' Surface 2506' 17-1/2" 2300 sx Coldset III,400 sx CS II 9-5/8" 47# L-80 Surface 9594' Surface 8004' 12-1/4" 500 sx Class'G',300 sx CS I 7" 26# L-80 3018' 10572' 3016' 8722' 8-1/2" 234 sx Class'G',452 sx Class'G', 136 sx Class'G' 4-1/2" 12.6# L-80 10391' 13072' 8589' 8917' 6-1/8" 328 sx Class'G' 24. Open to production or injection? ❑Yes ®No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): 4-1/2", 12.6#, L-80 10395' 10338'/8550' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. NED W MAY 2 2,014i...E, tf WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes IN No % t ,<LIh i rF DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11070' Set CIBP 1:'.1'' /T 10935' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Injection N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No Sidewall Core(s)Acquired? 0 Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS APR 1.7 10& Form 10-407 Revised 10/2012 CONTINUED ON REVERSE (� Submit Original Only V`LF 4/23119- Y/��iy' .z� . ✓c->< 29. GEOLOGIC MARKERS(List all formations an ,kers encounter 30. FORMATION TESTS NAME MD ND Well Tested? 0 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. Coleville Mudstone 9798' 8150' None HRZ 10257' 8492' Sadlerochit 10584' 8731' 43P 10614' 8753' 42N 10658' 8785' 42P 10707' 8821' 41N 10723' 8832' 31P 10748' 8848' 27P 10832' 8894' Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Travis Boltz,564-5750 Email: Travis.Boltz@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: Phone 564-4091 Date: MOh+ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only 03-33B, Well History (Pre-Rig Sidetrack) Date Summary 02/03/14 B&C#1 w/1.75"CT. Job Objective: Mill XN Nip,drift dmy whipstock&set CIBP. MIRU. M/U 3.800" Diamond Parabolic LH Milling BHA. RIH to 10359'CTMD and mill XN,continued drift down to 11423' CTMD. FP well w/20bbls of 60/40 methanol. POOH. Gauged mill at surface, 3.79" ID. MU PDS logging tools and 3.705"x13.98' Dmy whipstock&RIH.**********************************XN NIPPLE AT 10383' HAS BEEN MILLED OUT TO 3.79"ID.*********************************** 02/03/14 T/I/O 0/0/0 Temp=SI Frreze Protect FL for Halliburton CTU Pump 60 bbls Neat down Flowline. CTU on well at departure. 02/04/14 Bridge Plug [BPS]-B&C#1 W/1.75"CT. JOB OBJECTIVE: MILL XN NIP, DRIFT DMY WHIPSTOCK& SET CIBP. RIH W/PDS GR/CCL LOGGING TOOLS AND 3.705"X13.98'DMY WHIPSTOCK DOWN TO 10250'WITHOUT ANY ISSUES. LOG JEWELRY PASS UP @ 10383'. 02/04/14 B&C#1 w/1.75"CT. Job Objective: Mill XN Nip,drift dmy whipstock&set CIBP. RIH w/PDS GR/CCL logging tools and 3.705"x13.98' Dmy whipstock down to 10250'without any issues. Log jewelry pass up at 50fpm from 11250'to 10200'. Paint yellow/red flag at 11000'. POOH and process logging data, +11' correction. MU BKR 4-1/2"CIBP and RIH. CIBP set at 11070 and pressure tested(see log). POOH. SITP 200psi. RDMO. 02/12/14 T/I/O=Vac/0/0. Set 4"CIW H-TWC#260(pre-CTD). See log. RDMO. 02/12/14 T/I/O=TWC/0/0; Install Sarbor test spool#4 on SV and conduct Pre-CTD torque and test on all tree valves including THA to MV; Pull 4-1/16"CIW"H"TWC#260,tagged at 135";Valve tests for Nordic still need to be conducted after disconnect; Final T/I/O=0/0/0; 02/19/14 T/1/O=0/0/0.Torqued all tree flanges to API specs for Nordic 1. (see log) RDMO. Page 1 of 1 North America-ALASKA-BP Page 1.01 ,3 Operation Summary Report Common Well Name:03-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/17/2014 End Date: X3-0146M-C:(4,018,586.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 1 Spud Datemme:7/26/1984 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292114200 Active datum:28.5+27.89 4156.39 @56.39usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/17/2014 09:00 - 11:00 2.00 MOB P PRE RIG RELEASE FROM WELL DS 1-19 AT 0900 HRS, CONTINUE WITH PREPPING RIG AND LOCATION FOR MOVING OFF OF DS 1-19 AND MOVING TO DS 3. 11:00 - 12:30 1.50 MOB P PRE PJSM ON MOVING RIG OFF OF WELL 1-19. MOVE OFF WELL WITH NO ISSUES. STAGE RIG TO SIDE OF DRILL SITE. CONDUCT ROUTE RECON WITH WSL,TP,AND DRILLER. ALL GOOD,TEAM JUST FINISHING UP WITH PREP ON 3-33. BRIEF CREW ON MOVE ROUTE,SECURITY ON SITE. 12:30 - 17:30 5.00 MOB P PRE BEGIN RIG MOVE AT 1230 HRS. MOVE RIG FROM DS-01 TO DS-03 17:30 - 00:00 6.50 MOB N RREP PRE IDENTIFY HYDRAULIC LEAK IN RIG DRIVE MOTOR#3 FROM INTERNAL FAILURE. RIG LOCATED AT DS-17 ACCESS ROAD.NOTIFY CTD OPS SUPERINTENDENT AND SPILL RESPONSE TEAM.REPLACE RIG DRIVE MOTOR#3. "TRACTION INCIDENT REPORT REFERENCE #4643678" 2/18/2014 00:00 - 05:00 5.00 MOB N RREP PRE REPLACE RIG DRIVE MOTOR#3. ATTEMPT TO FLUSH HYDRAULIC SUPPLY LINES THROUGH HIGH PRESSURE FILTERS. DIFFICULTY FLUSHING LINES DUE TO LOW TEMPERATURES. 05:00 - 14:30 9.50 MOB N WAIT PRE KEEP HEATERS ON REAR MOVING SYSTEM, CONTINUE TO WARM FRONT MOVING SYSTEM HYDRAULICS WHILE WAITING ON WEATHER. CURRENT TEMP-49°,CANNOT MOVE RIG CONTRACTUALLY UNTIL WARMER THAN-40°. CREW WORKING ON MAINTENANCE CHECKLIST ITEMS,PREPPING EQUIPMENT FOR OPERATIONS 1-CONDUCT PJSM FOR MOVING RIG AS WEATHER BEGAN TO WARM UP SO THAT THE CREW IS READY TO GO ONCE THE TEMP RISES TO ABOVE-40°. 14:30 - 15:00 0.50 MOB N WAIT PRE TEMPERATURE HAS INCREASED TO-39°. SECURITY MOBILIZED,HEATERS MOVED AWAY FROM RIG. PJSM WITH ALL INVOLVED IN MOVE. CONDUCT WALK AROUND,PLACE SITE CONTROL BEHIND RIG TO MONITOR FOR ANY DAMAGE OR LEAKS. 15:00 - 17:45 2.75 MOB P PRE RESUME MOVING RIG TO DS3. -SEND IN UPDATE TO STATE REGARDING REQUEST TO AOGCC FOR BOP TESTING. -WITH RIG MOVING,VERIFY 0 PSI ON IA,OA. SHUT IN IA,OAAND VERIFY MASTER IS SHUT. 17:45 - 19:00 1.25 MOB P PRE SPOT RIG AT WELL. PJSM FOR MOVING OVER WELL. CONDUCT ONE LAST INSPECTION,TEST ESD. MOVE RIG OVER WELL. RIG ACCEPT AT 1900 HRS. Printed 3/3/2014 12:50:53PM North America-ALASKA-BP Page 2 e Operation Summary Report Common Well Name:03-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/17/2014 End Date: X3-0146M-C:(4,018,586.00) L Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 1 Spud Date/Time:7/26/1984 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292114200 Active datum:28.5+27.89 @ 56.39 @56.39usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ Susf) 19:00 - 21:00 2.00 BOPSUR ' P PRE RU OUTSIDE EQUIPMENT.SPOT FLOW BACK TANK AND RU HARDLINE.INSTALL ANNULUS GUARDS AND PRESSURE SENSORS.HOOK UP THE SSV HOSE. CONSULT W/LOADER OPERATOR REGARDING LOADER OPERATIONS IN COLD TEMPERATURES. 21:00 - 21:30 0.50 BOPSUR P PRE OPEN SWAB,SSV,AND MASTER VALVE. VERIFY 0 PSI AT WING VALVE. CLOSE SWAB, SSV,AND MASTER VALVE. RU TO WING VALVE AND LEAK TIGHT TEST PER WELL PLAN.GOOD TEST,BLEED PRESSURE TO 0 PSI,CLOSE THE SSV AND MONITOR VOID FOR PRESSURE WITH THE OA SENSOR WHILE BREAKING CONTAINMENT TO NU THE BOPE. 21:30 - 00:00 2.50 BOPSUR P PRE PJSM.ND TREE CAP FLANGE.NU BOPE. 2/19/2014 00:00 - 02:00 2.00 BOPSUR P PRE NU BOP.STRAIGHTEN TREE.INSTALL DRAINAGE CONTAINMENT PAN,LUBRICATOR AND QTS. UPDATE AOGCC CONTACT AT 01:40 AM REGARDING REQUEST FOR BOP TESTING. 02:00 - 02:30 0.50 BOPSUR P PRE CONDUCT RIG H2S EVACUATION DRILL AND AAR. 02:30 - 05:00 2.50 BOPSUR P PRE 1GREASE MUD CROSS AND BOP.DISABLE KILL LINE CHECK VALVE.SET TEST PLUG. 05:00 - 06:00 1.00 BOPSUR P PRE RU TO PRESSURE TEST BAKER CHOKE. CONDUCT PRESSURE CROSSCHECK PRIOR TO TESTING.PRESSURE TEST WELDS OF !NEW BAKER CHOKE. 07:30 j 1.50 BOPSUR P PRE 06:00 ',CONDUCT BODY PRESSURE TEST OF BOP. GOOD TEST,NOTIFY STATE AOGCC REP THAT TEST WAS GOOD. CONDUCT H2S/RIG EVACUATION DRILL AND AAR. 07:30 - 15:45 8.25 BOPSUR P PRE STATE REP ON LOCATION TO WITNESS TEST. CONDUCT BOP TEST AND ACCUMULATOR DRAWDOWN TEST PER AOGCC,NORDIC AND • BP REGULATIONS AND REQUIREMENTS. FUNCTION RAMS FROM BOTH DRILLER AND CTS CONSOLES. TEST ALL ALARMS. -SIMOPS: -TAKE ON MUD INTO PITS,CHECK CONTINUITY ON BAKER INTEQ TOOLS, ENSURE ALL TOOLS READY TO GO -CLEAR AND CLEAN RIG FLOOR OF TEST EQUIPMENT 15:45 - 16:45 1.00 BOPSUR P PRE STAB ON WITH INJECTOR. PRESSURE TEST HARD IRON AND INNER REEL VALVE,GOOD TEST. 16:45 - 19:45 3.00 RIGU P PRE DISPLACE REEL TO KCL,PUMP SLACK BACK. CAN NOT GET E-LINE TO MOVE WITH RIG FRESH WATER OR WITH WARM KCL. ORDER OUT 120°FRESH WATER TO PUMP. CIRCULATE WHILE WAITING ON WATER. -SIMOPS:VALVE CREW ON LOCATION TO CHECK TREE BOLTS AFTER BOP NU AND INJECTOR ON WELL Printed 3/3/2014 12:50:53PM North America-ALASKA-BP Page 3 dig Operation Summary Report Common Well Name:03-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/17/2014 End Date: X3-0146M-C:(4,018.586.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 1 Spud DateMme:7/26/1984 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292114200 Active datum:28.5+27.89 Op 56.39©56.39usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) - __ (usft) 19:45 - 21:00 1.25 I RIGU P PRE LINE UP FRESH WATER TO PUMP SLACK I I BACK.CLOSE MASTER VALVE AND SSV AND MONITOR THROUGH WING VALVE.PUMP SLACK BACK.MU HIGH PRESSURE HOSE AND PUMP BACK FLUID IN COIL W/AIR. 21:00 00:00 3.00 RIGU P PRE PJSM ON CUTTING COIL. POP OFF WITH 'INJECTOR AT LUBRICATOR CONNECTION.MU 1 COIL CUTTER. CUT 310'OF COIL. REMOVE COIL CUTTER. PREP END OF COIL FOR MAKING UP NEW CONNECTOR. INSTALL CONNECTOR,PULL TEST TO 40K,PRESSURE TEST CONNECTION TO 4000 PSI.MU STINGER AND NOZZLE.PUMP SLACK ' ' FORWARD. 2/20/2014 00:00 - 01:15 1.25 RIGU P PRE HEAD UP WITH BAKER INTEQ TOOLS. TEST E-LINE.MAKE UP UPPER QUICK CONNECT 01:15 02:30 1.25 RIGU P PRE STAB ON WITH INJECTOR.MAKE UP LUBRICATOR BACK TO INJECTOR.PUMP 1.5 COIL VOLUME FORWARD TO MOVE SLACK FORWARD.SPOT 5 BBL METHANOL IN COIL ACROSS ROOF TO PREVENT FREEZE UP. 02:30 - 03:15 0.75 ' BOPSUR P PRE PJSM.RU TO PRESSURE TEST.PRESSURE TEST 7"OTIS LUBRICATOR CONNECTION AND DUAL FLAPPER CHECK VALVES. _ CONFIRM GOOD TEST. 03:15 - 04:15 1.00 BOPSUR P I PRE PJSM.UNSTAB INJECTOR AND SET BACK.LD I I STINGER AND NOZZLE.MOBILIZE 1 WHIPSTOCK TO RIG FLOOR.PULL TEST 4----- --�----- PLUG. _-- 04:15 - 05:15 1.00 BOPSUR P PRE I PJSM FOR OPENING WELL.STAB INJECTOR. PRESSURE TEST QUICK TEST SUB.OPEN WELL TO CLOSED CHOKE.CONFIRM 0 PSI. I FILL WELL THROUGH KILL LINE. 05:15 - 05:45 0.50 BOPSUR P PRE FLOW CHECK FOR 30 MIN-CONFIRM GOOD NO FLOW. •05:45 - 07:30 1.75 STWHIP P • I WEXIT UNSTAB INJECTOR AND STAND BACK.RIG UP TO PICK UP WHIPSTOCK BHA. PJSM ON MAKING UP BHA. MU WHIPSTOCK BHA:45K I WHIPSTOCK PACKER,BOT HYDRAULIC SET TOOL MADE UP TO BAKER INTEQ SMART + TOOLS. STAB ON,PT QUICK TEST SUB. 07:30 - 10:30 3.00 STWHIP P I WEXIT RIH WITH WHIPSTOCK BHA. LOG TIE-IN AT 10,560'WITH-14.5'CORRECTION. 10:30 - 12:00 1.50 STWHIP P I WEXIT PICK UP HOLE TO 10,400'AND BEGIN LOGGING DOWN FOR CCL. LOG DOWN TO ' 11,030'. INTERPRET LOGS,CONFIRM THAT WHIPSTOCK SETTING DEPTH IS CLEAR OF C COLLARS. PULL UP HOLE,PUWAT 36.5K. �j 1-1 SET TOP OF WHIPSTOCK AT 10,935'30" Runs,PRESSURE UP AND OBSERVE SHEAR W AT 1700 PSI. SET DOWN 3K SLACKOFF TO LII CONFIRM SET. 12:00 - 13:00 1.00 • STWHIP P WEXIT DISPLACE WELL WITH WARM KCL FOLLOWED BY NEW 8.6 PPG MUD SYSTEM AT MAX FLOW RATE. 13:00 - 15:00 2.00 11 STWHIP P I WEXIT POH WITH BHA WITH NO ISSUES. FLOW I CHECK AT SURFACE,NO FLOW. PJSM ON I LAYING DOWN BHAAND PICKING NEXT BHA UP. Printed 3/3/2014 12:50:53PM North America-ALASKA-BP Page 4 f223' Operation Summary Report Common Well Name:03-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/17/2014 End Date: X3-0146M-C:(4,018,586.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 1 Spud Date/Time:7/26/1984 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292114200 Active datum:28.5+27.89 el 56.39 @56.39usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 15:15 0.25 STWHIP P WEXIT PULL TO SURFACE. POP OFF,LD WHIPSTOCK RUNNING BHA. BHA IN GOOD SHAPE. PICK UP MILL AND STRAIGHT MOTOR. GAUGE WINDOW SPEED MILL AT 3.80"NO GO,3.81"GO;GAUGE STRING MILL AT 3.79"NO GO. I STWHIP P i 15:15 - 18:45 3 50 WEXIT RIH WITH WINDOW MILLING BHA.. LOG TIE-IN WITH-12'CORRECTION. 18:45 - 19:00 0.25 STWHIP P WEXIT ESTABLISH SCRP'S. SCRP#1:. . 1-25-SPM,1113-PSI,.55-BPM -64-SPM,1523-PSI,1.53-BPM SCRP#2: -22-SPM,1106-PSI,.53-BPM -66-SPM,1567-PSI,1.56-BPM 19:00 - 19:15 0.25 STWHIP P WEXIT TAGGED PINCH POINT AT 10,936'AND ESTABLISHED PRESSURE INCREASE. PAINT FLAG ON PIPE.RIH TO BEGIN MILLING WINDOW. 19:15 - 00:00 4.75 STWHIP P WEXIT COMMENCE TIME MILLING. I•� TOW=10936'CTMD MW IN-8.6-PPG/MW-OUT-8.6-PPG '�f Q'4-33C 19:10-HRS.10936'/MM-IN-2.71-BPM/ W a ixr- MM-OUT-2.71-BPM/CIRC PSI 2520-PSI FREE 19:20-HRS.10936'/MM-IN-2.68-BPM/ MM-OUT-2.69-BPM/CIRC PSI-2567-PSI/ 1 DIFF P 77-PSI/WOB-0.52K-LBS. 20:10 HRS.10936.7/MM-IN-2.71-BPM/ MM-OUT-2.73-BPM/CIRC PSI-2615-PSI/ DIFF P 95-PSI/WOB-1.3K-LBS. 20:30-HRS.10936.9'/MM-IN-2.70-BPM/ MM-OUT-2.72-BPM/CIRC PSI-2615-PSI/ DIFF P 95-PSI/WOO-1.45K-LBS. 21:00-HRS.10937.4'/MM-IN-2.72-BPM/ MM-OUT-2.73-BPM/CIRC PSI-2700-PSI/ -DIFF P 180-PSI/WOB-2.64K-LBS. 21:30-HRS.10937.8'/MM-IN-2.70-BPM/ MM-OUT-2.73-BPM/CIRC PSI-2644-PSI/ DIFF P 124-PSI/WOB-2.90K=LBS. 22:00-HRS.10938.0'/MM-IN-2.77-BPM/ MM-OUT-2.80-BPM/CIRC PSI-2695-PSI/ DIFF P 175-PSI/WOB-2.80K=LBS. 22:30-HRS.10938.4'/MM-IN-2.65-BPM/ MM-OUT-2.65-BPM/CIRC PSI-2717-PSI/ DIFF P 197-PSI/WOB-3.75K=LBS. 23:00-HRS.10938.6/MM-IN-2.72-BPM/ •MM-OUT-2.72-BPM/CIRC PSI-2695-PSI/ DIFF P 175-PSI/WOB-3.23K=LBS. 23:30-HRS.10939.1/MM-IN-2.64-BPM/ MM-OUT-2.65-BPM/CIRC PSI-2524-PSI/ DIFF P 4-PSI/WOB-3.03K=LBS. 23:59-HRS.10939.5/MM-IN-2.68-BPM/ MM-OUT-2.67-BPM/CIRC PSI-2615-PSI/ DIFF P 95-PSI/WOB-2.73K=LBS. Printed 3/3/2014 12:50:53PM North America-ALASKA-BP Page 5 a -' Operation Summary Report Common Wet Name:03-33 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/17/2014 End Date: X3-0146M-C:(4,018.586.00) Project:Prudhoe Bay 'Site:PB DS 03 Rig Name/No.:NORDIC 1 Spud Daterfime:7/26/1984 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292114200 Active datum:28.5+27.89©56.39©56.39usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usf) 2/21/2014 00:00 - 06:00 6.00 STWHIP P WEXIT 01:00-HRS.10940.92/MM-IN-2.61-BPM/ MM-OUT-2.58-BPM/CIRC PSI-2534-PSI/ DIFF P 14-PSI/WOB-1.9 KLBS. 01:30-HRS.10942'/MM-IN-2.68-BPM/ MM-OUT-2.68-BPM/CIRC PSI-2604-PSI/ DIFF P 84-PSI/WOB-2.58 KLBS. 02:00-HRS.10943'/MM-IN-2.77-BPM/ MM-OUT-2.78-BPM/CIRC PSI-2758-PSI/ DIFF P 238-PSI/WOB-3.15 KLBS. 03:00-HRS.10943.9'/MM-IN-2.65-BPM/ MM-OUT-2.68-BPM/CIRC PSI-2633-PSI/ DIFF P 113-PSI/WOB-1.25 KLBS. 04:00-HRS.10944.91/MM-IN-2.64-BPM/ MM-OUT-2.65-BPM/CIRC PSI-2666-PSI/ DIFF P 146-PSI/WOB-1.76 KLBS. 05:00-HRS.10945.9'/MM-IN-2.69-BPM/ MM-OUT-2.67-BPM/CIRC PSI-2703-PSI/ DIFF P 183-PSI/WOB-2.07 KLBS. 06:00 - 09:15 3.25 STWHIP P WEXIT MILLING OPERATIONS CONTINUING VERY !SMOOTHLY. STRING REAMER BEGINNING TO WORK THROUGH WINDOW AT 10,947. 2770 PSI AT 2.75 BPM,WOB 1.25-1.6K. -AS STRING REAMER CLEARED WINDOW, CONTINUE TO MILL INTO OPEN FORMATION. INCREASED WOE TO RANGE OF 2.25-3.25K, 3035-3160 PSI AT 2.8-2.85 BPM. MW IN AND OUT 8.55 PPG -MILL 15'OF NEW FORMATION,PUMP UP SAMPLES FOR GEO. PUMP HI-VIS SWEEP OFF BOTTOM TO CLEAN UP ANY METAL DEBRIS. CIRCULATE UP,PICK UP OFF BOTTOM CLEAN. 09:15 - 11:00 1.75 STWHIP P WEXIT I MAKE FIRST REAM PASS THROUGH WINDOW AT 2.65 BPM,2455 PSI. TWO MINOR DIFFERENTIAL MOTOR WORK SPIKES AS REAMER CAME THROUGH BOTTOM OF WINDOW. CONTINUE UP UNTIL ASSEMBLY FULLY ABOVE WHIPSTOCK. -MAKE REAM PASS DOWN THROUGH !WINDOW AT 2.65 BPM,2430-2470 PSI. VERY I MINOR MOTOR WORK THROUGH WINDOW. I PICK BACK UP TO REAM AT 2.7 BPM,2500 I PSI,WITH A MUCH CLEANER PASS THROUGH,NO NOTICEABLE MOTOR WORK. -MAKE SECOND REAM PASS BACK DOWN 'THROUGH AT 2.65-2.75 BPM,2440-2560 PSI. MAKE PASS UP WITH NO ISSUES. PULL ABOVE WHIPSTOCK,DOWN ON PUMPS AND CONDUCT DRY DRIFT THROUGH ALL THE WAY TO CURRENT TD OF 10,961'WITH NO ISSUES. PICK BACK UP THROUGH WINDOW WITHOUT PUMPS,ALL GOOD. 11:00 - 13.15 2.25 STWHIP P WEXIT FLOW CHECK OFF BOTTOM,ALL GOOD. OPEN EDC,POH WITH MILLING BHA AT 3.5 BPM,2725 PSI. -MW IN 8.58 PPG,MW OUT 8.56 PPG -POH TO 200'. FLOW CHECK,ALL GOOD. PJSM ON LAYING DOWN BHA. 13.15 - 14:15 1.00 STWHIP P WEXIT PULL TO SURFACE,POP OFF. LD BHA. MILLS GAUGE AT 3.80"GO,3.79"NO-GO. CHECK TREE BOLTS,ALL GOOD. HOLE FULL,NO LOSSES WHILE AT SURFACE. Printed 3/3/2014 12:50:53PM 4 1. fY NOTES: WELL 41O'0 3-3 3 B H2S READINGS AVERAGE 11225Eppm OWHEN ON MI* �- D= MaEV ACTUATOR= BAKER C *** WELL REQUIRES A SSSV WHEN ON Ml MIAL KB.ELE 62' I BF ELEV= 27.89' ***PREVIOUS WELLBORE'SNOT SHOWN*** KOP 2850' Max Angle= 93°@ 11999' 'CONDUCTOR ? Datum MD= ---- 10762' — ' L 2206' H4-1/2"HES X MP,D=3.813" Etum TVD=-- 8800'SS 13-3/8"CSG,72#,L-80,D=12-347" H I 2506' TOP OF 7"SCAB LNR — 3018' 3018' H9-5/8"X 7"BKR ZXP LTP,D=6290" v 3036' H9-5/8"X 7"BKR FLEX-LOCK HGR,ID=6-310" Minimum ID = 3.800" @ 10383' 0 MILLED 4-1/2" XN NIPPLE •i 9444' 19-5/8"X 7"BKR C-2 ZXP LTP& $1 TIEBACK SEAL ASSY,D=6.151" 7"SCAB LNR,26#,L-80,BTGM, ---I 9453' al 9461' —I 9-5/8"X 7"BKR HMC HGR,ID=6.280" -0383 bpf,D=6276" 9-5/8"WHIPSTOCK(03/12/05) -H 9594' MILLOUT WINDOW(03-33B)9594'-9622' 9-5/8"CSG,47#, L-80,D=8.681" —I ^9594 I- 10317' H4-1/2"HES X NP,D=3.813" 2 10338' H 7"X 4-1/2"BKR S-3 PREM PKR,D=3.875" 10362' H4-1/2"HES X NP,D=3.813" 10383-14-1/2"HES XN NP MILLED TO 3.800"(02/03/14) 4-1/2"TBG,12.6#,L-80 TC-11, —I 10395' 0152 bpf,D=3-958" . 10391' —17"X 5"BKR ZXP LTP w/TH3K,D=4.450" 7"LNR,26#,L-80,BTC-M,.0383 bpf,ID=6-276" — 10572' \ F10395' �4-1/2"VVLEG,D=3-958"MD 10409' —7"X 5"BKR C HY DRO HGR, =4.430" PERFORATION SUMMARY \ 10417' —15"X 4-112"XO,ID=3.980" REF LOG:SSEWWDGR/ROP ON 03/20/05 � 10935' H4-1/2"VU-PSTOCK(02/20/14) ANGLE AT TOP PERF:89°@ 11100' up 11070' H4-1/2"BKR CIBP(02/04/14) Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 11444' —I4-112"VVFD PKR (09/17/12) 2-7/8" 6 11100-11200 C 09/20/12III' 2-7/8" 6 11652-11677 C 06/27/11 11890' -I4-1/2"I-ES EZ DRILL(05/26/10) 2-7/8" 6 11700-11750 C 05/28/10 2-7/8" 6 11706-11731 C 06/27/11 2-7/8" 6 11766-11791 C 06/26/11 ' 12300' CTM —{4-1/2"WFD CEP(11/12/08) 2-7/8" 6 12100-12150 C 11/13/08 12690'CTM —14-1/2"WFD CBP(03/03/07) 2-7/8" 6 12480-12530 C 03/03/07 2-7/8" 6 12880-12949 C 04/03/05 al 2-7/8" 6 12950-12976 C 04/03/05 ' 4-1/2"LNR,12.6#,L-80 IBT-M, —I 13072' PBTD —{ 12987' .0152 bpf,D=3.958" KIN DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/01/86 IMTIAL COMPLETION WELL: 03-33B 04/30/97 SIDETRACK(03-33A) PETRMTNo: 2050180 03/23105 142ES SIDETRACK(03-33B) API No: 50-029-21142-02 05/30/10 MV/PJC EZ PLUG/ADPERFS (05/26-28/10) SEC 11,T1ON,R15E,214'FSL&822'FWL 02/06/14 JDMJMD MILLED XN NP/SET CBP(02/03-04/14) BP Exploration(Alaska) ter, • • w w��\ I ■9 THE STATE Alaska Oil and Gas ALASKA Conservation C+mmission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader 02,05:—0 t 46 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-33B Sundry Number: 313-584 �pN�E+D NFL L Dear Mr. McMullen: Cj Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cath P.y Foerster Chair, Commissioner DATED this P day of November, 2013. Encl. STATE OF ALASKA • RECEIVED ' ALASIPOIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL a 1 t5� 20 AAC 25.280 AOGC 1. Type of Request: ❑Abandon ®Plug for Redrill ' ❑Perforate New Pool ❑ Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate ❑Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ❑Alter Casing ❑Other 2. Operator Nam€ 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 205-018 • 3. Address: ❑Development ®Service • 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-21142-02-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 03-33B Will planned perforations require a Spacing Exception? ❑Yes—MT—lo 9. Property Designatior 10. Field/Pool(s): ADL 028327 . Prudhoe Bay Field/Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth ND (ft): Plugs(measured): Junk(measured): 13072' ' 8917' • 12987' 8917' 11444,11890',12300',12690' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' _ 110' 1490 470 Surface 2506' 13-3/8" 2506' 2506' 4930 2670 Intermediate 9594' 9-5/8" 9594' 8004' 6870 4760 Production Liner 7554' 7" 3018'- 10572' 3016'-8722' 7240 5410 Liner 2681' 4-1/2" 10391'- 13072' 8589'-8917' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11100'- 12976' 8949'-8917' 4-1/2", 12.6# L-80 10395' Packers and SSSV Type: 7"x 4-1/2"Baker S-3 Packer Packers and SSSV 10338'/8550' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ❑Development ®Service 14. Estimated Date for j 15. Well Status after proposed work: Commencing Operation: November 25,2013 l ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ®Suspended . 17. I hereby certify that the f. oi.• s true an. orrect to the best of my knowledge. Contact: David Johnston,564-5985 Printed Name: JOAT' Y'y<4011■0' Title: Engineering Team Leader , Emai David.Johnston2 @bp.com i Signature: /� / Phone: 564-4711 Date: C( J3 Commission Use Only / Conditions o approval: Notify Commission so that a representative may witness Sundry Number: rj �/ 313- ce Lk ❑Plug Integrity (�BOP Test ❑Mechanical Integrity Test ❑Location Clearance RBDMS NOV 15 Other: 35-60 rsci 1Q/ 7-T3-i A Al-ke K, P14.-3 // - ..-. dite"4"..Q P- za ' z 7/2' a') Spacing Exception Required? ❑Yes dNo Subsequent Form Required: /O—q 7 i APPROVED BY p�A(/^ !t-(5 /3 Approved By: OA �//'" " "'7 COMMISSIONER THE COMMISSION Date: \ Form 10-403 Revised 1/2012 Appr�v cRpli6oll filAct/2 months rom the date of approval Submit In Duplicate Ai, • • To: Alaska Oil & Gas Conservation Commission From: David Johnston by CTD Engineer Date: Oct. 30, 2013 Re: 03-33B Sundry Approval Sundry approval is requested to plug the 03-33B perforations as part of the drilling and completion of proposed 03-33Ci MIST Injector, a coiled tubing sidetrack. y' History and current status: 03-33 was completed in 7/1994. 03-33A was completed 05/1997. 03-33B was completed 3/2005. Well was swapped to produced water injection in 2009. This well is currently in 4th set of MIST perfs and injecting water. Proposed plan: Sidetrack 03-33B to the 03-33Ci location using Nordic 1 Coiled Tubing Drilling rig on or around February 1, 2014. The 03-33Ci sidetrack will exit the existing 4-1/2" liner and kick off in the Ivishak Zone 2, and target a Zone 2 lateral, to target previously un- swept oil within the 03-12i pattern. This sidetrack will be completed with a 3-1/2" x 2-7/8" 13Cr-80 liner which will be cemented and selectively perforated. This Sundry covers plugging the existing 03-33B perforations via the primary cement iob to top of the liner or a liner top packer if the liner lap test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. T cp4wr. r4,) (~el `Gf grra-o4 , jecre®' ; 411 0 rte (14" "t jyi5st ,'„ ;(&,,0 M fel.110 QV/ AO l'r1i ,f X ufr/f )) :7 i tf G vrrCn t to t'r''0 /f / • i Pre-Rig Work(scheduled to begin Nov 25th, 2013) 1. C Dummy WS drift to 11,200' MD (KB LTP). 2. C Set a 4-1/2" CIBP at 11,050' MD and circulate out well. 3. F MIT-T 2,500 psi - Ckit..c. - /3D r„a... 4. C Mill X nipple at 10383' to 3.80" 5. C FP well to 2,500' with diesel 6. V PT MV, SV, WV. 7. 0 Remove wellhouse and level pad. ey k Rig Work(scheduled to begin Jan 15th, 2014) 1. MIRU and test BOPE 250 psi low and 3,500 psi high. (MASP 2,470 psi) _f_. 2. Set 4-1/2" KB packer whipstock TOWS at 10,950' ELMD - � 2. Mill 3.80"window and 0 1 of r ato h le. 3. Drill build: 4.125" OH, 593" (20 deg DLS planned). erN 4. Drill lateral: 4.125" OH, 2657' (12 deg DLS planned). 5. Run 3-1/2" X 2-7/8" 13Cr-80 liner leaving TOL at 10,890' MD. 6. Pump primary cement job: 40 bbls, 15.8 ppg, TOC at 9,4601.* 7. Perform liner cleanout and MCNL/GR/CCL log. 8. Perform liner lap test to 2,400 psi 9. Perforate liner based on log interpretation (-1000'). 10. Freeze protect well to 2,500' MD. 11. Set TWC; RDMO. *Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. Re-install wellhouse, flowline and pull BPV. 2. Set liner top packer with slickline* if liner lap test fails. *Approved alternate plug placement if liner lap test fails per 20 AAC 25.112(i) David E. Johnston CTD Engineer 564-5985 CC: Well File Joe Lastufka TREE= taw • S NOTES: H2S READINGS AVERAGE 125 . WELLHEAD= McEVOY Pp RN ON MI.WELL REQUIRES A SSSV KB.G TOR= RXE 640' 4 3-33B WHEN ON MI. WELL ANGLE>70°@ 10909°. BF. 56:g ***PARENT WELLBORE NOT SHOWN"" KOP= 9594' Max Angle= 93°@ 11999' L J I Datum MD= 10767 2206' —{4112"FESXN� D=3.813" Datum TV D= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" I 2506' 3018' —I9-5/8"X r BKR ZXP LTP,D=6.290' I I TOP OF r SCAB LNR —I 3018' I 3036' H9-5/i7 X 7"BKR FLEX-LOCK LNR hiGR,D=6.310° I Minimum ID =3.725" @ 10383' ;� 4-1/2"XN NIPPLE ►' ►� 9444' I-9-5/8"X 7"BKR C-2 ZXP LTP& k it TEBACK SEAL ASSY,D=6.151" 7"SCAB LNR 26#,L-80,BTC M H 9453' I 9461' 1-19-5/8"X 7"BKR I-PAC HGR,0=6.280" I .0383 bpf,D=6.276" IWHPSTOCK(03/12/05) 9594 9-5/8°CSG,47#, L-80,D=8,681" --I ^-9622 (��LOUT WINDOW(03 33C)9594'-9622' 10317' H4-1/2"HES X NP,D=3.813"I 7"X 4-1/2'BKR S-3 MEM PKR,D=3,875" ,� 10338' H I i 10362' H4-1/2"HES X N►?D=3.813"I I 10383' H4-1/2"HES xN NP,D=3.725" I L10391* Hr X 5"BKR ZXP LTP w/TEBK,D=4.450"I 4-1/2"TBG,12.6#,L-80 TC-11,.0152 bpf,D=3.958" 10395' 10395' 4-1/2"WLEG,D=3.958" I7"LNR,26#,L-80,BTC-M,.0383 bpf,D=6.276" I-j 10572' IL I 10409' I—7"X 5"BKR I#NC HYDRO PERFORATION SUMMARY LIIIR HGR,0=4.430° REF LOG:SSEWR/DGR/ROP ON 03/20/05 ` ANGLE AT TOP PERF: 89°G. 11100' 10417' —15"X 4-1/2"XO,D=3.980 I Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE 2-7/8" 6 11100-11200 0 09/20/12 4-1/2"WFD PKR I 11444' 2-7/8' 6 11652-11677 C 06/27/11 11890 I-I41/2°FES EZ DR LL(05/26110) I 2-7/8" 6 11700-11750 C 05/28/10 (09#17/12) 0. 2-7/8" 6 11706-11731 C 06/27/11 12300'CTM —14-1/2"WFDCBP(11/12/08) 2-7/8" 6 11766-11791 C 06/26/11 ' 12690'CTM H4-1/2"WFD COP(03/03/07) I 2-7/8' 6 12100-12150 C 11/13/08 /` 2-7/8" 6 12480-12530 C 03/03/07 2-7/8" 6 12880-12949 C 04/03/05 ` 2-7/8" 6 12950-12976 C 04/03/05 :..., Trri --I _1298T ,.- 14-112"LNR,12.6#,L-80,BT-M..0152 bpf,D=3.958" 13072' DATE REV BY COMNFNTS DATE REV BY COMMENTS PRUDHOE BAY UNT 03/01/86 ORIGINAL COMPLETION 06/28/11 PBS/PJC ADPERFS(06/26-27/11j WELL: 03-338 04/30/97 SIDETRACK(03-33A) 06/29/11 CJW PJC PERF CORRECTION PERMIT No: 205-018 03/23/05 NM SIDETRACK(03-33B) 01/10/12 TNIAUM.)ADDED I-2S SAFETY NOTE AFT No: 50-029-21142-02 05/30/10 MV/PJC EZ PLUG/ADPERFS (05/26-28/" 09/24/12 RRW/JkD SET CBP&ADFERF(09/18-20/12) SEC 11,T10N,R35E,2658'FE.&1515.13'FM 02/11/11 h/B/JID ADDED SSSV SAFETY NOTE 02/11/11 RCT/PJC I-ES NP D CORRECTION BP Exploration(Alaska) ELLFEAD= McEVOY "—ILIATOR= AXE LSON 063 3 C Proposed WHEN ON lig I.ON MI LELL REQ 70"@ 0909'V F. a.EV= 27.89' ***PARENT WELLBORE NOT SHOWN*** F.REV= 27.89' - DP= 9594' L ax Angle= 93°@ 11999' 3tum MD= 10762' 2206' —14-1/2"HES X NP,D=3.813" atum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12347" 2506' 3018' —I9-5/8"X 7"BKR ZXP LTP,ID=6.290" TOP OF 7"SCAB LNR 3018' I 3036' H9-5/8"X 7"BKR FLEX-LOCK LNR HGR,D=6.310 F Minimum ID =3.725" @ 10383' • ■ 4-1/2" XN NIPPLE 4 • 9444' I-9-5/8"X 7"BKR C-2 ZXP LIP& ij TLBACK SEAL ASSY,D=6.151" 15 7"SCAB LNR,26#,L-80,BTG H M, 9453' 12 I _ • I 9461 —19-5/8"X 7"BKR HMC HGR,ID=6.280" .0383 bpf,13=6.276" WHPSTOCK(03/12/05) — 9594' 9-5/8"CSG,47#, L-80,D=8.681" —I —9622 MLLOUT WINDOW(03-33C)9594'-9622' I 10317' IH4-1/2"HES X NP,D=3.813" till" 10338' —17"X 4-1/2"BKR S-3 PREM PKR,D=3.875" i 10362" —14-1/2"F-E5 X NP,D=3.813" I 10383' —14-1/2"HES XN NP,D=3.725" 10391' -17"X 5"BKR ZXP LTP w/TEE BK,D=4.45 10395' —I4-1/2"WLEG,D=3.958" 4-1/2"TBG, 12.6#,L-80 TG11,.0152 bpf,ID=3.958" — I 10395' 10409' —7"X 5"BKR HMC HYDRO 7"LNR,26#,L-80,BTC-M,.0383 bpf,D=6.276" -I 10572' `0n �� LNR HGR,D=4.430" r''� �MD 10417' —15"X 4-1/2"XO,D=3.980" I PERFORATION SUMMARY \TOL @ 10,890'MD - REF LOG:SSEWR/DGR/ROP ON 03/20/05 ANGLE AT TOP FERF: 89°@ 11100' TD @ 14,200'MD Ilk Note:Refer to Production DB for historical perf data 4-1/2"packer whipstock @ 10,950'MD SEE SPF I'ITI62VAL Opn/� DATE 75 Degree inclination 7/8" 6 11100 11200 O 09/20/12 CIBP 11,050'MD ----------.. '-7/8" 6 11652-11677 C 06/27/11 �� 2-7/8 13CR -7/8" 6 11700-11750 C 05/28/10 '-7/8" 6 11706-11731 C 06/27/11 OA '-7/8" 6 11766-11791 C 06/26/11 4-1/2"WFD PKR H 11444' j e 11890' H4-1/2"FES a DRILL(05/26/1 '-7/8" 6 12100-12150 C 11/13/08 (09/17/12) 12300' CTM —�4-1/2"WFD CIBP(11/12/08 '-7/8" 6 12480-12530 C 03/03/07 '-7/8" 6 12880-12949 C 04/03/05 12690' CTM H4-1/2"WFD CEP(03/03/0 '-7/8" 6 12950-12976 C 04/03/05 PBTD 12987' ` 4-1/2"LNR, 12.6#,L-80,ET-M. .0152 bpf,D=3.958" 13072' �1„„i�• DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY MIT 03/01/86 ORIGINAL COMPLETION 06/28/11 FBS/PJC ADPRRFS(06/26-27/11) WELL: 03-33B 04130/97 SIDETRACK(03-33A) 06/29/11 UN PJC PERF CORRECTION PERM T No: 205-018 03123105 N2E S SIDETRACK(03-33B) 01/10/12 TMWJMD ADDED H2S SAFETY NOTE AR No: 50-029-21142-02 05/30/10 MV/PJC EZ PLUG/ADPE2FS (05/26-28/1 09/24/12 RRW/JMD SET CEP&ADPERF(09/18-20/12) SEC 11,T10N,R35E 2658'FED&1515.13'FN- 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE 02/11/11 RCT/PJC FEES MP D CORRECTION BP Exploration(Alaska) NORDIC-CALISTA RIG 1 CHOKE / REEL/CIRCULATION MANIFOLD DIAGRAM • V12 V14 7-1/18"5000 psi BOP's ID=7.06" V15 V11 .... It 1/18"5000 psi,Rx-413 Transducers 0 11I n.ORB : V2 I V, V 16 —#W _'�'`.qly� GASSE' ,: Note.typical BOP arrangement for 23/5" coiled tubing drilling ;3,_ it 3 I 7 1/18"5080 ai,R%�8 111 V17 HCR �� IC �" 4' 46,IK OK iiii To Poor Boy Gas Buster V18 V19 I 21/18"5000 psi,Rx-24 3.00"6000 psi NCR /1■5', 111.1111111111111111.1 1 ■ n XI ®• .r 2-1/18"5000 Pai CHECK Y VALVE 1 Manual Choke '= IIIIIIIIIIIIIIEEMMIIIA g•••••• ••-111111 JAC& F� 1 71/18 Cameron FOV Gate I -..g.:..; Valve x 5000 pm rir 1`1 iii∎ - - MEOH/Diesel . �'— kiiii FP Line CoFlex Hose 114 Turn Halco : ,■:.' 10W00 To Production Tree or Cross Over • A T - e transducers CoFlex Hose CV11 „ 0 CV12 To Coiled Tubing I Bleed OR Inner Reel Valve -- - L. - AI - {I -- CV13 Cement Line In E Ground Level Tie-in CV10 a.: -I CV3 CV2 T Stand Pipe ee pts ,1/1 - _ :-- - _ - ��/ Manual Choke _ as1 -Iij I CV77 �� CV8 Tiger Tank •• Mud Pump2 7 — ® In From Baker MP 1 3 MP 2 O • Choke _ • -- . -• CV14 to Pits Rig Floor t Mud Pump#1 l CV16 Reverse Ci Cir CT while••H NM IIII 0 ilia • • To Manifold CV15 1-Jun-2010 4 pe„erse tire-Malice line/CT whim(1n11 CoFlex Hose i 1 1 % STATE OF ALASKA DC I 1 1 2012 . AIL OIL AND GAS CONSERVATION COMMON I REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon Li Repair Well LJ Plug Perforations •j Perforate Lf Other U Performed: Alter Casing ❑ Pull Tubing❑ Stimulate - Frac ❑ Waiver ❑ Time Extension0 Change Approved Program [] Operat. Shutdown0 Stimulate - Other SI A4 Re -enter Suspended Well❑ 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ - 205 -018 -0 3. Address: P.O. Box 196612 StratigraphiC Service SI 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21142 -02 -00 7. Property Designation (Lease Number): _ 8. Well Name and Number: ADL0028327 PBU 03 -33B 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13072 feet Plugs measured See Attachment feet true vertical 8916.5 feet Junk measured None feet Effective Depth measured 11890 feet Packer measured See Attachment feet true vertical 8933.05 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 77 20" 91.5# H-40 33 -110 33 - 110 1490 470 Surface 2474 13 -3/8" 72# L -80 32 - 2506 32 - 2505.88 4930 2670 Intermediate None None None None None None Production 9591 9 -5/8" 47# L -80 31 - 9622 31 - 8023.76 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth See Attachment feet SCANNED JAN 28 2013 True Vertical depth See Attachment feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 -10395 27 - 8591.72 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer 4 -1/2" MCX I -SSV 2206 2205.9 SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): 11100' - 11125', 11150' - 11200', 11652' - 11677', 11700' - 11750', 11766' - 11791' Treatment descriptions including volumes used and final pressure: 72 Bbls 12% HCL, 72 Bbls 9:1 Mud Acid 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 10528 0 1413 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run ExploratorE Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: r , Oil ❑ Gas 0 WDSPIJJ GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUC❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Email Garry.Catront BP.Com Printed Name Garry Catron Title PDC PE Signature k I Q� Ci Phone 564 -4424 Date 10/10/2012 Re -ms ReLms OCT 15 2012 A=,'°`- i 's -iL 1c7./ Form 10-404 Revised 10/2012 Submit Original Only • • 03 -33B 205 -018 -0 Plugs Attachement SW Name Date MD Description 03 -33B 5/28/2010 11890 4 -1/2" HES EZ DRILL PLUG 03 -33B 11/13/2008 12300 4 -1/2" WFD CIBP 03 -33B 3/5/2007 12690 4 -1/2" WFD CIBP • • Packers and SSV's Attachment ADL0028327 SW Name Type MD TVD Depscription 03 -33B SSSV 2206 2149.51 4 -1/2" MCX I -SSV 03 -33B PACKER 3018 2959.21 7" Baker ZXP Top Packer 03 -33B PACKER 9443 7838.44 7" Baker ZXP Top Packer 03 -33B PACKER 10338 8493.89 4 -1/2" Baker S -3 Perm Packer 03 -33B PACKER 10391 8532.41 5" Baker ZXP Top Packer Casing / Tubing Attachment ADL0028327 Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 20" 91.5# H-40 33 - 110 33 - 110 1490 470 LINER 6425 7" 26# L -80 3018 - 9443 3015.6 - 7894.83 7240 5410 LINER 1129 7" 26# L -80 9443 - 10572 7894.83 - 8722.32 7240 5410 LINER 2681 4 -1/2" 12.6# L -80 10391 - 13072 8588.8 - 8916.5 8430 7500 PRODUCTION 9591 9 -5/8" 47# L -80 31 - 9622 31 - 8023.76 6870 4760 SURFACE 2474 13 -3/8" 72# L -80 32 - 2506 32 - 2505.88 4930 2670 TUBING 10368 4 -1/2" 12.6# L -80 27 - 10395 27 - 8591.72 8430 7500 . • Perforation Attachment ADL0028327 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base X03 -33B 9/20/2012 APF 11100 11125 8948.67 8948.84 03 -33B 9/19/2012 APF 11150 11175 8948.48 8947.73 03 -33B 9/19/2012 APF 11175 11200 8947.73 8947.1 03 -33B 6/27/2011 APF 11652 11677 8940.17 8939.79 03 -33B 6/27/2011 APF 11700 11706 8939.36 8939.24 03 -33B 6/27/2011 APF 11706 11725 8939.24 8938.81 03 -33B 6/27/2011 APF 11725 11731 8938.81 8938.67 • 03 -33B 6/27/2011 APF 11731 11750 8938.67 8938.15 03 -33B 6/26/2011 APF 11766 11791 8937.66 8936.78 03 -33B 5/27/2010 BPS 12100 12110 8925.08 8924.88 03 -33B 5/27/2010 BPS 12110 12130 8924.88 8924.5 03 -33B 5/27/2010 BPS 12130 12150 8924.5 8924.13 03 -33B 5/27/2010 BPS 12480 12505 8915.79 8915.56 03 -33B 5/27/2010 BPS 12505 12530 8915.56 8915.55 03 -33B 5/27/2010 BPS 12880 12923 8916.47 8916.46 03 -33B 5/27/2010 BPS 12923 12930 8916.46 8916.46 03 -33B 5/27/2010 BPS 12930 12949 8916.46 8916.48 03 -33B 5/27/2010 BPS 12950 12976 8916.48 8916.5 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED • FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF 1 Daily Report of Well Operations ADL0028327 ACTIVITYDATE 1 SUMMARY •= 1 1 ; e s - • emp= o c moo -• -gone rea men pre- a. • pe s Y , 'en barriers, Rig up to tree cap. Pumped into tbg a 5 bbl meth spear, 238 bbls SBG mix, 5 bbls meth 9/11/2012 flush. start 3 hr. soak * * *wsr continued to 09- 12 -12 * ** WSR continued from 9/11/12 T /I /0= 1200/800/420 Temp =hot Schmoo -b -gone treatment (pre -CT add perfs) Pumped 227 bbls 140* 1%kcl down tbg to flush SBG mix. Capped well with 5 bbls 9/12/2012 meth. Final WHP's 800/0/20 SV,WV= closed SSV,MV,IA,OA =open DSO to POI after 3 hr. soak CTU 8, 1.75" coil. Job Scope: Tie -in log, Set CIBP, Add perf. • Rig up CTU. PJSM. PT barriers. PJSM. N/U BOPE. M/U MHA and PT. PJSM. M/U PDS memory logging tools. PT Lube. Bullhead 230 bbl diesel with 776. RIH with memory logging BHA. 9/17/2012 ** *Job in Progress * ** Continued from WSR of 09/17/12. CTU 8, 1.75" coil, Job Scope: Tie -in, set CIBP. Add perf. Continue RIH with PDS memory logging BHA. RIH clean to 11502'. Log up to 11400' and flag coil. Log up to 10200'. POH. Close swab and SSV. PJSM. L/0 BHA. PDA memory logging tools stopped after 13 min. No Data. Change out packoffs. RIH w/ BHA; 2.375" ctc, dfcv, disco, blank sub, 2.87" carrier w/ GR and CCL inside, 1.99 crossover, 3.7" nozzle. (oal= 12.92'). * *Held well control drill ** Stop at 11500' log up 40 fpm, flag pipe © 11400' and log 40 fpm to 10200'. Pooh. Good data. MU and RIH w/ BHA; 2.375" ctc, dfcv, disco, blank sub,2.865" crossover,3.62" setting tool, 3.56" setting adapter, 3.562" CIBP (oal= 11.34') . Set @ target depth of 11444. Start Pooh.. 9/18/2012 * *job continued on WSR 09- 19 -12 ** Continued from WSR of 09/17/12. CTU 8, 1.75" coil, Job Scope: Tie -in, set CIBP. Add perf. Continue RIH with PDS memory logging BHA. RIH clean to 11502'. Log up to 11400' and flag coil. Log up to 10200'. POH. Close swab and SSV. PJSM. L/0 BHA. PDA memory logging tools • stopped after 13 min. No Data. Change out packoffs. RIH w/ BHA; 2.375" ctc, dfcv, disco, blank sub, 2.87" carrier w/ GR and CCL inside, 1.99 crossover, 3.7" nozzle. (oal= 12.92'). * *Held well control drill ** Stop at 11500' log up 40 fpm, flag pipe @ 11400' and log 40 fpm to 10200'. Pooh. Good data. MU and RIH w/ BHA; 2.375" ctc, dfcv, disco, blank sub,2.865" crossover,3.62" setting tool, 3.56" setting adapter, 3.562" CIBP (oal= 11.34') . Set CIBP @ target depth of 11444. Start 9/18/2012 Pooh.. * *job continued on WSR 09- 19 -12 ** Daily Report of Well Operations ADL0028327 Continued from WSR of 09/17/12. CTU 8, 1.75" coil, Job Scope: Tie -in, set CIBP. Add perf. Continue RIH with PDS memory logging BHA. RIH clean to 11502'. Log up to 11400' and flag coil. Log up to 10200'. POH. Close swab and SSV. PJSM. L/O BHA. PDA memory logging tools stopped after 13 min. No Data. Will re -run tie -in and drift. Change out packoffs. M/U WFD MHA. 9/18/2012 ***Job in Progress * ** Continued from WSR of 09/19/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. • POH with CIBP running BHA. Close swab and SSV. PJSM. L/O BHA. PJSM. M/U 2.88" SWS perf gun BHA. PT Lube. RIH with perf gun BHA 1. Tag CIBP. Correct depth. Perforate 11175 - 11200'. SIWHP increased from 0 to 180 psi after firing the gun. Diesel in tubing. POH. Close swab and SSV. PJSM. L/O BHA, all shots fired. Cut coil, change packoffs, check chains. M/U perf BHA 2. PT lube. RIH with 25' perf guns. Correct depth at CIBP. Perforate 11150 - 11175'. POH with fired guns. LD spent guns, ball recovered, MU #3 25' gun assembly. PT & RIH. 9/19/2012 « <IN PROGRESS Cont'd On WSR 9- 20 -12 »> Continued from WSR of 09/19/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. POH with CIBP running BHA. Close swab and SSV. PJSM. L/O BHA. PJSM. M/U 2.88" SWS perf gun BHA. PT Lube. RIH with perf gun BHA 1. Tag CIBP. Correct depth. Perforate 11175 - 11200'. SIWHP increased from 0 to 180 psi after firing the gun. Diesel in tubing. POH. Close swab and SSV. PJSM. L/O BHA, all shots fired. Cut coil, change packoffs, check chains. M/U perf BHA 2. PT lube. RIH with 25' perf guns. Correct depth at CIBP. Perforate 11150 - 11175'. POH 9/19/2012 with fired guns. ** *Job in Progress * ** Continued from WSR of 09/19/12. • CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. POH with CIBP running BHA. Close swab and SSV. PJSM. L/O BHA. PJSM. M/U 2.88" SWS perf gun BHA. PT Lube. RIH with perf gun BHA 1. Tag CIBP. Correct depth. Perforate 11175 - 11200'. SIWHP increased from 0 to 180 psi after firing the gun. Diesel in tubing. POH. Close swab and SSV. PJSM. L/O BHA, all shots fired. Cut coil, change packoffs, check chains. M/U perf BHA 2. PT lube. RIH with 25' perf guns. Correct depth at CIBP. Perforate 11150 - 11175'. POH with fired guns. LD spent guns, ball recovered, MU #3 25' gun assembly. PT & RIH. 9/19/2012 « <IN PROGRESS Cont'd On WSR 9- 20 -12 »> Daily Report of Well Operations ADL0028327 f-" Continued from WSR of 09/19/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. Cont RIH w/ #3 25' gun assembly. Shoot 3rd interval from 11125' to 11150'. POOH LD spent guns, 9/20/2012 MU #4 set of 25' guns, PT & RIH. Continued from WSR of 09/19/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. Cont RIH w/ #3 25' gun assembly. Shoot 3rd interval from 11125' to 11150'. POOH LD spent guns, MU #4 set of 25' guns, PT & RIH. Correct depth to CIBP. Perforate 11100 - 11125'. POH. Lay out guns. All shots fired. PT tree cap. Performed injectivity test with diesel. Anc. Eng. decided the a r acid stimulation was needed. Ordered acid and fluids for job. MU 2.5" JSN acid noz assembly 13.08' OAL, RIH tag CIBP correct to set depth, 11,444', PU & hang off Coil at bottom perf depth 11200'. Wait on SWS pumpers to arrive for acid job. 9/20/2012 * ** Job in Progress *" Continued from WSR of 09/19/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. Cont RIH w/ #3 25' gun assembly. Shoot 3rd interval from 11125' to 11150'. POOH LD spent guns, MU #4 set of 25' guns, PT & RIH. Correct depth to CIBP. Perforate 11100 - 11125'. POH. Lay out guns. All shots fired. PT tree cap. Performed injectivity test with diesel. Anc. Eng. decided the 9/20/2012 acid stimulation was needed. Ordered acid and fluids for job. * "* Job in Progress * ** Continued from WSR of 09/19/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. Cont RIH w/ #3 25' gun assembly. Shoot 3rd interval from 11125' to 11150'. POOH LD spent guns, MU #4 set of 25' guns, PT & RIH. Correct depth to CIBP. Perforate 11100 - 11125'. POH. Lay out :7 guns. All shots fired. PT tree cap. Performed injectivity test with diesel. Anc. Eng. decided the acid stimulation was needed. Ordered acid and fluids for job. MU 2.5" JSN acid noz assembly • 13.08' OAL, RIH tag CIBP correct to set depth, 11,444', PU & hang off Coil at bottom perf depth 11200'. Wait on SWS pumpers to arrive for acid job. 9/20/2012 * ** Job in Progress * ** t:t X31.? Continued from WSR of 09/20/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. & Acid wash. Wait on SWS pumpers for acid job. RU for acid job. Start pumping acid job. Pump acid as per procedure. POH. Perform injectivity test at surface with diesel. 2.0 bpm at 1750 psi WHP. Close swab and SSV. Secure well. Change out packoffs and check chains. Rig down CTU. «< Job 9/21/2012 .; Complete >>> :. . • Daily Report of Well Operations ADL0028327 Continued from WSR of 09/20/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. &Acid wash. Wait on SWS pumpers for acid job. RU for acid job. Start pumping acid job. Pump acid as per procedure. POH. Perform injectivity test at surface with diesel. 2.0 bpm at 1750 psi WHP. Close swab and SSV. Secure well. Change out packoffs and check chains. Rig down CTU. «< Job 9/21 /2012 Complete »> Continued from WSR of 09/20/12. CTU 8, 1.75" coil, Job scope: Set CIBP and Add perf. &Acid wash. 9/21/2012 Wait on SWS pumpers for acid job. RU for acid job. Start pumping acid job. • • T = r 0 S4 10f NOTES: H2S READINGS AVM 125 'WELLHEAD= McEI/OY ACTUATOR = ARSON - - - -- ppm WHEN ON MI. WELL REQUIRES A SSSV 3 -3 3 B WHEN ON ML WELL ANGLE> 70° @ 10909'. KB. ELIV = — 56.40' BF. ELEV = 27.89' "'PARENT WELLBORE NOT SHOWN"'* KOP = 9594' Max Angle = 93° @ 11999' Datum M ) = 10762' li 1 2206' - - {4 -1/2" HES X NP, D = 3.813" Datum TVD = 8800' SS 113 -3/8" CSG, 72#, L -80, ID = 12.347" I 2506' I 3018' - 19 -5/8" X 7' BKR ZXP LTP, ID = 6.290' I TOP OF 7" SCAB LNR ; H 3018' ■ 3036' I- -19 X 7" BKR FLE X -LOCK LNR HGR, D = 6.310" • 0 R Minimum ID = 3.725" @ 10383' ;� ti 4 -1/2" XN NIPPLE ► ' 4 9444' - 9 -5/8" X 7" BKR C-2 ZXP LTP & 4 '` TIEBACK SEAL ASSY, D = 6.151" ►� � i ► 7" SCAB LNR, 26#, L -80, BTGM, -I 9453' 11 s 9461' - I9 - 5/8" X 7" BKR HMC HGR, ID = 6.280" I .0383 bpf, 13= 6.276" I WHPSTOCK (03/12/05) I 9594' 9-518" CSG, 47 #, L -80, ID= 8.681" H - 9622 MLLOUT WNDOW (03 -33C) 9594' - 9622' 10317' I- 14 -1/2" HES X NP, ID = 3.813" ` 7" X 4-1/2' BKR S 3 PRBvi PKR, D = 3.875" ■ , I 10338' - 1 I cif II 10362' H4 -112" 1-ES X MP, D = 3.813" 1 10383' I- 14 -1/2' HES XN NP, D = 3.725' 10391' - 17" X 5" BKR ZXP LIP w /TEBK ID = 4.450" 1 \ ii 4 -1/2" TBG, 12.6#, L -80 TG-11, .0152 bpf, D 3.958" — 10395' 10395' J - 14 -1/2" WLEG, ID = 3.958" i 1 0 7" LNR, 26#, L -80, BTC-M, .0383 bpf, ID = 6.276" - l 10572' ` ® n 10409' I—' X 5" BKR HMC HYDRO PFS FORATION SUMMARY LNR HGR, ID = 4.430" REF LOG: SSEM DGRlROP ON 03120/05 ANGLE AT TOP PE RE: 89° @ 11100' 10417' H 5" X 4 -112" XO, D = 3.980" I Note: Refer to Production DB for historical perf data '....- SIZE SPF INTERVAL Opn/Sqz DATE . * ` 2 -718" 6 11100 - 11200 0 09/20!1 ' 4 -112" WFD PKR 11444' 2 -7/8" 6 11652 - 11677 C 06/27/1 111111Tha. 11890' 1-14-1/2" HF EZ DRILL (05126110) 2 -718" 6 11700 - 11750 C 05/28/11 (09/17/12) 2 -7/8" 6 11706 - 11731 C 06/27/11 12300' CTM H4 -1/2" VVFD CEP (11 /12/08) 2 -7/8" 6 11766 - 11791 C 06/26/11 112690' CTM -14-1/2" WFD CEP (03103107) 1 2 -7/8" 6 12100 - 12150 C 11/13/08 1111/1•14 2 -7/8" 6 12480 - 12530 C 03/03/07 2 -7/8" 6 12880 - 12949 C 04/03/05 2 -7/8" 6 12950 - 12976 C 04/03/05 PBTD 12987' �� i! 14 -1/2" LNR, 12.6#, L -80, ET- M..0152 bpf, D = 3.958' 13072' DATE REV BY COMMENTS DATE REV BY COMMENTS FRUDHOE BAY UNIT 03/01/86 ORIGINAL COMPLETION 06/28/11 PBS/ PJC ADPE3RFS (06/26 - 27/11) WELL: 03-33B 04/30/97 SIDETRACK (03 -33A) 06/29/11 CJW PJC PE RE CORRECTION FH2MT No: 205 - 018 03/23105 N2E S SIDETRACK(03 - 33B) 01/10/12 TIMJM) ADDED H2S SAFETY NOTE AFI No: 50- 029 - 21142 -02 05/30/10 MV /PJC EZ PLUG/ ADPE32FS (05/26 - 28/' 09/24 /12 RRW /JMO SET CEP & ADPERF (09/18- 20/12) SEC 11, T1ON, R35E, 2658' FEL & 1515.13' FNL 02/11/11 M3/JM) ADDED SSSV SAFETY NOTE 02/11 /11 RCT /PJC HIES NP D CORRECTION BP Exploration (Alaska) • • 1E, JOIE CHF ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Higino Dos Santos Production Engineer a ©s _ L D BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03 -33B Sundry Number: 312 -326 '.l_U`' Dear Mr. Santos: A' � Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, 946- Commissioner DATED this2 ` day of August, 2012. Encl. ,ti g, RECEIVED 0 STATE OF ALASKA AUG 2 7 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS AOGCC 20 MC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate 5 " Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -enter Susp. Well ❑ at ' timulate Alter Casing ❑ Other: Set CIBP o 2. Operator Name: 4. Current Well Class: es' q.t • l 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 205 -018-0 - 3. Address: Stratigraphic ❑ Service 0 • 6. API Number: P.O. Box 196612, Anchorage, AK 99519 - 6612 50 -029- 21142 -02 -00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No 5 PBU 03 -33B . 9. Property Designation (Lease Number): 10. Field /Pool(s): ADL0028327 • PRUDHOE BAY, PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13072 " 8917 • 11890 8933 See Attachment None Casing Length Size MD TVD Burst Collapse Structural Conductor 77 20" 91.5# H-40 33 - 110 33 - 110 Surface 2474 13 -3/8" 72# L -80 32 - 2506 32 - 2505.88 4930 2670 Intermediate None None None None None None Production 9591 9 -5/8" 47# L -80 31 - 9622 31 - 8023.76 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): See Attachment See Attachment 4 -1/2" 12.6# L -80 L -80 27 - 10395 Packers and SSSV Type: See Attachment for Packer Types Packers and SSSV MD (ft) and ND (ft): See Attachment for Packer Depths 4 -1/2" MCX I -SSV 2206', 2205.9' 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program 5 BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG 5 • Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is� ue and correct to the best of my knowledge. Contact Higino Dos Santos Prepared by Garry Catron 564 -4424 Printed Name Higi Dos •s Title Production Engineer Signature — _ar = / Phone Date 564 -4342 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 61 2 - � j20 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /O— Yo APPROVED BY 2 Approved by: , / COMMISSIONER THE COMMISSION Date: �'I2.. ` . n/ �tP G INAL Form j ■ , - • 120 0 H �u � o �� ��� I S ub it in Duplicate , • Perforation Attachment ADL0028327 Well Date MD Plug Type TVD 03 -33B 5/28/2010 11890 4 -1/2" HES EZ DRILL PLUG 8933 03 -33B 11/13/2008 12300 4 -1/2" WFD CIBP 8921 03 -33B 3/5/2007 12690 4 -1/2" WFD CIBP 8917 Casing Summary ADL0028327 Casing Length Size MD Top MD Base TVD Top TVD Base Burst Collapse Grade CONDUCTOR 77 20" 91.5# H-40 33 110 33 110 1490 470 H -40 LINER 6425 7" 26# L -80 3018 9443 3016 7895 7240 5410 L -80 LINER 2681 4 -1/2" 12.6# L -80 10391 13072 8589 8917 8430 7500 L -80 LINER 1129 7" 26# L -80 9443 10572 7895 8722 7240 5410 L -80 PRODUCTION 9591 9 -5/8" 47# L -80 31 9622 31 8024 6870 4760 L -80 SURFACE 2474 13 -3/8" 72# L -80 32 _ 2506 32 2506 4930 _ 2670 L -80 • • • • Perforation Attachment ADL0028327 Well Date Perf Code MD Top MD Base TVD Top TVD Base 03 -33B 6/27/11 APF 11652 11677 8940 8940 03 -33B 6/27/11 APF 11700 11706 8939 8939 03 -33B 6/27/11 APF 11706 11725 8939 8939 03 -33B 6/27/11 APF 11725 11731 8939 8939 03 -33B 6/27/11 APF 11731 11750 8939 8938 03 -33B 6/26/11 APF 11766 11791 8938 8937 03 -33B 5/26/10 BPS 12100 ' 12110 8925 8925 03 -33B 5/26/10 BPS 12110 12130 8925 8925 03 -33B 5/26/10 BPS 12130 12150 8925 8924 03 -33B 5/26/10 BPS 12480 12505 8916 8916 03 -33B 5/26/10 BPS 12505 12530 8916 8916 03 -33B 5/26/10 BPS 12880 12923 8916 8916 03 -33B 5/26/10 BPS 12923 12930 8916 8916 03 -33B 5/26/10 BPS 12930 ' 12949 8916 8916 03 -33B 5/26/10 BPS 12950 12976 8916 8917 AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BRIDGE BPS PLUG SET OH OPEN HOLE FCC FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • • Packers and SSV's Attachment ADL0028327 Well Facility Type MD Top Description TVD Top 03 -33B SSSV 2206 4 -1/2" MCX I -SSV 2206 03 -33B PACKER 3018 7" Baker ZXP Top Packer 3016 03 -33B PACKER 9443 7" Baker ZXP Top Packer 7895 03 -33B PACKER ' 10338 4 -1/2" Baker S -3 Perm Packer 8550 03 -33B PACKER 10391 5" Baker ZXP Top Packer 8589 • • bp ��i %P ..�� �.� 'woo Memorandum To: Clark Olsen & Tyler Norene Date: July 25 2012 ADW Well Service Team Leaders From: Higino dos Santos AFE: DS- 03Production Engineer Reviewed: Michael Hibbert, 08/17/2012 Est. Cost: Subject: 03 -33B CIBP and Add Perf IOR: 200 Type Desc. Comment S Retrieve 4 -1/2" MCX and drift to deviation F Schmoo -B -Gone treatment C Drift/Flag /Log, Set J.P, Add 100' perforations, Injectivity Test, Acid Stimulation (P) S SBHPS, set 4 -1/2" MCX Current Status: WAG injector, SI MI on 3/19/12, swapped to water on 3/24/12. Last Injection Rate: 11,511 bwpd © 1,447 psi 7/22/2012 Max Deviation: 93° @ 11,999' MD Min. ID: 3.725" @ 10,383' MD (4 -1/2" XN Nipple) Last Downhole Ops: 06/30/2011 — Set 4 -1/2" MCX @ 2,206' MD and ran check set Last SBHP: N/A Latest H2S level: N/A - Injector Job Objective: The objective of this procedure is to set a CIBP to isolate all current perforations and to add 100' of • new perforations for the fifth MI bulb in the well. If required, an acid stimulation will be performed on coiled tubing to increase injectivity. Also, an opportunistic static bottom hole pressure will be obtained when slickline returns to re -set the MCX safety valve. Well History: Well 03 -33B is a horizontal well sidetracked in the bottom zone 27P (just above 26N shale) in 2005 for MI. The well is sharing a pattern with water injector 09 -20i and was POPed in April 2005 and just completed the 4 cycle of MI on 19 of March 2012 that lasted 230 days. 03 -33B is currently on water injection (11,511 bwpd) acting as injection swing well until is put back on MI. A total of 5 MI bulbs are planned for 03 -33B and the next MI bulb is scheduled for August 2012 to inject 5 BCF. Producers 09- 27, 09 -01, 09 -49 and 09 -03 are receiving benefit from these MI bulbs. Discussion and Justification 03 -33B has a history of add perfs followed by acid stimulations. Therefore the acid was included in the procedure to be performed on coil. The last CIBP and perforations were added without tie -in logs due to large uniform sands. This set of perforations will be located closer to the kick -off point and depth control is more critical. The well is currently in water injection and all gas should be - displaced away from the well by now. Once the well has been swapped to diesel, please pump only diesel to maintain diesel fluid column. For questions or comments please call Higino dos Santos 564 -4342 (work) or 713- 269 -3879 (mobile). Cc: Well File Note: This program was deed with the intention that it would req• 7 coil runs: 1. Drift/Log /Flag 2. Set CIBP 3. Add 25' perforations 4. Add 25' perforations 5. Add 25' perforations 6. Add 25' perforations 7. Acidize perforations to increase infectivity (pending infectivity test) 03 -33B SL Procedure 1. MIRU Slickline. PJSM. 2. Pull MCX from 4 -1/2" HES X Nipple @ 2,206' MD. 3. Drift to max deviation with drift large enough for 4 -1/2" CIBP and 25' 2 -7/8" dummy gun. Drifted to 10,977' SLM December 13 2010 with 2 -1/2" centralizer. 4. RDMO. 03 -33B Fullbore - Schmoo -B -Gone Treatment 1. MIRU. PJSM. 2. Pressure test. 3. Pump 5 bbl of methanol spear and 230 bbl of SBG mix. (17% concentration, 44 bbl of concentrate in 216 bbl of hot water) followed by 5 bbl of methanol. 4. Wait three hours. 5. Pump 220 bbl of 1% KCI displacement flush followed by 5 bbl of methanol. 6. Wait three hours. 7. Hand well back to operations to put well back on injection. 03 -36A Coil Add Perf Procedure Ate. C1 g p G / /'(kq 1. MIRU CTU. PJSM 2. Displace wellbore with -1.2 tubing volumes of diesel at ambient temperature. Bullhead -230 bbl diesel down tubing. 3. MU drift assembly with nozzle and GR/CCL. Drift to -11,500' MD, log to 10,200', paint flag and POOH. Tie in log: PDS Jewlery Log 1- Apr -2005 OD of CIBP to be run 4. Pick up CIBP, RIH, tie into flag and s CIBP @ 11,444' POOH. Ensure good depth control so we can use the CIBP to tag for future tie in if needed. When pumping balls to seat use diesel to maintain diesel fluid column. 5. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 6. RIH, tag CIBP for depth control and perforate 11,175' - 11,200' MD. POOH. - Note any tubing pressure changes in AWGRS summary. 7. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 8. RIH, tag CIBP for depth control and perforate 11,150' - 11,175' MD. POOH. 9. Pick up 25' of 2 -7/8" 2906 PowerJet Omega HMX, 6 SPF, 60deg phasing guns. 10. RIH, tag CIBP for depth control and perforate 11,125' - 11,150' MD. POOH. 2 11. Pick up 25' of 2 -7/8" 06 PowerJet Omega HMX, 6 SPF, 601 phasing guns. 12. RIH, tag CIBP for depth control and perforate 11,100' - 11,125' MD. 13. Pick up 200' and perform injectivity test with diesel down backside of coil. If injectivity is less • than 2bpm as 2,000 psi, perform the following acid stimulation, Otherwise, RDMO. Please record injectivity results in AWGRS report. 03 -33B PENDING Acid Stimulation Comments: • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. Note when acid and diverter stages hit the perfs and the response. • In general, pump job at maximum allowable or achievable rate /pressure. • Attempt to not exceed 2000 psi while acid is entering the perforations if possible. It is ok to go up to 3000 psi surface pressure in the following cases: a. If the diversion is very effective at plugging slots. Increase pressure as needed to allow job to be completed. • Send an electronic copy of the treatment report including digital, ASCII, or an excel copy of pumping rates and pressures to Higino dos Santos at: Hiaino.dos@bp.com Perforation Details Zone MDT MDB H Status Z2 11100 11200 100 Open Design Details: Wellbore Volume 170 bbls to top of perf at 11100' MD, 175 bbls to CIBP at - 11444' Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Foam Design 15bbl per diversion 70Q Foam (2 diversions) Pres SBHP 3110 psi at 8800 tvd, SBHT is 190 F Treatment Procedure 14. Ensure the following before starting the job: a. Ensure current MSDS for this job is onsite and acid safe handling procedures are followed b. Ensure that the acid shower trailer is on site and functional c. Keep out all personnel not associated with this job d. Ensure Sundry for performing acid stimulation is on location. e. Well has L -80 liner. Ensure correct additives are used. SBHT 190 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/-1% for HCI. Fluids should be 90 -110 F 15. MU coil tool string with jet swirl nozzle and RIH to top of perforations (diesel should be in the coil at this stage) and displace coil with Ammonium Chloride while taking returns through backside. Displace diesel -500ft away from top of perforations to prevent diesel and acid getting into contact with each other (500 ft - 6.5 bbl). Close in backside and keep on injecting ammonium chloride until steady injection is achieved. 3 If needed to establianjection, go to 3,000 psi WHP, but flip immediately back to 2,000 psi WHP as to not frac the well during the acid wash. 16. Pump fluids per attached pump schedule while reciprocating nozzle across newly perforated interval (11,100' - 11,200'). When acid is on the perfs, max WHP should be 2,000 psi. Before POOH, complete the over flush to ensure that the acid has been pushed away. The acid stim should take -9.5 hours to pump. Please record N2 rates and total volumes pumped in AWGRS report. 17. POOH with coil and perform another injectivity test with diesel down the backside and make note of stabilized rate and pressure in daily report. 18. RDMO Coil. Fluid Type Vol (bbl) Vol (gal) o aa) 3% NH4CI + F103 418 17,562 m = 12% HCI 71 3,000 I—° j 9:1 Mud Acid 71 3,000 Foam (3% NH4CI +F103 +N2) 8 336 Foam Mixing Rates Liquid Rate N2 Rate bbl /min scf /min 0.25 314 0.5 629 0.75 943 1 1257 1.25 1571 1.5 1886 Temperature: Medium (175 °F to 225 °F) Completion metallurgy: L80 total chem total chem Loading for: 12% HCI 9:1 mud acid 12% HCI 9:1 mud acid Product Code: Function: Units: A264 ACI gal /Mgal 6 6 18 18 A201 Inhibitor Aid gal /Mgal 15 15 45 45 A153 Intensifier Ib /Mgal 0 0 0 0 F103 Flowback aid gal /Mgai 2 2 6 6 L058 Iron Control Ib /Mgal _ 20 20 60 60 W054 Antiemulsifier gal /Mgai 5 5 15 15 U067 Mutual Solvent gal /Mgal 0 50 0 150 03 -33B SL Procedure 1. MIRU Slickline. PJSM. 2. SBHPS as per attached form. 3. Run MCX and set in 4 -1/2" HES X Nipple @ 2,206' MD. 4. Run check set to ensure MCX is set. 5. RDMO SL. 6. Hand well back to operation to POI. 4 Stage Cum Foam vol, N2 vol, Stage Step Description Fluid Fluid Fluid bbl I scf /bbl Pre -Flush 1 Pre - Displacement 3% NH4CI + F103 60 60 I 2 Acid 12% HCI 24 84 3 Mud Acid 9:1 Mud Acid 24 108 m 1 4 Overflush 3% NH4CI + F103 36 143 c 5 Diverter Foam (3% NH4CI + F103 + N2) 4 147 15 1257 s 6 Spacer 3% NH4CI + F103 20 167 v co 7 Acid 12% HCI 24 191 c 8 Mud Acid 9:1 Mud Acid 24 215 E 2 9 Overflush 3% NH4CI + F103 36 251 • ' 10 Diverter Foam (3% NH4CI + 1-103 + N2) 4 255 15 12571 a 11 Spacer 3% NH4CI + F103 20 275 12 Acid 12% HCI 24 298 3 13 Mud Acid 9:1 Mud Acid 24 322 14 Overflush 3% NH4CI + F103 36 358 Overflush 15 Displacement 3% NH4CI + F103 211 569 III I 1 1 • • TREE = ow SAFETY NOTES: H2S READINGS AVERAGE 125 WELLEAD ACTUAATOR = AXEL OY SON 03-33B WHEN ON M L W MI. WELL ELL ANGLE 70° 0909' ACTUTOR AXEL KB ELEV = 56.40' ***PARENT WELLBORE NOT SHOWN* ** BE ELEV = 27.89' i J KOP = 9594' Max Angle = 93° @ 11999' 2206' H4 -12" HES X NIP, ID = 3 Datum MD= 10762' Datum TVD = 8800' SS 113-3/8" CSG, 72 #, L -80, ID = 12.347" I 2506' 1 3018' 1 -19 518" X T' BKR ZXP LTP, ID = 6.290" ITOP OF 7" SCAB LNR 1— 3018' 3036' H9 -5/8" X 7" BKR FLEX -LOCK LNR HGR, ID = 6.310" • 0 Minimum ID = 3.725' @ 10383' 4-1/2" XN NIPPLE 9444' — 9- 5/8 "X7" BKR C- 2ZXPLTP8 • • TIEBACK SEAL ASSY, ID = 6.151" lo:, i 7" SCAB LNR, 26 #, L -80, BTC M, I 9453' y 9461' —19 -5/8" X 7" BKR HMC HGR, ID = 6.280" I 01 II, 0383 bpf , ID = 6.276" IWHIPSTOCK(03 /12/05) H 9594' 19-5/8" CSG, 47 #, L -80, ID = 8.681" I—I - 9622 MILLOUT WINDOW (03 -33C) 9594' - 9622' 10317' 1--141 /2" HES X NIP, ID = 1813" I i . 10338' — 17" X 4-12" BKR S -3 PREM PKR, ID = 3,875" II ' 10362' —14-1/2" HES X NIP, ID = 3.813" I 10383' —14 -1/2" HES XN NIP, ID = 3.725" I 10391' —I 7" X 5" BKR ZXP LTP w /TIEBK, ID= 4.450" 10395' —14-1/2" WLEG, ID = 3.958" 4-1/T TBG, 1264, L -80 TC-11, .0152 bpf, ID= 3.958" —I 10395' a 7' LNR, 264, L -80, BTC-M, 0383 bpf, ID = 6.276" H 10572' ` 10409' 1 — 7" X 5" BKR HMC HYDRO LNR HGR, ID = 4.430" PERFORATION SUMMARY REF LOG. SSEWR/DGR/RDP ON 03/20/05 g li. 10417' I — 5" X 4-1/2" XO, ID = 3.980" ANGLE AT TOP PERF: 91° @ 11652' Note Refer to Production 08 for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE .r— 11890' H41/2" HES EZ DRILL (05/26/10) I 2 -7 /8" 6 11652 - 11677 0 06/27/11 2 -7/8" 6 11700 - 11750 0 05/28/10 , 12300' CTM I-14-1/2" WFD CIBP (11/12/08) I 2 -7/8" 6 11706 - 11731 0 06/27/11 - 2 -7/8" 6 11766 - 11791 0 06/26/11 12690' CTM H 4 -12" WFD CIBP (03/03/07) 1 2 -718" 6 12100 - 12150 C 11/13/08 i 1 2-7/8" 6 12480 - 12530 C 03/03/07 2 -7/8" 6 12880 - 12949 C 04/03/05 , 2-7/8" 6 12950 - 12976 C 04/03/05 i •t1.f 1 PBTD I— 12987' ::� 11 ' . 14 -1/2" LNR, 12.64, L -80, IBT- M..0152 bpf, ID = 3.958" —1 13072' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUOhOE BAY UNIT • 03/01/86 ORIGINAL COMPLETION 06/28/11 PBS/ PJC ADPERFS (06/26- 27/11) WELL: 03 -3313 04/30/97 SIDETRACK(03 - 33A) • 0629/11 CJW PJC PERF CORRECTION PERMIT No. 205- 018 03123105 N2ES SIDETRACK (03.338) 01/10/12 TMN/JMD ADDED H2S SAFETY NOTE AR Nc 50-029-21142-02 05/30/10 MV /PJC EZ R-UG/ ADPERFS (05/26 - 28/10) SEC 11, T1 ON, R35E, 2658' FEL & 1515,13' FNL 02/11/11 MB/JMD ADDED SSSV SAFETY NOTE II 02/11/11 RCT /PJC HES NIP !D CORRECTION II BP Exploration (Alaska) Mini -Log • • 0 Minilog for Well Teehl©g Project PBU_WF 03 -33B L.trthor LAURA J.LARSON Scale 1 3000 Gate 4/16/2012 Injector Well: 03 -33B UW I: 500292114202 Elevation: 56.39 SPUD date: 2005-03-14 00:00:00 ; USA Short name: 03 -338 Etevaten datum: KB Completion date. 2005 -04-02 00:00:00 7v-I.1 PRUDHOE Long name: DRILLSITE 03 NO 33B Total depth: 13072 L rvait r.,. I - 148.2717074 Status: Hirt.- Alaska Coordinate system: NAD27 AFT L:+t cI 70.2288295 Operator: BPXA :r:9 oo BPXA z GPtmM Pt's'iC tr ppi�pp p PE Info D v n MWA V MR R OPM �� 3 -� TVDSS MD GR (FEET) (FEET) LL TVDSS MWD.GR c o O �- 13000 1:3000 mdn. T „nt5 _� - MWD art,7n WD ,,, 8660 Z f 4IP S 8730 J t - - 8790 -4 - 10750 - ' — 1 t - 8840 1 s - 8880 - 11000 • ti Add Perf @ 11,100' - 11.200' rnd _ - 11250 - — - 8890 - . CIBP 11,444' and 11580 1 -tf TSAD - 11750 .. _ : cc - 8880 27P : ` - 12000 ---- � - 8870 -- i.i• yr ... -- 12250 - 8860 12500 SOP 3c% - 8860 -r 2 12750 S SO O Q P '' BPS 5aP ., - 13000 7 • . • 0 Jewlery Log .. ! PROACTIVE DIAGNOSTIC SERVICES, INC. : -- -- _ ci c ' Company BP EXPLORATION (ALASKA), INC. - ii - 3 ... Well 3-33 B i 1 111111:11iiii liiIiiiiiniiiiiiiiiiiii co . 1 0 2 0 2 7 1 7244 < Field PRUDHOE BAY c, ! County NORTH SLOPE State ALASKA .4.-.--, ›.... 0 a , 0 : Surface Location : Other Services 2,658' FEL & 1515.13' FNL : Coil Flag SEC 11, T 10N, R 15E co co CL Z < i Elevation ! ai >, !Permanent Datum MSL Elevation 0.0 t' a - KB. 0.00' E ,!---. _ 4-. Log Measured From Drill Floor 56.39 Above Perm Datum I D.F. 56.39' 0 iii- Li 0 u) i API Serial Number 50-029-21142-02 !GI 27 89' Date . 1-Apr-2005 ' Run Number One PBTD 13,072' : i-t. i -1- ' Depth Loggei 12,991' — Bottom Logged Interval 12,991' l -1--- Top Log Interval 9,993' . Open Hole Size i N A. L . Type Fluid : N.A. .. l Max. Recorded Temp. N.A. 7' ! i FINAL PRINT Time Well Ready 15:00 Time Logger on Bottom • 4 20:18 : Equipment Number COIL # 9 ' Location North Slope • i ii _* Service Invoice No 5672 , 4 : Recorded By ' Wm. McCrossan — ! Witnessed By Kirk Forcade Clark Olsen , Borehole Record Tubing Record ' t Run Number i Bit i From 7- To ; Size i LB / Ft ! From ! To . _,_ --4 i ! 4.5 ' 12.6 T Surface ! 10,391' . i I i_ i ' f t --4- , - T i- A) 2i Casing Record i i Size , . LB/Ft . Top . . Bottom 1; t Surface Stnn9 13 3/8" . 72 Surface 2,506' ; Prot. String i 95/8 47 3,018' 10,374' TI i-- LI Liner 7" 26 9,444' ; 10,572' v! Liner 4 1/2" 12.6 !-- 10,391' -t- 13,072' , v Liner i - 8 • -� — •1, 1 i - ,-1 1---1 -4--h -F --4- , -_`r- - : -- 11 _ __rte -. t , -} - : I- +1-1- -ice _ • --. �_ i _ �_1.- ..... -- `-•"••-1---• .— F �N j i 1 j l • N °' Q I 1 — -- — — i — t t — I 0 . 7 0 1 it; :;'• 1 i i • • i 1 I III I I i _._� t 1 i I � 1 I : ■ - - I ; - -- - 1 -- - - -. }.. - --- -- i - I - - + 4 - - -- - . . i T n �:I. I ( I ! T i 1 1 0 O M 1 1 I i I H., 1 . II I i I , . I i I j I t_i , I -,� : , j - Ii; j; i I; Illi III - . • + ' ' I 1 I j j I +i I i � 1 ! � ! 1.1 i I 1 I � 1 I 'I Ij 1 1 f , Ij ,i —I .--.H....1--f--; a 1 �� t ' _ }- ! { I 1 1 ;� 1 , i 1 - -: * + : I I i i + _ , _ j I L O ! ■ _ _■ I I I I T r - ; _ • . O O , - - - � f + i r— - - T Tt– _ I i i: ! t • N 1' ! I I 1 1 I i ; I i �� 1 ! II! ! 1�i _d Q. - - + - � _ i -� I I I 3 I ! _ I .Y,- I + IT Vii_; 1 I , 1 , ! . 1 --� -- --- ( - V'.— t y if t , —1 T � . , • 1 1 1 11 I I I I I 4 —1 i • { 1 I 1 T r t �, ! �1 �_ -- - i j T I - r a ! t 1�1 t T - _ r `- r T - —. L 1 - L.I. -_ -_I , 1 --�-i - . . ', „ .L ` _t_.�.. : ; 1 ' I }" Y -, ,, „ , - I ' . I T 1 , I 1 , I 1--, ! ! , I ! ' I 1 I ! II _yi ! __ 1 I ! 1 ! i T{ I I I +4 - -[ —i--- — _;--H' 41 i 1 I 1 -, i , - I I l ' _ -r 1 . i------ I --..� --1 f 1-+ +-'T "- �r-4 -i-_- _ . +- t , ` 1 } 1 - + + -- I _- I ' -k): -. - I ! , + i � ; . ! i11: I Ii: I 1 1I ; { 1i1 ( ; ;' '11 i i ! rt - j — �, -1 : i I; ' r' . !;I O I I ~ �- i + t- t-+ .. + 4- 4±.--4------"; }- 1-- -H--- 1- -,1-F� , ' ' ,, 1 ' ' ` 1' 1 ', ' �' t , I i i- - ,� , I 1 ` i Ili' I I i 1 ; I 1 -T-- , i �i I ,, I i . -+. I--I -- � - - ±- ,. -.� -- —'- i ! ' I 1 f '444 '444 ( -I- t ' �. --Ll_ ` +--4-4 - '� Y i j.. —.,H- __ - — - I 1 1 i , V- i ! 1 I- -- r- 1 —I•-H- t - 1 [- r- Y - -' 1 -t-1- Li-- III Ili I I ,i' . !; I 1 1 1 1 1 ! I ; ,�:ii ,1 � :t I; ; I : II ; ' ! •l I i! ! •1 I o X 1 I II' ; I i i ! i i! I I 1 i I! I'; I I; 1! , I • i i I 1 - ;; - - I I l ! i 1 I ' _ ; - II - �-- ,I - - - _ II I i Ii ! I I I I I- t I f ! T - + T I I i i 1 { i j -}� -+ I ; . { ' ? -� -,- - +-�-• —! -- ! I - 1,- .- .. - .- -- -- - ! — — T — ? ! _ ( '� f - - -."'1 1 ± I . , 3 ! + 1 - 1 — - - 1 + { ! , - -'-- _ I - - x - 1 -- 1 ! 1 i - - -, 'I ti f j - --+ - - - .. - • • I it i1!: I • i I I,'. it 1 1 ! I I III I t i 1 1 1 ' IrI! 'II i! It!! ; .1; : ; ! - J -.� } -r H � -- -. I _ _. _ - I i ' • ; I 1 -'f' «'i f `rk'�.',r . 3.� �,1':r'-� - '°"r"'� - 4.-• * �� - .�#=t.•. . -r }. _•� tr�'b.- =-r a. 1- ...-.c y.. - .Y . _t i,._ -X iir • !. • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 d o 1 03 - 333 Mr. Tom Maunder Oil and Gas Conservation Commission 333 West 7 Avenue ��� Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -03 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -03 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, ti /:t Mehreen Vazir BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10 -404) DS -03 10/26/11 Corrosion Initial top of Vol. of cement Final top of Cement top Corrosion inhibitor/ Well Name PTD # API # cement pumped cement off date inhibitor sealant date ft bbls ft gal 03 -01 1750750 50029200930000 Sealed conductor NA NA NA NA NA 03 -02 1760240 50029202030000 Sealed conductor NA NA NA NA NA 03-03 1760390 50029202110000 Sealed conductor NA NA NA NA NA 03-04 1760510 50029202180000 Sealed conductor NA NA NA NA NA 03-05 1760570 50029202220000 Sealed conductor NA NA NA NA NA 03-06 1760600 50029202240000 Sealed conductor NA NA NA NA NA 03-07A 2040430 50029202200100 Sealed conductor NA NA NA NA NA 03-08 1760730 50029202310000 Sealed conductor NA NA NA NA NA 03-09 1790220 50029203620000 Sealed conductor NA NA NA NA NA 03-10 1790210 50029203610000 Sealed conductor NA NA NA NA NA 03-11 1790470 50029203830000 Sealed conductor NA NA NA NA NA 03 -12 1790580 50029203920000 Sealed conductor NA NA NA NA NA 03-13 1790710 50029203990000 Sealed conductor NA NA NA NA NA 03-146 2090020 50029204070200 Sealed conductor NA NA NA NA NA 03 -15A 1930150 50029204140100 Sealed conductor NA NA NA NA NA 03 -16A 1970330 50029204150100 Sealed conductor NA NA NA NA NA 03-17 1791020 50029204200000 Sealed conductor NA NA NA NA NA 03 -18A 1930420 50029204210100 Sealed conductor NA NA NA NA NA 03 -19 1830920 50029209710000 0.3 NA 0.3 NA 1.7 7/31/2010 03 -20A 1930470 50029209800100 6.2 NA 6.2 NA 40.8 8/2/2010 03 -21 1831120 50029209900000 6.6 NA 6.6 NA 49.3 8/3/2010 03 -22 1831230 50029210000000 0.0 NA 0 NA 7.7 10/26/2011 03 -23 1831270 50029210040000 >25 21.0 0.8 7/15/2011 5.1 7/18/2011 03-24A 1980060 50029210150100 1.3 NA 1.3 NA 8.5 9/16/2010 03-25A 1930230 50029210210100 >25 12.0 2.25 7/12/2011 13.6 7/17/2011 03 -26 1831510 50029210270000 0.2 NA 0.2 NA 0.85 8/2/2010 03 -27 1840620 50029211090000 23.5 5.0 0.4 7/12/2011 3.4 7/17/2011 03 -28 1840720 50029211140000 55.0 17.0 0.4 7/12/2011 3.4 7/17/2011 03 -29 1840790 50029211180000 6.0 NA 6 NA 20.4 8/3/2010 03-30 1840830 50029211220000 4.4 NA 4.4 NA 22.5 8/3/2010 03-31 1840920 50029211290000 10.0 NA 10 NA 113.9 8/3/2010 03-32B 2090050 50029211410200 1.5 NA 1.5 NA 8.5 7/30/2010 "- 03-336 2050180 50029211420200 7.8 NA 7.8 NA 57.0 7/30/2010 03 -346 2000110 50029211320200 0.2 NA 0.2 NA 9.4 10/26/2011 03-35 1910800 50029221840000 5.8 NA 5.8 NA 39.1 7/28/2010 03-36A 2070200 50029223400100 1.5 NA 1.5 NA 3.4 7/28/2010 03-37 2091390 50029234210000 2.5 NA 2.5 _ NA 16.2 8/2/2010 STATE OF ALASKA ALASKAIDAND GAS CONSERVATION COMMISSI10 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate irj Other 0 ACID Performed: Alter Casing ❑ Pull Tubing Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development ❑ Exploratory ❑ J 205 -0180 3. Address: P.O. Box 196612 Stratigraphic❑ Service 0 6. API Number: Anchorage, AK 99519 - 6612 ,, 50- 029 - 21142 -02 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028327 PBU 03 -33B 10. Field /Pool(s): c. PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: 11890, 12300 Total Depth measured 13072 feet Plugs (measured) & 12690 feet true vertical 8917 feet Junk (measured) None feet Effective Depth measured 12987 feet Packer (measured) 3018. 9443 10391, 10338 feet true vertical 8917 feet (true vertical) 3016, 7895 8589, 8550 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 77' 20" 33 - 110 33 - 110 1490 4770 Surface 2474' 13 -3/8" 32 - 2506 32 - 2506 5380 2670 Production 9591' 9 -5/8" 31 - 9622 31 - 8024 6870 4760 Liner 7554' 7" 3018 - 10572 3016 - 8722 7240 5410 Liner 2681' 4 -1/2" 10391 - 13072 8589 - 8917 8430 7500 Perforation depth: Measured depth: 12880 - 12923 12923 - 12930 12930 - 12949 12950 - 12976 _ True Vertical depth: 8916.47 - 8916.46 8916.46 - 8916.46 8916.46 - 8916.48 8916.48 - 8916.5 _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 10395 Packers and SSSV (type, measured and true vertical depth) Two 7" Baker ZXP To Packer 3018. 9443 3016.7895 Two 5" Baker ZXP Top Packer 10391 8589 4 -1/2" Baker S -3 Packer / 5" BKR ZXP Packer 10338 8550 12. Stimulation or cement squeeze summary: Intervals treated (measured): }} rr,, Treatment descriptions including volumes used and final pressure: «,�Sj L 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 1988 3083 Subsequent to operation: 14. Attachments: 15. Well Class after work: _ Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service 151 Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 311 -150 Contact Elizabeth Barker Printed Name Elizabeth Barker Title Data Manager Signature F:f 60,4 / Phone (907) 564 -5674 Date 7/11 /2011 Form 10-404 Revised 10/2010 IIBDNMS JUL 13 QP"L v.._ Submit Original Only 7,1361 03 -33B 205 -018 PERF ATTACHMENT Sw Name Operation Date Peri Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -33B 4/3/05 PER 12,880. 12,923. 8,916.47 8,916.46 03 -33B 4/3/05 PER 12,923. 12,930. 8,916.46 8,916.46 03 -33B 4/3/05 PER 12,930. 12,949. 8,916.46 8,916.48 03 -33B 4/3/05 PER 12,950. 12,976. 8,916.48 8,916.5 03 -33B 3/2/07 APF 12,480. 12,530. 8,915.79 8,915.55 03 -33B 3/2/07 BPS 12,690. 12,987. 8,916.83 8,916.5 03 -33B 3/3/07 APF 12,480. 12,530. 8,915.79 8,915.55 03 -33B 11/13/08 BPS 12,300. 12,690. 8,920.84 8,916.83 03 -33B 11/13/08 APF 12,130. 12,150. 8,924.5 8,924.13 03 -33B 11/13/08 APF 12,110. 12,130. 8,924.88 8,924.5 03 -33B 11/13/08 APF 12,100. 12,110. 8,925.08 8,924.88 03 -33B 5/26/10 APF 11,725. 11,750. 8,938.81 8,938.15 Ill 03 -33B 5/26/10 BPS 11,890. 12,300. 8,933.05 8,920.84 03 -33B 5/27/10 APF 11,700. 11,725. 8,939.36 8,938.81 03 -33B 6/26/11 APF 11,766. 11,791. 8,937.66 8,936.78 03 -33B 6/27/11 APF 11,652. 11,677. 8,940.17 8,939.79 03 -33B 6/27/11 APF 11,706. 11,731. 8,939.24 8,938.67 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 03 -33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 6/27/2011 CTU #8 w/ 1.75" CT (33.7 bbls) Scope: Drift/log, add 75' perfs, mud acid stim for injectivity Finish POH w/ perf gun #1. RIH and perforate 11706- 11731' w/ 6 spf w/ SWS 2- 17/8" guns. POH w/ perf gun #2. Shots fired, ball recovered. RIH w /Gun #3. perf w /6spf x 2 7/8" guns 11652' - 11677'. POOH w /spent guns, ball recovered. RD TCP, MU JSN assembly for acid job, 13.57' TOL, Max OD 2.25 ". Liquid pack wellbore w/ i ;244 bbls NH4C1. RIH w/ nozzle assy to tag of CIBP at 11890'. Acidizeby program €w/ 30 bbls 10% DAD acid, 50 bbls 12% HCI acid, 50 bbls mud acid using foam 1 diversion and spacers of NH4CI while recip over perf interval 11652 - 11791'. Initial injectivity 0.3 bpm at 1500 psi. After DAD acid pass had 1.5/1500 injectivity I. In pro ress 6/28/2011 CTU #8 w/ 1.75 CT (33.7 bbls) Scope: Drift/log, add 75' perfs, mud acid stim for injectivity Finish acid job. Injection test at 2.0 bpm for 60 bbls was —1100 psi and at 3.0 bpm for 50 bbls was —1300 psi. Overdisplace w/ 140 bbls NH4CI + 140 bbls FW. FP wellbore w/ 40 bbls McOH. Weekly BOP test w/ no failures. Wait on weather to lay, down derrick 1Job complete I i FLUIDS PUMPED BBLS 15 50/50 METH 200 1% KCL XS 75 50/50 McOH 1 DIESEL 50 12% HCI ACID 50 MUD ACID 30 10% DAD ACID 500 NH4CI 210 FW 1131 TOTAL TREE.' * CM/ SAFETY IFS: WELL REQUIRES A SSSV WELLHEAD = McEVOY WHEN O L WELL ANGLE > 70° @ 10909'. ACTUATOR = AXELSON 03-3313 ** * PARENT WELLBORE NOT SHOWN * ** KB. ELEV ,= 56.40' BF. ELEV = 27.89' KOP = 9594' Max Angle = 93 @ 11999' 1 2206' H4 -1/2" HES X NIP, D = 3.813" Datum MD = 10762' Datum "(VC = _ 8800' SS 1 13-3/8" CSG, 72 #, L -80, ID = 12.347" I-1 2506' 1 , 3018' 1-19-5/8" X 7" BKR ZXP LTP, ID = 6.290" ITOP OF 7" SCAB LNR 1 - 1 3018' 1 1 3036' H 9 -5/8" X 7" BKR FLEX -LOCK LNR HGR, ID = 6.310" I ■ 4 Minimum ID = 3.725 " @ 10383' • 4-1/2" XN NIPPLE ; 9444' 1 — 9 -5/8" X 7" BKR C-2 ZXP LTP & I I , , II TIEBACK SEAL ASSY, ID = 6.151" 7" SCAB LNR, 26 #, L -80, BTGM, — 9453' 9461' H 9 -5/8" X 7" BKR HMC HGR, ID = 6.280" I .0383 bpf, ID = 6.276" 'WHIPSTOCK (03/12/05) 1 - 1 9594' 9 -5/8" CSG, 47 #, L -80, D = 8.681" I-1 — 9622 MILLOUT WINDOW (03 -33C) 9594' - 9622' 10317' 1 - 14 - 1/2" HES X NIP, ID = 3.813" I ii ' 7" X 4 -1/2" BKR S -3 PREM PKR ID = 3.875" 1'i 10338' 1--1 1 ►i 10362' H 4 -1/2" HES X NIP, ID = 3.813" 1 10383' 1 14 -1/2" HES XN NIP, ID = 3.725" 1 I 10391' j X 5" BKR ZXP LTP w /TIEBK, ID = 4.450"I I4 - 1 /2" TBG, 12.6 #, L -80 TC -11, .0152 bpf, ID = 3.958" 1--1 10395' 10395' H 4 -1 /2" WLEG, ID = 3.958" 1 17" LNR, 26 #, L -80, BTC-M, .0383 bpf, ID = 6.276" I---1 10572' 10409' 17" X 5" BKR HMC HYDRO LNR HGR, ID = 4.430" PERFORATION SUMMARY REF LOG: SSEWR/DGR/ROP ON 03/20/05 10417' 1 X 4-1/2" XO, ID = 3.980" ANGLE AT TOP PERF: 91° @ 11652' Note: Refer to Production DB for historical perf data 11890' 1 - 14 - 1/2" HES EZ DRILL (05/26/10) 1 SIZE SPF INTERVAL Opn /Sqz DATE 2 -7/8" 6 11652 - 11677 0 06/27/11 2-7/8" 6 11700 - 11750 0 05/28/10 i 12300' CTM 1 - 14 - 1/2" WFD CIBP (11/12/08) I 2 -7/8" 6 11706 - 11731 0 06/27/11 �� ' 12690' CTM 1 14-1/2" WFD CIBP (03/03/07) 1 2 -7/8" 6 11766 - 11791 0 06/2,6/11 0 2 -7/8" 6 12100 - 12150 C 11/13/08 iix,..0— 2 -7/8" 6 12480 - 12530 C 03/03/07 2 -7/8" 6 12880 - 12949 C 04/03/05 2 -7/8" 6 12950 - 12976 C 04/03/05 1 PBTD I 12987' �� i � * f ft � ' 1 14-1/2" LNR, 12.6 #, L -80, IBT- M. .0152 bpf, ID = 3.958" 1 13072' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/01/86 ORIGINAL COMPLETION 06/28/11 PBS/ PJC ADPERFS (06/26- 27/11) WELL: 03 -33B 04/30/97 SIDETRACK (03 -33A) 06/29/11 CJN/ PJC PERF CORRECTION PERMIT No: 205- 018 03/23/05 N2ES SIDETRACK(03 -33B) API No: 50- 029 - 21142 -02 05/30/10 MV /PJC EZ PLUG/ ADPERFS (05/26 - 28/10) SEC 11, T10N, R35E, 2658' FEL & 1515.13' FNL 02/11/11 MB /JMD ADDED SSSV SAFETY NOTE 02/11/11_ RCT /PJC _HES NIP ID CORRECTION BP Exploration (Alaska) • • SI EXTE ralF AELnZEn SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Josiah Igwe Petroleum Engineer O 1 g BP Exploration (Alaska), Inc. D\P P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Pool, PBU 03 -33B Sundry Number: 311 -150 Dear Mr. Igwe: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of May, 2011. Encl. STATE OF ALASKA 1��,(l F IVEI V4 ALASKAQAND GAS CONSERVATION COMMISSIO• 5 t : +U ° , �/ APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 i � ' 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well ❑`" a7(g "1Cp e P ro g ra � Suspend ❑ Plug Perforations ❑ Perforate El - Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ AcAtimulate - Alter Casing ❑ ❑ Other: 2. Operator Name: 4. Current Well Class: y. y, /. // 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 205 -0180 - 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0 , 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 21142 -02 -00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Spacing Exception Required? Yes ❑ No El PBU 03 -33B 9. Property Designation (Lease Number): 10. Field /Pool(s): ADLO- 028327 - PRUDHOE BAY Field / PRUDHOE BAY Pool - 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth ND (ft): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13072 - 8916.5 - 12987- 8916.5 - 11890, 12300, 12690 NONE Casing Length Size MD ND Burst Collapse Structural Conductor 77' 20" 91.5# H -40 33 110 33 110 1490 470 Surface 2474' 13 -3/8" 72# L -80 32 2506 32 2506 5380 2670 Production 9591' 9 -5/8" 47# L -80 31 9622 31 8024 6870 4760 Liner 7554' 7" 26# L -80 3018 10572 3016 8722 7240 5410 Liner 2681' 4 -1/2" 26# L -80 10391 13072 8589 8917 8430 7500 Perforation Depth MD (ft): Perforation Depth ND (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 27 10395 Packers and SSSV Type: 7" Baker ZXP Too Packer Packers and SSSV MD and ND (ft): 3018 3016 7" Baker ZXP Top Packer 9443 7895 4 -1/2" Baker S-3 Perm Packer 10338 8550 5" Baker ZXP Top Packer 10391 8589 12. Attachments: Description Summary of Proposal 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory p Development ❑ Service El 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 5/12/2011 Oil ❑ Gas ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑] - Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Josiah Igwe Printed Name Josiah Igwe Title PE Signature r` — Phone Date \,)wG.J 564 -4753 4/28/2011 Prepared by Joe Lastufka 564 -4091 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: 3 1 1 6 Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: Subsequent Form Required: /d • 1 10 -4 1 i APPROVED BY Approved by: MS MAY 0 4 201 C MISSIONER "Z THE COMMISSION Date: s J � R:. fIRIGINAL . Form 10-403 Revised 1/2010 /, G Submit in Duplicate 03 -36B 205 -018 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03 -36A 5/4/07 PER 15,010. 15,110. 9,047. 9,045.36 03 -36A 2/8/09 APF 14,490. 14,510. 9,045.95 9,046. 03 -36A 2/8/09 BPS 14,650. 15,110. 9,046.22 9,045.36 03 -36A 2/12/09 APF 14,460. 14,470. 9,045.9 9,045.92 03 -36A 2/12/09 APF 14,470. 14,490. 9,045.92 9,045.95 03 -36A 4/11/11 APF 14,355. 14,380. 9,045.7 9,045.81 03 -36A 4/11/11 APF 14,517. 14,542. 9,046.02 9,046.11 03 -36A 4/12/11 APF 14,330. 14,355. 9,045.61 9,045.7 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • • 03 -33B Adperfs /Mud Acid AFE #: APBD03WL33 To: J. Bixby/T. Norene Wireline Team Lead Date: Apr. 26, 2011 C.Olsen /R.Liddlow Well Services TL Ross Huebel Petroleum Engineer From: Josiah lgwe Wells Engineer AFE: APBD03WL33 -C Est. Cost: Subject: 03 -33Bi: Coil Adperfs and Mud Acid Stimulation IOR: 200 Operation Sequence: 1. S Slick Line retrieve 4.5" MCX plug and drift to max deviation 2. C Coil Flag, Adperfs and Mud Acid Stimulation 3. S Set 4.5" MCX plug 4. 0 POI Current Status: MI Last test: 02/28/2011: Less than 2000 bwpd, Injection Pressure at 3,100 psi Max Deviation: 93 deg @ 11,999' MD Last Downhole Op: 02/10/2011: S /Line set 4.5" MCX plug Last Tag 12/13/2010: 10,977' SLM Minimum ID 3.725" @ 10383' 4 -1/2" HES XN Nipple Last SBHP /SBHT: None, Estimated 3215 psi Latest H2S Value: N/A (Injector) Objective: The objectives of this job are to perforate 11652' - 11677', 11706' - 11731', and 11766' - 11791', acid stimulate the open perforated intervals, and return the well to MI injection. Well History: Well 03 -33A was sidetracked in March 2005 as a horizontal MI injector and benefits 9 -01, 9 -03, and 9 -27. The 4 -1/2" liner was cemented in place. The well is currently on its 4 set of injection perfs. The first three set of injection perfs were shot with CT and immediately followed up with an acid job and had good injectivity. The fourth set of perfs (50'), currently open, was shot on E -line tractor with no acid job. Injectivity in the well has been extremely poor ever since. Multiple attempts to inject into the well up to 4000 psi wellhead pressure have been unsuccessful. This 1 • • 03 -33B Adperfs /Mud Acid AFE #: APBD03WL33 program will re -perf 25' of the original 50', as well as add two more 25' perforated section both above and below the original perforations. Risk Discussion: Injection at up to 4000 psi into this well has been unsuccessful. It is doubtful there is any fill in this well above the plug because of a lack of injection in the well, but it is a possibility. If the well will not take any fluid, provisions must be made to flow back displacement volumes to run in the hole as well as any clean out that needs to be done to get to PBTD. Also, well has been completely locked up for recent pumping jobs. Contacts: Ross Huebel Production Engineer Office / Cell: 564 - 5779/832 - 455 -0275 Josiah Igwe Wells Engineer Office / Cell: 564 - 4753/590 -0610 S -Line Procedure 1. MIRU Slick Line • Load tubing with 270 bbls of diesel 2. Pull MCX from 4 -1/2" HES X Nipple @ 2206' and U.41-vJ 3. Drift to maximum deviation w/ 3 -3/8" Dummy Guns. Attachments: o Tie -in Log: SLB - GR/CCL/Temp/Pressure Log Dated:03 /01/2007 - page 7 o Tie -in Log cover copy — page 8 o Perforating procedure — page 9 o 03 -33i Well Bore Schematic — page 10 Coil Procedure: Drift 1. MIRU CTU 2. Make up BHA with PDS logging tool and 3.70" bull nose. • This will serve as a coil flag and a drift for 3 -3/8" gun 2 • • 03 -33B Adperfs /Mud Acid AFE #: APBDO3WL33 3. Open tree valves and RIH checking CT weight as required 4. Tag CIBP @ 11,890', PUH to 10' and begin log up hole at 60 fpm • If top of plug is not tagged POOH and PU 2.0" JSN to clean up to 10,890' 5. Flag pipe as required and continue logging up to 10,600'. • The reason for logging up to 10,600' is to get a good tie in at some of the tubing jewelry. 6. Wait 5 minutes for logging break. 7. POOH pumping CT displacement down backside 8. At surface LD logging tools, check for good data and calculate depth correction to shoot perfs. • Tie in Log : SLB, GR/CCLJTemp/Pressure Log Dated:03 /01/2007 CT Procedure: Adperfs. 1. MU tool string with Gun #1 SLB 25' gun 3406 PowerJet HMX, 6 SPF 60 deg phasing. o Note Max. diameter of gun in liquid/gas after shot is 3.6673.70 ". ( Make sure there is enough liquid at the shooting depths) o Tie in Log : SLB, GR/CCL/Temp/Pressure Log Dated:03 /01/2007 2. Run in Hole to flag for depth control. PUH and correct to top shot depth 3. Perforate interval (11766'- 11791') o Note any tubing pressure change in the AWGRS summary 4. At surface, makeup BHA #2 SLB 25' gun 3406 Powerjet HMX, 6 SPF 60 degree phasing 5. RIH to flag for depth control. PUH and correct to top shot depth 6. Perforate interval (11706' - 11731') 7. At surface, makeup BHA #3 SLB 25' gun 3406 Powerjet HMX, 6 SPF 60 degree phasing 8. RIH to flag for depth control, PUH and correct to top shot depth 9. Perforate interval (11652' — 11677') 10. POOH. 3 03 -33B Adperfs /Mud Acid AFE #: APBD03WL33 Acid Stimulation comments; • Filter all fluids that will enter the perforations to 3 microns absolute. • Obtain oil sample from offset producer and deliver to Schlumberger Well Services Lab for pre job emulsion /sludge testing. Allow 5 days prior to treatment due to tests that need to be done before pumping commences. • Monitor IA and OA pressures every 30 minutes during treatment and note on WSR. • Acid strength to be verified and documented via titration before leaving Schlumberger. Please note the acid titrations on the WSR and have results available on location. • Record time, rate, well head pressure, treating pressure, and annulus pressures in the WSR throughout the job. • Pump acid within 24 hours of mixing to ensure mixture homogeneity. • In general, pump job at maximum allowable or achievable rate /pressure. Scheduled rates are estimates only. Perforation Details Zone MDT MDB H Status 27 11652 11677 25 Open 27 11706 11731 25 Open 27 11766 11791 25 Open Total Footage: 75' Design Details: Wellbore Volume 178 bbls to top of pelf at 11,700' MD, 181 bbls to CIBP at 11890' Acid Design 30 gpf of 12% HCL and 30 gpf of 9:1 Mud Acid Foam Design basis 0.10 bpf, 70% foam quality Pres Estimated -3215 psi from offset producer CT Acid Treatment Procedure 1. Ensure the followings before starting this job: • Current MSDS for this job is onsite and acid safe handling procedures are followed • Ensure that the acid shower trailer is on site and functional • Keep out all personnel not associated with this job 2. MU CTU tool string with 2.00" JSN. 3. Load well by pumping down backside with -270 bbls (1.5 x wellbore volume) of 3% NH4CL (80 -110 degF) at 4 -5 bpm if possible while RIH. Note that injectivity in this well has been poor and it may not be possible to load the well without taking returns. 4 • • 03 -33B Adperfs /Mud Acid AFE #: APBD03WL33 4. Pump - 140 bbls of diesel to establish a positive -100 psi WHP. Note that well has not been taking injection and it may take very little volume to establish pressure. • Diesel must be pumped down the backside only. 5. RIH CT to tag CIBP at 11,890'. PU 10' and flag pipe. Establish injection test using 20 bbls of 3% NH4CL not exceeding 2000 psi WHP. 6. RU acidizing equipment. PT surface lines to 4500 psi. 7. Jet acid as per pumping schedule across the perforations down CT at maximum rate below 0.65 psi /ft gradient. • Reciprocate coil between intervals as per program. 8. Exceed frac. gradient if necessary to establish injectivity or complete the job, reduce pressure after injection is established. • Note: Maximum allowable treating pressure is 2000 psi. 9. Once over flush is out of the nozzle, displace tubing with 50 bbls of 3% NH4CL. o Note any increase in injection rate while over displacing. 10. POOH and freeze protect top of well with 38 bbls of 60/40 meth 11. RDMO. Mixing Recipe 50 bbls 9:1 Mud Acid Composition A264 Corrosion Inhibitor 6 Gal /Mgal A201 Inhibitor Aid 15 Gal /Mgal F103 Surfactant 2 Gal /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal U067 Mutual Solvent 50 gal /Mgal 50 bbls 12% HCI Composition A264 Corrosion Inhibitor 6 GaI /Mgal A201 Inhibitor Aid 15 Gal /Mgal F103 Surfactant 2 Gal /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal 5 I 03 -33B Adperfs /Mud Acid AFE #: APBD03WL33 Note: 3% NH4CL, 0.2% F103 and 2% U067 3% NH4CL, 0.2% F103 30 bbls 80:20 DAD 10% Composition H036 Hydrochloric Acid 10% A026 Xylene 10% A264 Corrosion Inhibitor 6 Gal /Mgal A201 Inhibitor Aid 15 Gal /Mgal F103 Surfactant 2 GaI /Mgal L058 Iron Control 20 Ib /Mgal W054 Antiemulsifier 5 gal /Mgal Note: Well has L -80 liner. Ensure correct additives are used. BHST 206 F. Inhibitor Package needs to be checked for 24 hours minimum protection time. Acceptable acid concentrations +/-1% for HCI. Fluids should be 90 -110 F. 3. Slick Line: ,rt • MIRU 0.3sg" _/ y. vi./( • Set MCX pat 2206' and 7 `" • RDMO 4. Pad Operator: To be monitored by WOE. • Put on MI Injection 6 M CO - _t— _ . = �. Cf) ° ' .:,: A NI = h Tie -In Log: Memory CCi CL a L min AM= m at= : Temperature /Pressure Survey `_ :_. -�__! . w - -1, � ® � = Dated: March 1, 2007 1.: AN . O imam ' " INA momollinn IN . ^,.« -in� 11652'-11677' s -- i -, = = l_ = : a welmmIlMmi I- iiiN s= :. •": _ ! E -'� _ � 1-- minmAra pi El t I I . . _ 9 __i___ ' - _I= c __: 11706 11731 - :_ ® _ i 4- ...„ . ... 7____t___J . • • 7 . rim 1 , _....; mim Ad Ma r . 7.:T.4 l a i= Emil cn -7� ` 1176 11791' hF ..� e .< ... # "" Mil i .._ CO ch O .r -, A • 0 03-33B Adperfs/Mud Acid AFE #: APBDO3WL33 ,,, sl,, sumougge 0 in ,', in — 3 i 9 6 6 • 0 2 0 2 7 Schlumberger 1 BP EXPLORATION (ALASKA). INC. 1 Final 1 1 • 03 i PRUDHOE B*Y ..... NORTH SLOE Slate. ALASKA _ .. --- Memory Temperature/Pressure Survey :, .. ; co I GR/CCUTEMP/PRESS cr , ...4 • ; I 01-March-2007 0 . 58 26 ' FEL & 1515.13' FNL Bev,: K.Q. 56.4 ft gi AT SURFACE G.L. 27.89 ft 2 ,.., 11. r..... i■,5 uj 0 Permanent Datum: MSL Elev . 0 t co 01 -------------- Log Measured From : B_... 56.4 ft above Perm. Datum _ __ F, 1 Drilling Measured From: RKB ______ o_ E 1 AP; Serial Kir. ! Sector I Towns I - ' Ran9e 50-029-21142-W I 11 10N 15E i 5 ] . de 144Pr- Rf I. ..._ _ ._ , _.. _______ -..... .................._ ....._ _ _........_ ...._ ...............,. .... . . . . _ _ _ ______ .- , I' 12967't _ •..... .. _._ .. _. ___.___ ..„ ___ ___ _ _ ,„ - ' 1 lnferval 12940 ft erval 10202 ft a Type - - - ---- TN - J*16""te Fu.115§ . ' " " - ' - - - - - - - — • - - --- ' .... ...... . ._____ .....__......_________.. . .... .. , 4G1TUBING STRING - . . •' ■ing_Size .i. 4 50C in 12.6 Ir'm!ft - -- - . ., __ rt 12987 ft tecorded Yes - -7 182 degF ( , -I: Bottom , Time 1-Mar-2007 19:07 ?r 1 Location 6125 I PRUDHOE BAY I 1 5y 1 GITHERTON 3tE -5 .........___ ---....; 8 ,, • • 03 -33B Adperfs /Mud Acid AFE #: APBDO3WL33 PERFORATING PROCEDURE • Well: 03 -33Bi API #: 50 -029- 21142 -02 Date: 4 /26/11 Prod Engr Ross Huebel Office Ph: 594- 5779 _....._......_.... ' ....._ H2S Level: Home Ph: ..._.._....... IN L Cell/Pager: 832 - 455 -0275 CC or AFE: APBDO3WL33 -C WBL Entries IOR Type Work Description 200 1 S ::Pull MCX. Drift and Tag 200 i C 'Adperf and acid slim 200 i S ;Run MCX Well Ob iectives and Pe rforating Notes: Add perfs and stint with acid in order to increase injectivity. Attachment: Tie -in log with proposed perfs annotated Reference Log Tie in Log Subtract 6' .._.._............ feet .......... Memory Log: MD Temp/Press from the tie-in log to be on Date: 3/20/2005 3/1/2007 depth with the reference log. Company: ,Sperry SLB (from -to) Depths (from -to) Feet SPF Orient Phasing Zone Ad/Reliperf 11,646' - 11,671 . 11 . ,652' . ,,...,.. - ,..11677' 25' 6 random 60° 27 Adperf 11„ - .... 1j725' ............... 1 ........ - 11 731' 25' 6 random 60° 27 ReVerf 11460' _ - 1 1 785' 1 1 766' - 11 791' 25',,. ,.,,.._ 6 random 60° 27 Adperf Requested Gun Size: 3 -3/8 Charge: „Power ,et 3408 Is Drawdown Necessary/Desired /Unnecessary During Perforating Unnecessar y ... ............................... Preferred Amount of Drawdown/Suggestions to Achieve Drawdown Last Tag: 70,977 ft RIG on 12/13/2010 Est Res. Pres.@ 8,800 MD is _ „_....._ 3215 psi Perforation Summary ` Summa Dist Well: 03 -33Bi __ Town: Date: API #: 50 -029- 21142-02 Prod Engr: ......... .._.._._ ...... I ' nch Prod Engr P.D. Center PBTD General Comments: Depths Balance Referenced to BHCS Gun Dia. Orient SPF Phasing Zone Adperf/Reperf 0 /8 /U 0 /B /U 0 /B /U 0 /B /U 0/Bill 0 /B /U 0 /B /U 0 /B/u 0 /B /U 9 v , 0 • 03-33B Adperfs/Mud Acid AFE #: APBDO3WL33 TREE= CfW SAFETY NOTES: WELL REQUIRES A SSSV 'WELLHEAD= /lc EVOY WIF_Al ON ML WELL ANGLE> 70* (I 10909'. I ACT1JATOR = AXEL SON 03-33 B , " W ELLBORE NOT SNOWN”. 114.8. ELEv = 56.40 I OF. ELEV = 27.89 I KOP = 9594 ,,... Ave = 93 @ 11999 I 2206' I-14-1.2' I-ES X NIP ID = 3.813' I I Datum 1.13 = 10762 'Datum TVD = 8803 SS I 13-3E' CSG, 720, L-80, ID = 12.347' H 2506' 6 3018' H9-5.8' X7 BKR DE LTP, ID = 6.290' ITOP OF 7' SCAB LNR H 3018' 3036' H9-543' X T BKR FLEX-L00( LIE HGR, 13= 6.310' I II; : Minimum ID = 3.725"" @ 10383' N ! 4-112" XN NIPPLE i44 V . 9444 9-5E' X 7* BoR C-2 2.XP LIP & TEBAOS SEAL ASSY, ID =6,151" o ■: i" , 17' SCAB LW, 261, L-83, sTr.,-M. ri 9453' k'' 9461' I-I 9-5,8' X r SKR FAC NCR, D = 6.280' I .0383 oaf, ID =6276" IWHPSTOCK (0312105) 9594' .LOUT WNDOW (03-33C) 9594' - 9622 Lay 0311205) H \ ; 1031T H4.1.2" HES X NIP, (3= 3.113'' I9-5/8" CSG, 47*, L-80, ID = 8.681' H 10374 I g." ;■: . 42 : ■,.. 10338' Hr x4-112" BKR 5-3 FRENROR, 13 = 3.875' I , . ,•eqj, 4. (04 % II S v 10362 I-14-1;2' I-ES X NE, ID= 3.813" I .. * 10383' H4-12" HES >N NE, ID = 3.725' 10391' T X 5' SIR ZYP LTPw;11133K. ID= 4A501 10395' FI4-1/2' ALM, ID = 3.958" I4-1.2" TBG, 12.6*, TC- 11, .0152 tot. ID = 3.958' H 10395' .. .. 1 10409' r X S' BKR OLIC HYDRO INRHGRI) = 4.430' IT LtR., 26*, L-80, BTC-M, .0383 bpf. .13 = 6.276' 10572' 10417' 1-15* X 4-112' XO, ID = 3.980' X .....- 11890' H4-112' HES EL GRILL 105128110 I .4.- FERFCRATION SUP.S1ARY REF LOG: SSEAROGRROP ON 0312005 Illk 12300' CTM 4-IT WFI3 CEP (11112)08) A NGiLE AT TOP FERF: 91 @ 11700' _......-- Nzie: Ref et to Poox ton � foe bestomai pf aata 1 269 CW ;2 NFL) CEP (0G.031 11 SEE SPF KreivAL OpftSciz DATE 2-718' 6 12100- 12150 0 11; 13,08 2-718' 6 11700 - 1 1750 0 05128.10 2-718" 6 12480 - 12530 C 0343,07 2- 718' 6 12880 - 12949 C 0410105 FEID • •": 2-74r 6 12950 - 12976 C 04e3.435 1298T 14-1,2' LON, 12.6*, L-80, ET-I& .0152 bpf, (1= 3.958' 13072' DATE RE/ BY oce.t.efrs DATE REV BY CONRENTS FRUDHOE BAY UNIT 0101/08 ORIGINAL COMPLETION 11120/08 DO.ErfLH FERFS & RUG SET (11;1208) WELL: 133-338 04130/97 SEETRACK (03-33A) 05133110 MV.PJC EZ FLUG ADPERFS (0512810) PEFAIT No: 205- 018 03123105 N2E5 SEETRACK (03-338) 02/11;11 NEU PAD ADDED SSSV SAFETY NOTE API No: 50-029-21142-02 04,03 V PJC PERFORATIONS (SCITFOCK B) 0211/11 RCT;PJC I-ES NIPID CORRECTION SEC 11. T 1 ON R35E, 2658 FE- & 1515.13 RA_ 01:10107 JA F.PJC DFLG DRAFT CORRECTION 010107 GLUT LH C BP SET f ACPERFS BP Expioraton (Alaska) 10 STATE OF ALASKA ALASKA LAND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other ^ Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ Change Approved Program ^ Operat. Shutdown ^ Perforate ~ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ^ Exploratory ^ 205-0180 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ .API Number: Anchorage, AK 99519-6612 50-029-21142-02-00 8. Property Designation (Lease Number) : 9. Well Name and Numbe ADLO-028327 PBU 03-33B 10. Field/Pool(s): ~ PRUDHOE BAY FIELD / PRUDHOE BAY POOL 11. Present Well Condition Summary: Total Depth measured 13072 feet Plugs (measured) 12690 12300 feet 11890 true vertical 8916.5 feet Junk (measured) None feet Effective Depth measured 12987 feet Packer (measured) 10338 true vertical 8916.5 feet (true vertical) 8550 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" 91.5# H-40 SURFACE - 110 SURFACE - 110 1490 470 Surface 2506 13-3/8" 72# L-80 SURFACE - 2506 SURFACE - 2506 5380 2670 Intermediate Production 9594 9-5/8" 47# L-80 SURFACE - 9594 SURFACE - 8004 6870 4760 Liner 7554 7"26# L-80 3018 - 10572 3016 - 8722 7240 5410 Liner 2661 4-1/2" 12.6# L-80 10391 - 13072 8589 - 8917 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# TC-11 ~ SURFACE - 10395 SURFACE - 8592 Packers and SSSV (type, measured and true vertical depth) ~ " ~~ 7"X4-1/2" BKR S-3 PREM BKR ,.,~ 10338 8550 RE~ElVED 12. Stimulation or cement squeeze summary: ~(JN Intervals treated (measured): a-. z ^ ~ ''' ~~~i y ~ ` ~ 'a" Alasks Oi! Et Gay Guts. Commission y »~. Treatment descriptions including volumes used and final pressure: ~I10~~~g~l 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 6675 1742 Subsequent to operation: 10000 1897 14. Attachments: 5. Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^ Service Q Daily Report of Well Operations X .Well Status after work: Oil Gas WDSPL GSTOR ^ WAG ^~ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sund ry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre a Title Data Management Engineer Signature Phone .564-4944 Date 6/28/2010 i unn ~u'~u~ i~gv wcu ~icuva -" _.' __ ~~.~~~ ~~~ ~ v~..v~. u. v~.y.~~c.. v..~~ 03-33B 205-018 DFRF ~TTA('_HMFNT u Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-33B 4/3/05 PER 12,880. 12,949. 8,916.47 8,916.48 03-336 4/3/05 PER 12,950. 12,976. 8,916.48 8,916.5 03-336 3/2/07 APF 12,480. 12,530. 8,915.79 8,915.55 03-33B 3/2/07 BPS 12,690. 12,976. 8,916.83 8,916.5 03-33B 3/3/07 APF 12,480. 12,530. 8,915.79 8,915.55 03-33B 11/13/08 BPS 12,300. 12,310. 8,920.84 8,920.56 03-33B 11/13/08 APF 12,130. 12,150. 8,924.5 8,924.13 03-33B 11/13/08 APF 12,100. 12,110. 8,925.08 8,924.88 03-33B 11/13/08 APF ~ 12,110. 12,130. 8,924.88 8,924.5 03-33B 5/26/10 BPS 11,890. 11,891. 8,933.05 8,933.02 03-33B 5/26/10 APF 11,725. `~ 11,750. 8,938.81 8,938.15 03-33B 5/27/10 APF 11,700. 11,725. 8,939.36 8,938.81 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • i • 03-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/25/2010. ~**WELL SHUT-IN UPON ARRIVAL*** ~ .INITIAL T/I/0= 150/0/0 i DRIFT RUN WITH 3.66" SWEDGE. JEWELRY LOG ALSO RUN. 10280'-11940'. ***JOB CONTINUED ON 26-MAY-2010*** 5/26/2010'`**JOB CONTINUED FROM 25-MAY-2010*** RIH WITH 4.5" HALLIBURTON EZ DRILL PLUG. SET DEPTH 11890'. I PERFORATE INTERVAL: 11725 - 11750 FT. POOH AND HANG UP IN TIGHT SPOT AT 4820 FT CCL DEPTH. TRACTOR DOWN, LINE UP LRS WITH SAFELUBE. PUMP SAFELUBE AND FREEZE PROTECT. }***JOB IN PROGRESS AND CONTINUED ON 27 MAY 2010*** 5/26/2010 T/I/O =Vac/0/0/ Assist E-Line with pumping down Tubing; 5 bbls meth„ 100 bbls of Xtra Slick, and 28 bbls meth. ***Job in progress, Continued on next day*** 5/27/2010 **Job in progress*** (Assist E-line) Continue to pump 9 bbls meth down Tubing for freeze~rotect. E-line has control of well u on departure. FW HP_'s=100/0/0. 5/27/2010 ***JOB CONTINUED FROM 26-MAY-2010*** (ELINE - PERF) DRIFT WELL WITH 20' - 2.875" SPENT GUN AND 20' 3.375' SPENT GUN TO 10987' AFTER PULLING TIGHT ON PREVIOUS GUN RUN WHILE POOH. PERFORATE INTERVAL FROM 11700'-11725' WITH 2906 PJ HMX. GUN CONVEYED USING WELLTEC TRACTOR. FINAL T/I/O=0/0/0 ***JOB COMPLETE*** FLUIDS PUMPED BBLS 3 meoh 3 diesel 6 Total TREE _ „- CfW WELLHEAD= McEVOY ACTUATOR = AXELSON KB. ELEV = 56.40' BF. ELEV = 27.89' KOP = 9594' Max Angle = 93 @ 11999' Datum MD = 10762' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" I- j 2506' ~- TOP OF 7" SCAB LNR 3018' Minimum ID = 3.725"" @ 10383' 4-1/2" XN NIPPLE 7" SCAB LNR, 26#, L-80, BTGM~ 9453' 0383 bpf, ID = 6.276" WHIPSTOCK (03112!05) (-~ 9594' Ezsv (o3n2/a5)~--(- 9646' SAFET ES: WELL ANGLE> 70° @ 10909' O ~ -~ ~ ~ '"`*PA WELLBORE NOT SHOWN""" 2206' I--14-112" HES X NIP, ID = 3.83" 301$-~ 9-5/8" X 7" BKR ZXP LTP, ID = 6.290" I 3036' 9-5l8" X 7" BKR FLEX-LOCK LNR HGR, ID = 6.310" 9~~ 9-518" X 7" BKR G2 ZXP LTP & I TIEBACK SEAL ASSY, ID = 6.151" 9461' ~ 9-5/8" X 7" BKR HMC HGR, ID = 6.280" MILLOUT WINDOW (03-33G) 9594' - 9622' 10317' -14-1/2" HES X NIP, ID = 3.813" 10~ 7" X 4-1 /2" BKR S-3 PREM PKR, ID = 3.875" ~ 9-5/8" CSG, 47#, L-80, ID = 8.681" I-( 10374' ~4-1/2" TBG, 12.6#, TG11, .0152 bpf, ID = 3.958" ~ 7" LNR, 28#, L-80, BTGM, .0383 bpf, ID = 6.276" I PERFORATION SUMMARY REF LOG: SSEWRlDGR/ROP ON 03/20105 A NGLE AT TOP PERF: 91 @ 11700' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7i8" 6 12100 - 12150 O 11/13/08 2-7i8" 6 11700 - 11750 O 05/28/10 2-7/8" 6 12480 - 12530 C 03!03/07 2-7l8" 6 12880 - 12949 C 04/03/05 2-7/8" 6 M362~~ 4-112" HES X NIP, ID = 3.813" I 10383' 4-1/2" HES XN NIP, ID = 3.725' 10391' 7" X 5" BKR ZXP LTP w (fIEBK, ID = 4.4: 10395' 4-1/2" WLEG, ID = 3.958" 10409' 7" X 5" BKR HMC HYDRO LNR HGR, ID = 4.430" 10417' S" X 4-1i2" XO, ID 3.980' 11890' 4-1/2" HES Q DRILL (05/28/10} 12300' CTM 4-1/2" WFDCIBP(11/12/08) 12690' GTM 4-1/2" WFD CIBP (03/03/07} 12950 - 12976 C 04(03/05 L ~~ 4-1/2" LNR, 12.6#, L-80, IBT-M..0152 bpf, ID = 3.958° 12987' 13072' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/01/86 ORIGINAL COMPLETION 11/20/08 DMS/TLH PERFS & PLUG SET (11/12/08) 04/30/97 SIDETRACK (03-33A) 05!30/10 MV/PJC EZ PLUG/ ADPERFS (05/28/10) 03/23/05 N2ES SIDETRACK (03-338) 04/03/05 ?/ PJC PERFORATIONS (SDTRCK B) 01/16/07 JAF/PJC DRLGDRAFTCORRECTION 03/03(07 GLMITLH CIBP SET / ADPERFS PRUDHOE BAY UNIT WELL: 03-336 PERMfT No: 205- 018 API No: 50-029-21142-02 SEC 11, T10N, R35E, 2658' FEL & 1515.13' FNL BP Exploration (Alaska) • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: r, ~ DATE: Monday, December Ol, 2008 Jim Regg ! ~ ~ i ~ ZC P.I. Supervisor YI~"%~~ Jw SUBJECT: Mechanical Integrity Tests `` t BP EXPLORATION (ALASKA) INC 03-33B FROM: Chuck Scheve PRUDHOE BAY WIT 03-33B Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed B P.I. Suprv ~~~ Comm Well Name• PRUDHOE BAY UNIT 03-33B Insp Num: mitCS08 1 125071 536 Rel Insp Num: API Well Number 50-029-21142-02-00 Permit Number 205-018-o Inspector Name: Chuck Scheve Inspection Date• 11/24/2008 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ~ 03-33B ,Typo InJ• ~ W ~ TVD ~~ 5550 ~ IA ~ 90 ~ 2500 ~ P T• ~ 2osolao iTypeTest SPT ~ Test psi ~ z13~s ~ pA ~ 90 loo ~ I ~' Interval or1~R p~F F ~ Tubing ~ I9so ~ I9so I ( I ~- Notes' Test prior to MI swap. Test aborted due to multiple leaks on casing head gland nuts. ~~~~~~~` ~~P~ ti «. BOG Monday, December O 1, 2008 Page 1 of 1 ~~ a._„. ~Y - . ~` ~~ ~` STATE OF ALASKA `~~~ ALA OIL AND GAS CONSERVATION COM101 f 'vE'..~ ~-~ REPORT OF SUNDRY WELD,, ~F7~Q~IS 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~ acid treatment Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver[] Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development r Exploratory 2o5-oleo ' 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~' ~ 6. API Number: Anchorage, AK 99519-6612 50-029-21142-02-00 7. KB Elevation (ft): 9. Well Name and Number: 56.39 KB ~ PBU 03-33B 8. Property Designation: 10. Field/Pool(s): ADLO-028327 ~ Prudhoe Bay Field/ Prudhoe Bay Pool 11. Present Well Condition Summary: ~~~~~ \~~i'3~C9 Total Depth measured 13072 ° feet Plugs (measured) 12690' 3/3/07 ~~ true vertical 8916.5 - feet Junk (measured) None Effective Depth measured 12987 ° feet `' ~4;~~a`~~~.-::- ~~~~ ~~ ~x ~~~~% true vertical 8916.5 feet Casing Length Size MD TVD Burst Collapse Conductor 110' 20" 91.5# H-40 Surface - 110' Surface - 110' 1490 470 Surface 2506' 13-3/8" 72# L-80 Surface - 2506' Surface - 2506' 5380 2670 Production 9594' 9-5/8" 47# L-80 Surface - 9594' Surface - 8004' 6870 4760 Liner 7554' 7" 26# L-80 3018' - 10572' 3016' - 8722' 7240 5410 Liner 2681' 4-1l2" 12.6# L-80 10391' - 13072' 8589' - 8917' 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# TC-11 SURFACE - 10395' 0 0 - Packers and SSSV (type and measured depth) 7"x4--1/2" bkr S-3 PREM BKR 10338' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 9967 1677 Subsequent to operation: 6079 1874 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development r Service ~" Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG ~' GINJ rr WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 11/24/2008 ~. Form 10-404 R~~d~4?/2~~ ~ ~~ ~ ~ ~ , ~,,~~ ~ ~~~ a ,~~o~f- ~ `~ - Submit Original Only ~_. t,, ~ ,,~. ~~ 03-336 205-018 PERF ATTACHMENT • Sw Name Operation Date Perf Operation Code - -- Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-33B 4/3/05 PER 12,880. 12,949. 8,916.47 8,916.48 03-33B 4/3/05 PER 12,950. 12,976. 8,916.48 8,916.5 03-33B 3/2/07 APF 12,480. 12,530. 8,915.79 8,915.55 03-33B 3/2/07 BPS 12,690. 12,976. 8,916.83 8,916.5 03-336 3/3/07 APF 12,480. 12,530. 8,915.79 8,915.55 03-336 11/13/08 APF 12,100. • 12,110. 8,925.08 8,924.88 03-33B 11/13/08 APF 12,110. ,/' 12,130. 8,924.88 8,924.5 03-33B 11/13/08 APF 12,130. ~/ 12,150. 8,924.5 8,924.13 03-33B 11/13/08 BPS 12,300. ~ 12,310. 8,920.84 8,920.56 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • U 03-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 11/11/2008 CTU #6 w/1.75" OD CT. Add/Pert. MIRU. Job Continued on 11/12/08 WSR. 11/12/2008 Assist coil Freeze protect F/L .Pumped 70.4 bbls 60/40 meth water down F/L .from lateral line back to well. Final F/L PSI=2000 Lateral valve flagged & tagged DSO notified upon departure ~~ . , _. _ _ . _ _ _._ __.._ ___ _. _ __.__M__.. __. 11/12/2008 CTU #6 w/1.75" OD CT. Add Perf. Job continued from 11/11/08 WSR. ~ ' «InterAct Publishing» RIH w. Weatherford 3.6" O.D. Drift and gauge tubing !to 12400' CTM freeze protect flo-line with 70 bbls 60/40 meth. `~*job continued ' on WSR 11-13-08*'" __. - 11/13/2008 CTU #6 w/ 1.75" CT. Add Perf; Job continued from 11/12/08. «InterAct Publishing» RIH w/ 3.563" (DB1 CIBP. Set @ 12300' CTM Tested CIBP to 3000 psi on tubing. RIH w. 2.88 HSD 2906PJ Omega 6 shots per/ft 60 deg. ;phasing. Used CIBP for depth control during pert runs. Perforate 12100'- 12150' CTM Note: all depths are coiled tubing depths. No correlation log used to tie-in due to large window per town APE's ... Cont' on WSR 11/14/08 ... ~ 11/14/2008 CTU #6 w/ 1.75" CT. Add Perf /Acid Stim; ... Cont from WSR 11/13/08 ... Con't POOH with last gun run. MU and RIH with 2.5" JSN. Pump 25 bbls of 25 bbls - 80:20 12% DAD Acid followed by 25 bbls of 9:1 Mud Acid and overflush with 50 bbls of 3% NH4CL across interval 1 2070-1 21 80' md. Observed an initial 500 psi breakdown as HCL hit the perfs followed by a continual breakdown as mud acid hit the perfs. Initial injectivity = 0.9 bpm at 2000 psi. Final injectivity = 1.6 bpm at 821 psi. RDCTU and hand well over to DSO to put on injection **`Job Complete""` -- FLi JIDS PUMPED BBLS 70 DIESEL 54 METH 25 9:1 Mud Acid 25 80:20 12% DAD 50 3% NH4CL 224 Total Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, December 23, 2008 4:19 PM To: 'Preble, Gary B (SAIC)' Subject: DS 03-33B (205-018) Gary, I am reviewing the 404 for the work recently accomplished on this well. The CIBP set at 12300' on 11/13 is not Listed on the front of the 404. I have made that notation. You might add that to your copy. No need to send in another 404. Tom Maunder, PE AOGCC 12I23I2008 • MEl®'I®RANDUM To: Jim Regg ~ ~ ff P.I. Supervisor ~C~CI ~ ~~`~'~~(L~~' t FROM: Bob Noble Petroleum Inspector • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, December 03, 2008 SUBJECT: Mechanica] Integrity Tests BP EXPLORATION (ALASKA) INC 03-33B PRUDHOE BAY UNIT 03-33B Src: Inspector NON-CONFIDENTIAL Reviewed Br P.I. Suprv ~2--- Comm Well Name: PRUDHOE BAY UNIT 03-33B Insp Num: mitRCN081202143513 Rel Insp Num: API Well Number: 50-029-21 I42-02-0o Permit Number: 205-ots-o Inspector Name: Bob Noble Inspection Date: I2~Ii2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well ! 03-33B !Type Inj. W TVD j 8550 ~ IA ii 30 ~ 4000 X 3890. 3870 i ~ P.T. ', zosotso IiTypeTest SPT ~~ Test psi ';; aooo ~~ OA I o ~ Io ~ ~ Io ~ Io OTHER P Interval P/F / TUbing 140 ~ 140 ~ _ ~ ]40 140 ~_ ~ NOteS' MIT-IA to 4000 psi pre MI swap. I had q uestions if this well was on ]ine becouse the tubing psi was so low and I was told it was on line. ~v~~ ~~~ ! ~ ~1~~ Wednesday, December 03, 2008 Page 1 of 1 • ALASKA OIL A1~TI) GA5 CO1~T5ERRA7`IOAT COl~'II~IISSIOI~T Chris Colbert BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 • SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-33B Sundry Number: 308-384 O>\~ r ~~~. Dear Mr. Colbert: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may 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, Cathy P. Foerster Commissioner ~^' DATED this day of October, 2008 Encl. ~~~,~ ~ ~ ~ (~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ~Y_:cy~. APPLICATION FOR SUNDRY APPROVAL I~`'~~~? ~ ~ 20~~ 1. Type of Request: Abandon Suspend Operational shutdown Perforate ~ - aive ~°° ~ ~' Alter casing ^ Repair well ^ Plug Perforations^ Stimulate Q -Time Extensi~+ ~~~~~ Change approved program ^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl^ Exploratory ^ 205-0180 ~ 3. Address: P.O. Box 196612 Stratigraphic^ Service ^~ 6. API Number: Anchorage, AK 99519-6612 50-029-21142-02-00 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 03-33B ~ Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): ADLO-028327 ~ 56.39 KB ~ Prudhoe Bay Field / Prudhoe Bay Pool 11 • PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13072 , 8916.5 _ 12987 - 8916.5 - 12690' 3/3/07 NONE Casing Length Size MD TVD Burst Collapse Conductor 80 20" 91.5# h-40 30 110 30 110 1490 470 Surface 2475 13-3/8" 72# I-80 31 2506 31 2506 5380 2670 Intermediate 9562 9-5/8" 47# I-80 32 9594 32 8004 6870 4760 Liner 2985 7" 26# I-80 3018 10572 3016 8722 7240 5410 Liner 2681 4-1/2" 12.6# L-80 10391 13072 8589 8917 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4-1/2" 12.6# TC-11 SURFACE - 10395' Packers and SSSV Type: 7"X4-1/2" BKR S-3 PERM PKR Packers and SSSV MD (ft): 10338' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ^ Service ^~ - 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/5/2008 OIL ^ GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^~ - GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Chris Colbert Printed Name hris Colbert Title PE ~ Signature ~ ~ Phone 564-5135 Date 10/22/2008 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~~ ~& Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: Subsequent Form Required: APPROVED BY ~ ' ~ + A d b pprove y: COMMISSIONER THE ~ Date: S ~ ~ ~ ~ - - v .. ~.,. ii E . :~ ~~. ~ Form 10-403 Re sed 06/2006 # - ~ ~-. ~ ~UF3tnit in Duplicate f~~4 03-336 205-0180 PFRF ATT~[_HMFNT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 03-338 4/3/05 PER 12,880. 12,949. 8,916.47 8,916.48 03-33B 4/3/05 PER 12,950. 12,976. 8,916.48 8,916.5 03-33B 3/2/07 APF 12,480. 12,530. 8,915.79 8,915.55 03-33B 3/2/07 BPS 12,690. 12,976. 8,916.83 8,916.5 03-33B 3/3/07 APF 12,480. 12,530. 8,915.79 8,915.55 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED _ FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~~, • • To: Jerry Bixby /Clark Olsen GPB Well Ops Team Leaders From: Chris Colbert DS 03 & 17 Production Engineer Subject: DS 03-33Bi CIBP, Perf, and Acid Stimulation PBD03WL33-C Capacity Sustainment Please perform the following steps: 1. S: Pull MCX Valve. Drift and tag with dummy gun (pre-adperf) 2. C: Set CIBP, AdPerfs, Injectivity test, Acidize 3. S: Set MCX valve Max Deviation: Prop Plug Deviation: Prop Adperf Deviation Min. ID: Last TD tag: Last Downhole Ops: Latest H2S value: Tie-in/ PDC Log: OBJECTIVE 93° 0 11999'MD 92° 91° 3.725" 0 10383' MD, 4-1/2" XN Nipple 03/03/07: 12678' CTMD tagged CIBP 04/21/07: Pulled PX-plug 010,366' SLM. No Data - DS03 is an H2S Site Sperry-Sun EWR/DGR/ROP - 03/20/2005 Date: October 15, 2008 Est. Cost: $150M IOR: 500 The purpose of this procedure is to add a third set of injection perforations to start the next MI bulb for well 03-33Bi. An acid stimulation procedure will be used to help improve Injectivity. WELL HISTORY Well 3-33Bi is a MI injector in Zone 2 drilled in March 2005. It has 4-1/2" L-80 tubing with open perforations at 12480'-12530'. The plan for this well is to have a minimum of 4 sets of perfed injection intervals each set separated by a CIBP. MI will be injected into each set with each "plug- perf-MI injection" cycle lasting 1-2 years. This will be the third set of perforations added since the side track was completed in March 2005. Please contact Chris Colbert at 564-5135 (office) or 306-2465 (cell) or Jennifer Julian at 564- 5663 (office), 274-0929 (home) or 240-8037 (cell) with any questions or comments. Note: Jennifer Julian's cell phone may not work from the coil tubing unit so you may have to use an alternate line to call her. cc: w/a: 03-33B Well File Chris Colbert • • PREP iNORK: 1. Pull MCX valve from 4-1/2" HES X NIP @ 2206' MD. 2. Drift and tag as deep as possible with 2 7/8" dummy gun. CT OPERATIONS: Note: *Memory log is not required for CIBP setting or perf job due to large window **25' Power Jet Omegas were used for the previous perforations 3. SI PW Injection. RU CT. 4. Make CTU drift run with nozzle to 12,400' ctmd prior to running the CIBP. 5. RIH with 4-1/2" CIBP and set at 12300' CTMD while POH. P-test the CIBP to 3000 psi ~ 6. RIH and perforate with 2-7/8" Powerjet Omegas, 6 SPF from 12100' - 12150' CTMD. Memory depth control log not required due to large window. 7. Do infectivity test by pumping down 4 ~/z" tubing Q max rate at 2000 psi. Establish stable rate and pressure. • • Acid Job 8. RU nozzle BHA. RIH for perf wash. Make multiple passes (12,070' - 12,180') across the perfs and pump the following at maximum rate with a recommended maximum WHP of 2000 psi (*). Don't POOH until the entire overflush has been pumped behind pipe in order to reduce the chance of stirring up schmoo. 25 bbls 12% 80:20 DAD Acid 0.5 % A261 Inhibitor 4.0 ppt A179 Inhibitor Aid 8.0 ppt A153 Inhibitor Aid 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Preventer 1.5 % U074 Dispersing Agent/Emulsifier 20.0 % A026 Xylene 25 bbls 9:1 Regular Mud Acid 0.5 % A261 Inhibitor 0.5 % A201 Inhibitor Aid 0.2 % F103 Surfactant, EZEFLO 20.0 ppt L058 Iron Stabilizer 0.5 % W054 Non-Emulsifying Agent 0.5 % W060 Sludge and Emulsion Pre 50 bbls 3% NHaCI 4 0.2 % F103 Surfactant, EZEFLO 10.0 % U067 Mutual Solvent • * Go to 3000 psi if necessary to establish injection. Once acid is at the perfs, the maximum treating pressure should be 2000 psi or you will frac the acid away • DO NOT bring acid to surface due to likely H2S formation. • All fluids should be filtered to 3 microns. Treatment Design: 1) 25 bbls 12% 80:20 DAD Acid 0.5 % A261 4.0 ppt A179 8.0 ppt A153 0.2 % F103 20.0 ppt L058 0.5 % W 054 0.5 % W060 1.5 % 0074 20.0 % A026 2) 25 bbls 9:1 Regular Mud Acid 0.5 % A261 0.5 % A201 0.2 % F103 20.0 ppt L058 0.5 % W 054 0.5 % W 060 3) 50 bbls 3% NHaCI 4 0.2 % F103 10.0 % U067 Please note the acid titrations and iron ppm on the WSR. 9. POOH. RDMO. Put on PWI injection. 10.SL: Set MCX Valve in 4'/2" HES X NIP C«~ 2206' MD Well: ...... 03-338 ..................... . Date : ..... ................ ........10/15J2008 Cost Est: . ..... S150M ...................................... CC or AFE: ...... PBD03WL33-C ...................................... PERFORATING PROCEDURE API #: 50.029-21142-02 Prod Engr ..............Chris Colbert_______ ....... Office Ph:..... 564-5135 Home Ph: ...._.._ ..... Cell/Pager: ...................... 306-2465 WBL Entries Ver 12. Rev 10/21/01 ..... H2S Level:.____ NA IOR Type Work Description S ~ ;'Pull MCX Valve E ......................................................................................................................................................................................... 500 i C i :Set CIBP; Adperf, Injectivitytest: Acidize i S 'Set MCX Valve Well Ob'ectives and Perforatin Wotes: The purpose of this procedure is to add a third set of injection perforations to star) the next MI bulb for well 03-3361. An aad stimulation procedure will be rued to help improve infectivity Attachment: Reference log with proposed perfs annotated, 5"/100' scale Reference Log Tie in Log Add/Subtract 0 feet Log: EWR/DGR/ROFEWR/DGR/ROP ...................... to the tie•in log to be on Date: 3/20/2005 3/20/2005 ., depth with the reference log. Company: sperrx.sun Sperry-suri._. Depths (from-to) Depths (from-to) Feet SPF Orient. Phasing Zone AdlRelperf ...12:100'.,. ,..._12,150'... _..12,100'.__. -...12,150' 50' ..............6...__..._._.... No 60° 42P Adperf Requested Gun Size: 2 7/8" Charge: Power Jet Omesa 2906 HMX Is Drawdown Necessary/DesiredNnnecessary During Perforating Unnecessary Preferred Amount of Drewdown/Suggestions to Achieve Drawdown Last Tag: ....,12r678.....,ft MD on .__3/3/2007... Est Res. Pres. (a _.___.12.150....__ MD is ______________3350 psi Perforation Summary welh o3-33B Date: API #: 50-029-21142-02 General Conunerrts: Depths Balance Based on Ref Log Gun Dia. Orient. SPF O/8/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - O/B/U - • • Reference Log: • WSR WELL SERVICE REPORT • WELL 03-33B JOB SCOPE PERFORATING UNIT CTU #5 DATE 3/3/2007 DAILY WORK PERFORATING DAY SUPV BU R N ETT COST CODE PLUS PBD03WL33-C KEY PERSON DS-TRASK NIGHT SUPV MURPHY MIN ID 3.725 " DEPTH 10383 FT TTL SIZE 4.5 " DAILY SUMMARY CTU #5. Add Perf / Acidize. *** Continued from WSR 03/02/2007 *** RU BHA #5 2.75" PJOmega 2906 6spf perforating gun. RIH to CIBP. Correct top shot to CIBP. PUH to firing depth (12480' - 12505'). Fire guns with 1/2" aluminum ball. Good indication of firing. POOH. All shots fired. MU JSN BHA. RIH and tag CIBP C~ 12678' ctmd. Correct to CIBP. Initial infectivity was 1.7 bpm C~3 1700 psi. Begin pumping 25bbls 12% DAD, 25bbls 9:1 Mud Acid, 50bbls 3% NH4CL with F103 and U67. Overdisplace fluid with 315 bbls of 3% NH4CI .POOH laying in 3% NH4CI while freeze protecting CT. *** Continued on WSR 03/04/2007 *** LOG ENTRIES Init T b , IA, OA 41 0 0 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:00 0 *** Continued from WSR 03/02/2007 *** Making up to wellhead with Gun run #2 00:11 0 5m Online with 60/40 meth to re for PT 00:15 0 211 4 8 Be in LPT 00:18 0 208 4 Ram to HPT 00:19 0 1550 4 Be in HPT 00:23 0 1450 4 HPT com lete, bleed down and re too en well 00:32 0 0 5 O en swab, RIH, IAP = 0 si, OAP = 0 si 01:23 5011 556 0 Wei ht check 11.4k u , 6.Ok down 02:08 10000 692 0 Wei ht check 19.5k u , 10.2k down 02:46 12660 690 0 Wei ht check rior to to in lu 21.5k u , 11.2k down 02:50 12680 459 0 Tag top of plug (12674' up depth at 21.5k weight) mechanical counter at 12714' 02:58 12674 130 0 6' off top of plug, correct to top shot depth (12683' - 26.83') =corrected depth of 12656.3 03:00 12653 108 0 *** All de the now reference to shot on remainder of this run 03:05 12480 77 0 At to shot de th, PJSM to dro 1/2" aluminum ball 03:10 12480 47 0 Pre to dro ball, line u to take returns throu h choke 03:25 12480 44 910 1.5 0 Online with 60/40 meth, ball confirmed rollin 03:43 12480 62 1097 0.7 26 Reduce rate to land ball 03:51 12480 65 1200 0.7 31.4 Ball on seat 03:53 12480 45 3200 0 32.7 Good indication of guns firing, shut down pumping, pickup clean 22.Ok up, POOH 03:57 12101 0 0 35/Od Freeze rotect lines out to Ti er tank with 60/40 meth with 2 bbls 03:59 11865 0 0 0.3 Od Online with diesel down backside 05:25 200 210 0 0 31 Shut down um ,continue POOH 05:30 -17 0 0 Ta u at surface, close swab, bleed down, hold PJSM for breakin off uns 05:46 0 CT crew on location for chan eout 06:10 0 All shots fired, continue ri in off tools 06:30 0 Ball recovered from firin head 07:00 0 Co Re chan a-out 07:18 0 Re lace seal in reel swivel before acid 'ob 07:59 0 Reel swivel re-built, be in makin u Acid BHA 09:00 0 Pull test connector to to 10k 09:45 0 Pressure test connector to 3500 si ood 10:37 0 297 LPPT on well(good) • • 11:51 0 ~ Fluid ack for ressure test on well 12:00 0 4011 HPPT on well ood 12:29 0 Test down hole check valves to 1500 si ood 12:38 0 Om Be in um in 60/40 methanol down backside for in'ectivit test 12:47 0 8 Establish in'ectivit at .7b m and 1800 si 12:54 0 RIH with nozzle for acid job: CRC, 1" X .08', DCV 2" x 1.16', STGR 2.0" x 5.75', STGR 2.0" x 5.75', XO 2.0" x .25', JSN 2.80" x .6'. OAL = 13.59' 13:53 5000 725 37 WT ck 11 k, riw 14:26 7500 629 33 WT ck 14.5k 15:03 10515 578 34 WT ck 20k 15:33 12500 802 33 WT ck 21 k 15:49 12678 413 31 Ta CIBP , uh to et wei ht back 15:52 12679 Re-confirm to uh to et wei ht back 15:53 12671 181 Correct coil de th to CIBP 12689' , -18' correction 15:56 12689 77 On Pum coil volume of NH4CL 16:04 12689 43 2608 2 Hold 'sm and THA with coil crew and acid um in crew 16:29 12654 -5 -4 35 Freeze protect coil pump with 60/40 methanol, line up pumpers to pt surface lines 16:42 12562 90 -15 3 Coil um freeze rotected 17:01 12560 39 726 Fluid ack for t of um ers iron 17:04 12560 428 34 PT cementers line to 4000 si ood 17:09 12560 387 806 Oa Be in um in 25bb1 DAD acid 17:11 12560 1132 1090 .5 1 Perform in'ectivit test with NH4CI down coil, 1100 si WHP @ .5b m 17:12 12560 1393 2810 1.1 4 Perform in'ectivit test with NH4CI down coil, 1390 si WHP C«~ i.ib m 17:15 12560 1700 3750 1.2 15 Perform in'ectivit test with nh4cl down coil, 1688 si WHP C~3 1.2b m 17:26 12560 1728 3588 1.2 19 Continue um in DAD acid 17:32 12554 1745 3657 1.2 26 Swa to Mud acid down coil 17:38 12560 1863 2432 .6 34 Reci rocate accross erfs whille in'ectin acid 17:47 12461 2131 2206 .3 37 Continue in'ectin acid at minimum rate, IAP = 0 si, OAP = 0 si 18:03 12528 1786 1847 .5 43 Injection pressure beginning to drop slowly, continue reciprocating across erf interval 18:15 12468 1420 1526 .6 51 a+ Swa to NH4CL with F103 and U67 18:19 12451 1825 3685 1.2 56 Continue dis lacin acid with NH4CI 18:27 12490 1020 3540 1 64 WHP fallin noticeabl 19:10 12501 0 83 0 102 Finish pumping NH4CI with F103 and U67, vac truck on location for cleaning up cementers has a frozen valve, online with CT pump at minimum rate with 60/40 meth waitin on valve to thaw 19:16 12400 210 59 1 105a Online with CT um down coil with NH4CI to overdis lace 19:23 12403 801 1501 1.1 110 1.1 b m @ 800 si 19:40 12403 1100 3757 1.8 131 1.8 b m C~ 1100 si 20:00 12400 1323 3742 1.8 167 1.8 b m C~ 1326 si 20:16 12365 1403 1800 0.3 195 Line up to inject into top of well and down CT to test infectivity and contiune overdis lacin acid 20:18 12365 500 500 2.5 200 Online walkin um rate u 20:35 12365 1891 1980 2.7 240 WHP linin out at 2.7 b m @ 1900 si 20:47 12365 1970 2021 2.4 270 Continue over dis lacin 21:28 12365 1998 2121 1.7 354 Total wellbore displace to 3% Ammonium Chloride, final injection rate at 1.6 b m @ 2000 si. 22:30 12365 1900 2000 0 426/m Out of 3% ammonium chloride, swap to 60/40 meth down backside to freeze rotect surface lines 22:37 12365 55 86 0.3 429/Om POOH, online with 60/40 down CT 23:59 2600 0 243 34 Continue POOH, *** Continued on WSR 03/04/2007 "** Final Tb , IA, OA 0 0 0 JOB COSTS SERVICE COMPANY -SERVICE DAILY COST CUMUL TOTAL DOW ELL $37,722 $81,764 SCHLUMBERGER $21,780 $31,343 VECO $4,354 $11,222 WAREHOUSE $2,100 $12,949 W EATHERFORD $0 $15,607 ~ A LITTLE ED $0 $4,220 • TOTAL FIELD ESTIMATE: $65,956 $157,106 FLUID SUMMARY 83 bbls 60/40 meth 31 bbls diesel 360 bbls 3% Ammonium Chloride 50 bbls 3% Amonium Chloride w/ 0.2% F103 and 10% U67 25 bbls 12% 80:20 DAD Acid (titration = 12.3% HCI, Iron < 22 ppm) 25 bbls 9:1 Mud Acid titration = 9.2% HCI and 1.2% HF, Iron < 22 m PERFORATIONS TOP DEPTH BOTTOM DEPTH GUN DIAMETER TATION ORIE N SHOT DENSITY SHOT PHASE 12,480 12,530 2.875 _ _ N 6.00 _ 60 • • ::, .' MICRt~FILMED 013/41 /2C1t18 DO NOT PLACE ANY NEW MATERIAL .UNDER THIS PAGE ,_ ~' ~~:.. F:\LaserFiche\CvrPgs_InsettslMicY~o~ilin Marker.doc ~~ DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill Well Name/No. PRUDHOE BAY UNIT 03-33B Operator BP EXPLORATION (ALASKA) INC 2050180 MD 13072 TVD Completion Status WAGIN Current Status WAGIN -,-~ 8917 Completion Date 4/2/2005 ----~~_. ~--~-~ ~_.._,--~~-.-.~--"-~~---~-~. ~~-~--,~~"~ REQUIRED INFORMATION API NO.) fo~-21~ï2-t!:tJ~ 1 ~ UIC Y ~~"---"---"----'---'-"~'-'~-~--'--'~-'-- Directional Survey c:;;;;; _. --_._--~~ Mud Log No Samples No -'~-_'~-~-"--~~'_~-~'~--_'_-~--'~-- .---- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR / PWD, MWD DIR / GR / RES / ASI, USIT Well Log Information: (data taken from Logs Portion of Master Well Data Maint Received Comments 4/27/2005 IIFR 4/27/2005 MWD 8/30/2005 Ultrasonic Cement Image Tool USIT, CCL, GR Ultrasonic Cement Image Tool USIT, CCL, GR GR EWR4 ASI PWD ROP GR EWR4 ASI PWD ROP ROP DGR EWR plus Graphics <e, Temp, Pres Survey, GR, CCL 1-Mar-2007 Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (ßb~D~-- Directional Survey MD "D Asc '~ I fD C Lis ,jkD D Lis #Pt YED C Las I ~~____ Temperature_~~_~___~~: Log Log Scale Media Run Interval OH/ No Start Stop CH 9494 13072 Open 9494 13072 9430 10567 Case Directional Survey Cement Evaluation Col 5 13232 Cement Evaluation 9430 1 0567 Case 8/30/2005 8689 13012 Open 9/26/2005 8689 13012 Open 9/26/2005 9596 13072 Open 2/22/2006 10202 12940 Open 4/20/2007 13278 Induction/Resistivity 13278 LIS Verification 13594 Induction/Resistivity Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received ADDITIONAL INFORMATION Well Cored? Y (f;) Chips Received? ~ Daily History Received? G/N tiJ/N Formation Tops Analysis Received? ~ --- --- --- Comments: e e --- -- DATA SUBMITTAL COMPLIANCE REPORT 5/2/2007 Permit to Drill 2050180 Well Name/No. PRUDHOE BAY UNIT 03-33B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21142-02-00 MD 13072 TVD 8917 Completion Date 4/2/2005 Completion Status WAGIN Current Status WAGIN UIC Y -------~------~---JJo- - co:plianc-e ReVie~:~~-_-_=-- ----=--- ~-~,.. "--~-_. Date: ~3 - ~ -~ ---=== e - RECEIVED Schlumbepger APR 2 U Z007 NO 4214 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ,~~ Oil & Gas Cons. Comm~ Al'If.:OOrage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 LiIŒ¿Ç¡D·S-""C 1"7J~ Field: Prudhoe Bay Well Job# Log Description Date BL Color CD 02-15 11661130 MEM PROD PROFILE 02/25/07 1 U-06B 11469946 MEM PROD PROFILE 02/24/07 1 P-09L 1 11676933 LEAK DETECTION LOG 03/18/07 1 U-12A 11649941 MEM PROD PROFILE 02/17/07 1 Z-32BL 1 11661128 MEM PROD PROFILE 02/19/07 1 L-04 11649945 MEM SPINITEMP/PRESS LOG 02/18/07 1 DS 16-22 11676935 LEAK DETECTION LOG 03/22/07 1 DS 12-31 11594485 LEAK DETECTION LOG 03/23/07 1 DS 07-35 11676932 LEAK DETECTION LOG 03/17/07 1 06-07 11637114 LEAK DETECTION LOG 03/16/07 1 L5-28AL 1 11660526 MEM PROD PROFILE 02/08/07 1 03-33B 11661131 MEM TEMP/PRESS SURVEY 03/01/07 1 Z-19A 11649953 STATIC PRESS & TEMP LOG 03/21/07 1 F-11 B 11649954 MEM PROD PROFILE 03/22/07 1 P2-37 A 11628754 MEM DEPTH CONTROL LOG 02/11/07 1 P2-58 11661129 MEM STATIC PRESS SURVEY 02/24/07 1 Y-06A 11628751 MEM INJECTION PROFILE 02/09/07 1 Z-35 11628753 DEPTH CONTROL LOG 02/10/07 1 P2-40 11637320 PROD PROFILE 02/25/07 1 05-20B 11649952 MEM DEPTH DETERMINATION 03/20/07 1 03-36 11649951 MEM STATIC PRESS & TEMP 03/18/07 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Date Delivered: Received by: éj( 04/16/07 e - 1Ø- . STATE OF ALASKA l..r-r-ð~ MAR 06 Z007 ALASðolL AND GAS CONSERVATION COMM ION Cp . REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. CommissIOn o o o . 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Opera!. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 56.39 KB ( 8. Property Designation: ADLO-028327 / 11. Present Well Condition Summary: Total Depth 13072 / 8916.5 / measured true vertical Effective Depth measured 12987 ' feet true vertical 8916.5 I feet Casing Length Size CONDUCTOR 80' 20" 91.5# H-40 Surface 2475' 13-3/8" 72# L-80 Intermediate 9562' 9-5/8" 47# L-80 Liner 2985' 7" 26# L-80 Liner 2681' 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 12480' - 12976' True Vertical depth: 8916' - 8917' Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 3933 0 o shut-in 0 15. Well Class after proposed work: Exploratory Development 16. Well Status after proposed work: Oil Gas WAG P' Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development Stratigraphic feet feet MD 30' - 110" 31' - 2506' 32' - 9594' 3018' - 1 0572' 1 0391' - 13072' - - 4-1/2" 12.6# 7"x4-1/2" BKR S-3 o o o 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Signature Form 10-404 Revi ed 04/2006 0 RIG I Stimulate 0 Other 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 205-0180 / Exploratory Service p 6. API Number: 50-029-21142-02-00 / 9. Well Name and Number: PBU 03-33B ( 10. Field/Pool(s): Prudhoe Bay Fieldl Prudhoe Bay Pool I Plugs (measured) Junk (measured) None None TVD Burst Collapse 30' - 110' 1490 470 31' - 2506' 5380 2670 32' - 8004' 6870 4760 3016' - 8722' 7240 5410 8589' . 8917' 8430 7500 - - L-80 SURFACE - 10395' 10338' o o o Tubing pressure 1314 o Service p WINJ WDSPL Title Data Engineer Phone 564-4944 ····L Date 3/5/2007 Submit Original Only e e RF~FI\/ED ~ ,;4""/,../\; 03-33B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY \ > w,/·,>·,·······,.,,".,··,·/~.,.~···, 3/1/2007 CTU #5. Drift/Temp Log, MU Weatherfrord 3.7" drift with 2.6· JSN. RIH. Tag @ ; 12936' ctmd. PUH and flag pipe 20' off bottom(red). POOH. MU SLB memory Iogging tools with GR/CCLlTemp. RIH. Log down pass at 10600' to 12929' Ictmd. Up pass from 12929' to 10200'. POOH. Recover good data from tool. MU Weatherford 4-1/2· CIBP. *** Job continued on WSR 03/0212007 *** , 3i2l2ÕÕirCTU#S.Set ·cISPiÄdpert: .... Continued from WSR õ37õ:¡i2õõi'.;;Memory' "I 1 log required +15' shift, correlated to Sperry-Sun EWR-DGR dated 3/21/2005. I RIH w/ BHA #3 Weatherford 4.5· CIBP. Corrected depth to flag (+9'). Set plug lat 12690' ctm. Successfully PT to 3000 psi. POOH pumping 60/40 meth for displacement. RD CIBP setting tool. RU BHA #4 2.75" PJOmega 2906 6spf iperforating gun. RIH to CIBP. Correct bottom shot to CIBP. PUH to firing depth i ì(12505' - 12530'). Fire guns with 1/2· aluminum ball. Good indication of firing. 1 POOH. RD perforating guns. Makeup BHA for 2nd gun run. ì ** Continued on WSR 03/03/2007 **** ... 3i3i2ÕõiicTU#S:'AddPerl TÄcidlze: .. ;··Continued from WSRÕ3iÕ2I2õõi····RU 'sRÄ#s! 12.75" PJOmega 2906 6spf perforating gun. RIH to CIBP. Correct top shot to CIBP. PUH to firing depth (12480' - 12505'). Fire guns with 1/2· aluminum ball. Good indication of firing. POOH. All shots fired. MU JSN BHA. RIH and tag 'CIBP @ 12678' ctmd. Correct to CIBP. Initial injectivity was 1.7 bpm @ 1700 ¡psi. Begin pumping 25bbls 12% DAD, 25bbls 9:1 Mud Acid, 50bbls 3% NH4CL ¡with F103 and U67. Overdisplace fluid with 315 bbls of 3% NH4CI. POOH laying ì in 3% NH4CI while freeze protecting CT. ,w I *** Con!il'!~~.<:!<?1'! WSR 03/04/2007 *** .w 3/4/2007ICTU #5. Acidizingl Rig Down *** Continued from WSR 03/03/2007 *** POOH freeze protecting CT. At surface, freeze protect well per DSO request with 35 i bbls of 60/40 meth. RD CTU. Notify DSO of well status. Final WHP 0/0/0. t.***,~o~ ~o~plete *** '., .............. w., ,.ro"..J\., \ ,.ro"r... \" FLUIDS PUMPED BBLS 83 60/40 METH 360 3% AMMONIUM CHLORIDE 31 DIESEL 50 3% AMMONIUM CHLORIDE w/0.2% F103 AND 10% U67 25 12% 80:20 DAD ACID (TITRATION=12.3% HCI, IRON <22PPM) 25 9:1 MUD ACID (TITRATION=9.2% HCI AND 1.2% HF, IRON <22 PPM) 574 TOTAL .rI""J...,:/'"'" . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 16, 2006 {JIC 8DFj- D I 'S /0::/14-- RE: MWD Formation Evaluation Logs 03-33B, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 03-33B: LAS Data & Digital Log Images: 50-029-21142-02 1 CD Rom II ?1iV/{¡f¡ Ii V""'\ (j (~) (!)( ~91 ÒlÞ . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Helen Warman 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 August 19,2005 RE: MWD Formation Evaluation Logs: 03-33B, AK-MW-3591175 1 LDWG formatted Disc with verification listing. API#: 50-029-21142-02 f)fi PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: ~~~~\) 1lJ oJ1J Signed: ),or... ~l ~ 08/30/05 Schlumbergel' NO. 3460 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm AUn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Date BL Color CD Z-15 I'S~·- (Jl.,'f 11084273 PPROF W/DEFTfGHOST/CALlPER 07/08/05 1 L5-17A lr¡'"í -ÀÅ3 11075898 MEM PPROF W/DEFT/GHOST 07/03/05 1 DS 04-26 I.Y ~--JN 11072873 PRODUCTION PROFILE 07/30/05 1 S-14A '). \¡ Ii - 011 10893047 LEAK DETECTION LOG 10/17/04 1 G-27 I :f(.- (rID 10942221 MEM PPROF & IPROF 06/29/05 1 DS 05-20B ~ Ð '-I .. J..) If 10942220 MEM INJECTION LOG 06/26/05 1 E-37A '1 C ç - \:¡t 7.... 10928640 MEM PPROF, IPROF & WARM BACK 06/14/05 1 D-29 I ~ ç-l..rJ 11084274 RST 07/09/05 1 1 i ),,) ~.~ L2-28 It;- r - C j S- 11076453 RST 07/27/05 1 1 /3 ~.J'I C-13A fr:¡7-;Lì~ 11075900 MCNL 07/05/05 1 1 I J).) r OWDw-swl'>J C '-). 3 ð 10893096 RST-BORAX CHANNEL DETECTION LOG 03/24/05 1 1 iJ).). f.£ 06-08A 1 q r -, q )- 11062628 RST 05/17/05 1 1 13 )..'J. 7 12-29 J,V'1 - t3L 11072867 RST 07/07/05 1 1 J.?2.J..8 C-19B,AG ..:;- 0\0 r 10928632 MCNL 05/12/05 1 1 i? .2. ;u¡ G-27 iSl\¡- , 1 lö 10942221 MCNL 06/29/05 1 1 j ~ 13~ F-02A ?. &~- - C vI <.j 10928630 MCNL 05/08/05 1 1 13:U; 03-33B ).0$--015 10913011 USIT PDC-GR 03/19/05 1 1 11>,), ~J.. MPK·22 ~À (¡ 5-"- ü.:l2- 10893106 USIT 04/20/05 1 . . BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: )/ ~ :tt\\ \ --~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995g;3.,', ~p'38 ,,_,.,'j¡¡.', " ATTN: Beth / 2/ Ii /'} / Received by: ìf-(~""U ' / ~ .. STATE OF ALASKA _ ALASKWIL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LORE CE IVE D ~ L ~A AV n ':t 700:3 la. Well Status: 0 Oil o Gas o Plugged o Abandoned o Suspended IHI WAG lb. Well Class: - 20AAC 25.105 20AAC 25.110 ~.~~.¡.[j DGINJ DWINJ o WDSPL No. of Completions One Other IC.L .§^ervlce 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to u rfbër BP Exploration (Alaska) Inc. 4/2/2005 205-018 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 3/14/2005 50-029-21142-02-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 3/20/2005 PBU 03-33B 215' NSL, 821' EWL, SEC. 11, Tl0N, R15E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2470' NSL, 5191' EWL, SEC. 11, Tl0N, R15E, UM 56.39' Prudhoe Bay Field / Prudhoe Bay Pool ~ r~ePth: . ( :> P'V 9. Plug Back Depth (MD+ TVD) ~. NSL,7~EWL, SEC. 12, Tl0N, R15E, UM 12987 + 8917 Ft 4b. Lo~ation of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 714114 y- 5936278 Zone- ASP4 13072 + 8917 Ft ADL 028327 TPI: x- 718416 y- 5938658 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 719220 y- 5940617 Zone- ASP4 2206' MD -- -- n -- 19. Water depth, if offshore 20. Thickness of Permafrost 18. Directional Survey IHI Yes DNo NI A MSL 1900' (Approx.) 21. Logs Run: MWD DIR I GR I PWD, MWD DIR I GR I RES / ABI, US IT 22. CASING, LINER AND CEMENTING HECORD CASING SETTING EPTH .MD SETTING EPTHTVD HOLE . AMOllNT SIZE WT. PER FT. GRADE Top I I:K>TTOM lOP I I:K>TTOM SIZE CEMENTING RECORD PUI..LEO 20" 91.5# H-40 Surface 110' Surface 110' 30" 191 0# Poleset 13-3/8" 72# L-80 Surface 2506' Surface 2506' 17-1/2" 12300 sx Coldset 1/1, 400 sx CS II 9-518" 47# L-80 Surface 9594' Surface 8004' 12-1/4" 500 sx Class 'G', 300 sx CS I 7" 26# L-80 3018' 10572' 3016' 8722' 8-1/2" þ34 sx Class 'G', 452 sx Class 'G', 136 sx Class 'G' 4-1/2" 12.6# L-80 10391' 13072' 8589' 8917' 6-1/8" 328 sx Class 'G' 23. Perforations oRen to Production (MD + TVD of Top and 24. TUBING RECORD Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 6spf 4-1/2", 12.6#, L-80 10395' 10338' MD TVD MD TVD 12880' - 12905' 8916' - 8916' 25. ACID, FRACTURE, CEMEN"tSQUEezE,E]'"C. 12905' - 12930' 8916' - 8916' 12923' - 12949' 8916' - 8916' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12950' - 12976' 8916' - 8917' 2300' Freeze Protect with 155 Bbls of Diesel 12880' - 12976' Acid Treatment on 04/05/05, See Daily Report for Details (Post Rig) 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): April 22, 2005 Water Injection Date of Test Hours Tested PRODUCTION FOR Oll-Bsl GAs-McF WATER-BSl CHOKE SIZE I GAS-Oil RATIO TEST PERIOD + Flow Tubing Casing Pressure CALCULATED + Oil -BSl GAs-McF WATER-BSl Oil GRAVITY-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). SUbm~~none, state "none' Cu,..,) '..;.,~d",:,'ii ;: None y~~ RBDMS BFL MAYO 4 2005 '~U¡ . t ii ft Gf ..:'~-j '~'i' ~"!:;~ Form 1 0-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". CM1 9798' 8150' None HRZ 10257' 8492' Sadlerochit 10584' 8731' 43P 10614' 8753' 42N 10658' 8785' 42P 10707' 8821' 41N 1 0723' 8832' 31P 10748' 8848' 27P 10832' 8894' 30. List of Attachments: Summary of Daily Drilling Reports. Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Terrie Hubble Title Technical Assistant Date PBU 03-33B Well Number Prepared By NameINumber: Drilling Engineer .. Terrie Hubb/e, 564-4628 Dave Wesley, 564-5153 205-018 Permit No. I A roval 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 1 0-407 Revised 12/2003 Submit Original Only 4,531 (psi) 0.00 (ppg) - Printed: 3/28/2005 1: 11 :36 PM 725 (psi 8.40 (ppg) 8,722.0 (ft) 0,572.0 (ft) 3/1 3/17/2005 I FIT Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3f7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/7/2005 00:00 - 07:30 7.50 MOB N WAIT PRE Waiting on Security to move. 07:30 - 08:00 0.50 MOB P PRE PJSM to move rig. 08:00 - 18:00 10.00 MOB P PRE Move sub from F pad to DS 3 Wire line has set up on DS 17 and would not allow rif=g to pass without additional snow removal. Call out roads and pads to remove snow. Up right tanks had been placed in rig move path after route was review and driven. 18:00 - 21 :30 3.50 MOB N WAIT PRE Rig on stand-by waiting on snow removal to pass wire line operations on DS 17 21 :30 - 00:00 2.50 MOB P PRE Move sub base from DS 17 to DS 3 3/8/2005 00:00 - 01 :00 1.00 MOB P PRE PJSM: Lay Herculite and spot sub base. 01 :00 - 06:30 5.50 MOB P PRE PJSM: Rig up and raise derrick. Rig up rig floor and cellar. Berm area and cellar. 06:30 - 08:00 1.50 DHB P DECOMP Install Secondary annulus valve and pull back pressure valve. Productive time for rig. 08:00 - 11 :30 3.50 MOB P PRE Lay matting & Herculite. Spot pits and camp. Hook up pits. Berm and spot cutting tank. 11 :30 - 12:00 0.50 WHSUR P DECOMP Pre-job and Spud meeting with both crews for rig accept. Review pre-spud check list and do walk through with driller and pusher. Rig accept. Rig has 1.5 hour working time installing secondary annulus valve and pulling BPV from 6:30 to 8:00 am today. This cost will be captured in daily cost section. 12:00 - 13:00 1.00 WHSUR P DECOMP PJSM: Rig up lines to circulate well. Test lines to 4000 psi and chart same. 13:00 - 16:30 3.50 WHSUR P DECOMP Circulate well to seawater First pump down annulus and recover freeze protect from tubing. Swap lines and pump soap pill down tubing, Circulate well to fresh sea water. Verify well is dead. 16:30 - 17:30 1.00 WHSUR P DECOMP PJSM: Dry rod back pressure valve. Test from below to 1000 psi. Blow down surface equipment. Winds at 35 MPH visibility as < 20 feet. Security calling phase 2 but much worse on location. Plan to secure well and shut down operation for safety. 17:30 - 20:30 3.00 WHSUR P DECOMP PJSM: Nipple down tree. and adapter flange. Verify tubing hanger flange and that the tubing hanger is not a welded hanger. Check threads with Cameron, WSL and Driller. 20:30 - 22:00 1.50 WHSUR P DECOMP PJSM & review procedure: Nipple up BOP. Working towards securing well to do weather shut down. 20:15 hours Fuel truck drive scrapes against warm up shack. HSE and security notified. Incident report and traction started. Visibility is < 20 feet. Security call Phase 3. 22:00 - 00:00 2.00 WHSUR N WAIT DECOMP Phase 3 conditions: Review safety condition, fuel and water level of rig and shut down operation. Weather very severe. 3/9/2005 00:00 - 15:30 15.50 WHSUR N WAIT DECOMP Phase 3 Waiting on weather. Very Bad! Winds 40 - 50 MPH wind chill - 70 degrees. Stack is set with 4 bolts tight. Not tested. Tested BPV in place. Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/912005 00:00 - 15:30 15.50 WHSUR N WAIT DECOMP Will try to change out crews with heavy escort this morning. 15:30 - 17:30 2.00 WHSUR P DECOMP PJSM: Clear exit from pad. Hold PJSM to NIU BOP. Nipple up BOP. Witness waived by John Crisp AOGCC 17:30 - 22:00 4.50 WHSUR P DECOMP PJSM & Review procedure to test BOP's: Test BOP's. 250 low test and 4000 psi high test. Top set rams failed. Test annular to 3000 psi high test. 22:00 - 23:00 1.00 WHSUR P DECOMP PJSM amd review procedure: Change out top rams to 5 1/2" fixed bore. 23:00 - 00:00 1.00 WHSUR P DECOMP Test 5 1/2" Rams 250 low 4000 psi high. Good test. DSM is unable to get crew to location to pull BPV till around 6 AM estimated. Drill Site Maintenance was on V pad 1 7ES and could not make it to pull BPV. While waiting, repaired the variable 3 1/2" X 6" rams. Waiting on DSM. 3/10/2005 00:00 - 02:00 2.00 WHSUR P DECOMP Test valves on top drive 250 low and 4000 psi high. Waiting on Drill Site Maintenance. BOP test witness waived by AOGCC John Chrisp. 02:00 - 03:00 1.00 WHSUR P DECOMP While waiting on DSM: Change out top rams to 3 1/2" variable and re tested 250 low and 4000 psi high to utilize rig time. Pull Blanking plug. Rig down test joint. Blow down top drive and kill lines. Phase 3 on Pads and Phase 2 on spine roads. 03:00 - 06:00 3.00 WHSUR N WAIT DECOMP Waiting on DSM to pull BPV 1 Service rig and top drive while waiting. 06:00 - 11 :00 5.00 WHSUR N WAIT DECOMP Phase 3 conditions: All operations shut down. Unable to keep access to rig open. Will need DSM to start up operations. 11 :00 - 12:30 1.50 WHSUR P DECOMP DSM arrives: PJSM: Rig up lubricator. Pull back pressure valve. Rig down DSM and lubricator. 12:30 - 14:00 1.50 PULL P DECOMP PJSM & Review procedure: Make up landing joint and Release lock down screws. 14:00 - 15:00 1.00 PULL P DECOMP PJSM & Review procedure: Pull Hanger to rig floor. 180,000 # Up to free tubing spool from tree. Lay down hanger and landing joint. 15:00 - 15:30 0.50 PULL P DECOMP PJSM with Schlumberger I Cameo: Rig up Spooling unit. 15:30 - 18:00 2.50 PULL P DECOMP Lay down tubing while spooling control line from 9700 to 7520'. Terminated control line. Recover 4 stainless steel bands and 27 clamps and pins. Phase conditions on Pad are getting worse. Will continue to safe point and secure well. 18:00 - 18:30 0.50 PULL P DECOMP Rig down Cameo spooling unit. Secure well and shut down due to weather and phase conditions. Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/10/2005 18:00 - 18:30 0.50 PULL P DECOMP 18:30 - 19:30 1.00 PULL N WAIT DECOMP Waiting on weather. Well Site Leader and Toolpusher audit location for access and evaluate ability to get emergency assistance to and from rig. Fork lift operator able to keep access open. Phase 3 on pads and access roads and Phase 2 on spine roads. Snow blowing in as fast as we can move it. DRifts 6 - 8 feet on location. Able to keep road open. 19:30 - 00:00 4.50 PULL P DECOMP PJSM discuss conditions and weather: Resume operations at controlled pace. Pull out of hole laying down tubing form 7490' to 2755'. Running both loaders, 1 keeping access open and second moving tubing. Location is blowing in. Can not get large trucks turned around on location. Roads and pads can not support, working on fire lanes and main roads only. Work continuing at controled pace. Drifts 6 - 8 feet on pad. 3/11/2005 00:00 - 04:30 4.50 PULL P DECOMP Pull out of hole with 5 1/2" tubing and lay down same from 2755 to tubing cut @ 9660' 15' from collar t to cut. Cut flared and jagged. A full cut but not very clean, flared. Weather conditions have improved slightly but location has 6 - 8' drifts. Trucks unable to turn around on locations. 04:00 - 06:30 2.50 PULL P DECOMP Clear Rig floor and lay handling tools. Install 4" Rams and test stack and rams. 250 psi low and 4000 psi high. Test Bag to 3000 psi. Rig down test joint. 06:30 - 07:30 1.00 PULL P DECOMP PJSM: Pick up mills and BHA for clean out run. 07:30 - 09:00 1.50 CLEAN P DECOMP Pick Up BHA, DC's and HWDP to 955" 09:00 - 15:30 6.50 CLEAN P DECOMP Pick up 4" drill pipe from 955' to 9660' tag top of fish. Lay down one joint. Up weight = 205,000# Slack off = 165,000# 15:30 - 16:30 1.00 CLEAN P DECOMP PJSM: Make up RTTS / storm packer. Set packer 3' below tubing spool. Test from below 500 psi. Blow down surface equipment. 16:30 - 18:00 1.50 CLEAN P DECOMP PJSM: Nipple down BOP. 18:00 - 23:00 5.00 CLEAN P DECOMP PJSM: Remove tubing spool, Remove spool and tree from cellar. Change out top seal on lower pack off. Install new tubing spool and test pack off to 3800 psi. 23:00 - 00:00 1.00 CLEAN P DECOMP PJSM: Nipple up BOP. 3/12/2005 00:00 - 01 :30 1.50 CLEAN P DECOMP PJSM: New Crew. Make up raiser and flow line. Derrick inspections. Run in test plug. 01 :30 - 02:00 0.50 CLEAN P DECOMP PJSM: Test break in stack at tubing spool. Test plug not holding. Rig down test plug and install wear bushing. 02:00 - 03:00 1.00 CLEAN P DECOMP PJSM: Pick up single drill pipe and TIW valve. Sting into RTTS and pick up to string weight 160,000#. Test against RTTS and upper rams. 250 low and 4000 psi high. Good test. Test plug showed signs of damage and needs to be changed out. Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/12/2005 02:00 - 03:00 1.00 CLEAN P DECOMP Release RTTS and pull to surface. Lay down RTTS and clear rig floor. Pick up single and tag fish at 9660. 03:00 - 05:30 2.50 CLEAN P DECOMP PJSM: Circulate and swap out seawater to 10.5 LSND Mud @ 10 BPM. 04: 15 During displacement the returns were diverted to cuttings box and the down snout was frozen off, causing fluid to back up and splatter over and drop onto the top rim of the cutting box and onto the herculite, Approximately 15 - 20 gallons all in containment. 5700 was called at 04:45 hours. SRT call the rig at 05:00. Discussed the event and advised us to continue and clean up. SRT:Vic Richart responded assessed the discharge as a leak contained by secondary containment / non-reportable. Traction Report # 2005-IR-1278522 Cleaned up the splatterand dirty snow around the cutting box. 05:30 - 07:00 1.50 CLEAN P DECOMP PJSM: Cut and slip 125' of drilling line. Service top drive. 07:00 - 10:00 3.00 CLEAN P DECOMP Pull out of hole 9660 to 955' 10: 00 - 11 :00 1.00 CLEAN P DECOMP PJSM: Handle BHA stand back HWDP & DC's. Lay down bumper sub and mills. Mills look good. 11 :00 - 12:30 1.50 DHB P DECOMP PJSM and review procedure. Rig up Schlumberger wire line to set BP. 12:30 - 16:30 4.00 DHB P DECOMP Make up bridge plug and tiring head. Run in hole and tag top of fish 9684 WLM. Log for collars. Set EZSV @ 9646 WLM. POOH with wire line and rig down Schlumberger. 16:30 - 17:30 1.00 DHB P DECOMP PJSM: Rig up and test 9 5/8" casing to 4000 psi for 30 minutes and chart. Good test. 17:30 - 21 :00 3.50 STWHIP P WEXIT PJSM: Pick up and make up whip stock BHA. Up load MWD. Surface test at 500 gpm 770 psi. MWD working. Make up BHA from 450 to 1035 feet HWDP and DC's. 21 :00 - 00:00 3.00 STWHIP P WEXIT Run in hole from 1035 to 7102 with pipe from derrick. Fill pipe every 3000' and test MWD. 3/13/2005 00:00 - 01 :30 1.50 STWHIP P WEXIT Run in hole to 9527 feeV Fill pipe and hook up blower hose to top drive. Establish whip stock tool face and set to 68 right of highside. 01 :30 - 02:30 1.00 STWHIP P WEXIT Set whipstock tool face to 68 right of highside and set at 9594' top of window. Tag BP @ 9616' MD bottom WS. Up weight = 215,000# whip stock on 205,000 off String weight 147,000# down Torque off bottom 10,000# Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/13/2005 01 :30 - 02:30 1.00 STWHIP P WEXIT Torque milling 12 - 15,000# Higher than normal. Will increase lubes to attempt to decrease torque. WLM depth corrected to DP measurements. TOW 9594' 02:30 - 08:30 6.00 STWHIP P WEXIT Milling window: 9594' to 9610'. Continue making hole to 9622'. 100 rpm Torque = 12 - 15,000 5K WOB Milling at 2 - 4 feet per hour Top of window 9594' MD 8003.4' TVD Pumping at 510 gpm SP = 2250 psi Magnet in return lines and recovering & weighting cuttings Up weight = 180,000# Down Weight= 160,000# Rotating weight = 170,000# Torque dropped slightly with lube increase to 9 - 13K 08:30 - 09:30 1.00 STWHIP P WEXIT Pump sweep, work through window 190,000 # up II 155,000# down Recovered 80 # metal total 09:30 - 10:30 1.00 STWHIP P WEXIT PJSM: Rig up to perform FIT while circulating. Perform FIT to 12.5 ppg 840 psi on surface @ 8003' TVD. Good test. 10:30 - 14:30 4.00 STWHIP P WEXIT Pump dry job and POOH with milling BHA from 9622 to 1013'. 14:30 - 16:30 2.00 STWHIP P WEXIT POOH 1013 to 386. Lay down drill collars and mills. Mills in good shape and full gauge. 16:30 - 17:30 1.00 STWHIP P WEXIT PJSM: Pull wear ring. Flush BOP's with Johnny whacker. Function BOP. 17:30 - 20:00 2.50 STWHIP P WEXIT PJSM: Make up 81/2" drilling BHA. Orient MWD I motor offset. Surface test MWD and motor. 20:00 - 20:30 0.50 STWHIP P WEXIT PJSM: Service top drive and skate. 20:30 - 00:00 3.50 STWHIP P WEXIT Run in hole 802 to 6402' Pick up single drill pipe to 5189' after running stands form derrick. Fill pipe every 3000' and test MWD.. 3/14/2005 00:00 - 01 :00 1.00 STWHIP P WEXIT Trip in hole from 6402' to 8730' to start MAD PASS. 01 :00 - 02:30 1.50 STWHIP P WEXIT Mad Pass 8730' to 8970' to tie in gamma log. Break circulating and estibilish clean hole ECD. 550 = 10.82 ppg 525 = 10.80 ppg With cold mud. 02:30 - 03:00 0.50 STWHIP P WEXIT Trip in to above window. Break circulation and estibilish tool face 65 R to exit. 03:00 - 04:00 1.00 STWHIP P WEXIT PJSM: Wash under gauge hole 9610 to 9622' Up weight 185,000# Down weight= 155,000# 04:00 - 06:00 2.00 DRILL P INT1 Drill from 9622 to 9850' ECD 10.9 to 11.1 ppg Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/14/2005 04:00 - 06:00 2.00 DRILL P INT1 Clean hole - 10.82 ppg Reducing pump rate to 2/3 on down stroke. 550 GPM 2450 psi off bottom 2800 psi on bottom\ Control drilling at 100 - 150 fph (150 max) 06:00 - 17:30 11.50 DRILL P INT1 Drill from 9850 to 10572' MD. Up weight 197,000 # Down = 150,000# Rotating = 174,000# Torque off 7000 ft/# 80 RPM = 9 - 1 0,000ft/# of torque on bottom Pumping at 520 GPM 3050 psi on bottom / 2800 psi off 7.55 total rotating hours 2.05 Total siding hours 9.6 total drilling hours ECD's = 11.2 - 11.6 PPG Clean hole was 10.82 PPG 17:30 - 19:00 1.50 DRILL P INT1 Circulate bottoms up for sample for geology. Circulate until shaker are clean. 19:00 - 19:30 0.50 DRILL P INT1 PJSM: Short trip to window 11 stands. Hole looks good, no tight spots on short trip out. 215,000# maximum pull on short trip Estibilished down weight with no pumps 145,000# 19:30 - 21 :00 1.50 DRILL P INT1 PJSM: Slip and cut drilling line and service top drive. 21 :00 - 21 :30 0.50 DRILL P INT1 PJSM: Trip in hole from window 9578' to Td 10572'. Tag up with no problems or tight spots. 145,000# down weight. 21 :30 - 00:00 2.50 DRILL P INT1 PJSM and crew change tour meeting: Circulate at 575 GPM and 80 RPM 3600 PSI. Pump sweep (hi-vis) and circulate until shakers clean up. No excess amount of cutting seen across shakers. Spot liner running pill with 4% lubes. 3/15/2005 00:00 - 03:30 3.50 DRILL P INT1 Pump dry job. Drop 2 3/8" drift down drill pipe. POH from 10572' to 802' feet @ HWDP. 03:30 - 06:30 3.00 DRILL P INT1 UD BHA, retreive drill pipe drift. Flush MWD tools, down load MWD. clear & clean rig floor. 06:30 - 10:30 4.00 CASE P LNR1 PJSM, R/U to run 7" liner. M/U shoe track, fill pipe and check floats. RIH with 26 joints of 7",26#, L-80, BTC-M liner. M/U packer, XO and space out pups and 1 stand of 4" drill pipe. RIH to 1160'. 10:30 - 11 :00 0.50 CASE P LNR1 Circulate liner volume @ 5.5 bpb @ 160 psi. 11 :00 - 16:00 5.00 CASE P LNR1 RIH with 7" liner on 4" drill pipe from 1160' to 9531', fill pipe @ 10 stand intervals. 16:00 - 16:30 0.50 CASE P LNR1 Circulate drill pipe & liner volume @ 6 bpm @ 680 psi. UWT = 175K, DWT = 140K. 16:30 - 17:30 1.00 CASE P LNR1 RIH with 7" liner from 9531' to 10553'. M/U cement head, break circ @ 2.5 bpm @ 480 psi. Tag bottom @ 10572'. UWT = 195. 17:30 - 19:00 1.50 CASE P LNR1 Circulate, stage pump up to 7 bpm @ 1300 psi. Hold PJSM with drill crew & Schlumberger cement crew. Batch mix cement. Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/15/2005 19:00 - 20:00 1.00 CASE P LNR1 Pump 3 bbl of water, test lines to 4500 psi. Pump water from cement line to flow line through "T' with spacer, pump 25 bbl of Mudpush11 @ 12.0 ppg, pump 50 bbl [235 sacks] of class G cement @ 15.8 ppg, wash up lines, drop wiper plug. Displace with Schlumberger W 1133 bbl of mud. Bump plug with 3500 psi. Bleed off, floats held, CIP @ 19:50 hrs. Rotate & release from liner hanger, pressure up drill pipe to 1000 psi. Unsting & pump 50 bbl @ 11.5 bpm. Set packer with 70K of down weight, rotate & set down 70K. 20:00 - 21 :30 1.50 CASE P LNR1 CBU, @ 11.5 bpm @ 3000 psi, reciprocate pipe. No cement returns seen @ surface 21 :30 - 00:00 2.50 CASE P LNR1 Blow down lines, UD cement head & single of drill pipe. POH from 9426' to 387'. 7" liner shoe @ 10572', liner top packer @ 9443'. 3/16/2005 00:00 - 09:15 9.25 CASE P LNR1 P/U Baker 7" tieback seal assy and run 7" 26# L-80 IBT-M scab liner from 9453' to 3036'. 09:15 - 10:15 1.00 CASE P LNR1 MU hanger & L TP assembly. RIH on 1 std DP. PT liner to 1000 psi for 5 min - OK. 10:15 -11:00 0.75 CASE P LNR1 Circ 1 liner vol, @ 7 bpm @ 600 psi. Blow down top drive. 11 :00 - 12:30 1.50 CASE P LNR1 CBU, pump heavy dry job @ 6632'. (Mud overflowing top of pipe). Blow down surface equipment. 12:30 - 15:30 3.00 CASE P LNR1 RIH from 6632' to 9436'. Screw top drive into each stand of drill pipe to keep mud from flowing over top of DP when RIH.. UWT = 230K, DWT = 150K. 15:30 - 16:00 0.50 CASE P LNR1 Make up cement head, tag no-go @ 9453', P/U and expose ports on tie back assembly. 16:00 - 16:30 0.50 CASE P LNR1 Stage pumps up slowly to 7 bpm @ 1340 psi, circ drill pipe & liner volume. PJSM with drill crew & cement crew. 16:30 - 18:30 2.00 CASE P LNR1 Pump 5 bbl water, pressure test lines to 4500 psi. Pump 5 bbl water, 25 bbl mudpush @ 11.8 ppg, 145 bbl (450 sx) lead cement @ 13.5 ppg, 29 bbl (140 sx) tail cement @ 15.8 ppg. Shut down, drop wiper plug, pump 10 bbl water and displace with 10.5 ppg mud. Plug did not bump. Slack off DP and sting seal assembly fully into tieback sleeve. Pressure up to 1500 psi, slack off 30K, pressure up to 4200 psi, bleed off, floats holding. Had no indication of hanger setting. Pressure up to 1000 psi, release from hanger. CIP @ 1830 hrs. 18:30 - 20:00 1.50 CASE P LNR1 CBU @ 12 bpm @ 1840 psi, no cement to surface. UWT = 70K. Stop pump, rotate & set down 50K two times & set hanger. Pump dry job, blow down surface equipment. UD cement head & single of drill pipe. 20:00 - 21 :30 1.50 CASE P LNR1 POH from 3018'. UD liner running tool. Clear & clean rig floor. 21 :30 - 00:00 2.50 CEMT P LNR1 PJSM. P/U BHA #3 & Hughes MX-18HDX bit. Orient & up load MWD. 3/17/2005 00:00 - 03:00 3.00 CASE P LNR1 RIH, fill pipe @ 3000' intervals, tag cement @ 9345' - (33' above landing collar). 03:00 - 06:00 3.00 STKOH P LNR1 Drill cement & float equipment down to float collar @ 9423' 06:00 - 06:30 0.50 STKOH P LNR1 RU & test casing to 4000 psi. 06:30 - 09:00 2.50 STKOH P LNR1 Drill float collar @ 9423'. RIH, tag obstruction @ 10285', drill through obstruction & clean out to landing collar @ 10486'. UWT = 205K, DWT = 120K, RWT = 155, torque = 10K amps @ 40 rpm. 09:00 - 10:00 1.00 STKOH P LNR1 Test casing to 4000 psi, OK. Hold for 30 min on chart. Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/17/2005 10:00 - 11 :00 1.00 DRILL P LNR1 Drill float equipment & cement to 10565'. UWT = 205K, DWT = 120, RWT = 155K, Torque = 10K @ 40 rpm 11 :00 - 13:30 2.50 STKOH P LNR1 Pump 75 bbl of fresh water followed by 40 bbl of hi-vis sweep. Displace well to 8.4 ppg mud @ 6 bpm @ 1950 psi. 13:30 - 14:30 1.00 DRILL P LNR1 Drill cement, 7" float shoe & 20' of new formation to 10592'. Pull bit into casing. Perform F./.T. to 10.0 ppg EMWT using 8.4 ppg mud, pressure up to 725 psi. 14:30 - 00:00 9.50 DRILL P PROD1 Drill 6 1/8" hole from 10592' to 10880'. ART = 2.04 hrs, AST = 5.64 hrs, UWT = 180K, DWT = 145K, RWT = 160K, torque off btm = 6K, on btm = 7K. pump @ 280 gpm @ 2190/2340 psi, WOB = 20K, rpm = 60 3/18/2005 00:00 - 20:00 20.00 DRILL P PROD1 Drill 6 1/8" hole from 10880' to 11783' M D, 8937' TVD. ART = 6.85 hrs, AST = 17.24 hrs, UWT = 180K, DWT = 135K, RWT = 165K, torque @ 45 rpm = 4/6000 ft. Ibs. off btm, 7/8000 on btm. Pump = 280 gpm @ 2400 psi. WOB = 25K. 20:00 - 21 :00 1.00 DRILL P PROD1 Pump hi-vis sweep, circulate open hole volume 3 times. 21 :00 - 21 :30 0.50 DRILL P PROD1 POH from 11783' to 11567', UWT = 200K, hole in good shape. 21 :30 - 22:00 0.50 DRILL P PROD1 Drop dart and pump open circ sub. CBU @ 450 gpm @ 1600 psi. 22:00 - 00:00 2.00 DRILL P PROD1 POH from 11567' to 4875'. Will run USIT log when out of the hole. 3/19/2005 00:00 - 02:30 2.50 DRILL P PROD1 POH from 4875' to 209'. 02:30 - 03:30 1.00 DRILL P PROD1 Down load MWD, UD BHA, clear & clean rig floor. 03:30 - 09:00 5.50 EVAL P LNR1 PJSM with Sclumberger wire line crew & drill crew. R/U SWL & run US IT log from 10572' to 9442'. 09:00 - 10:00 1.00 DRILL P PROD1 P/U 1.5 degree bend mud motor, insert bit & BHA, up load MWD & surface test. 10:00 - 15:00 5.00 DRILL P PROD1 RIH from 211' to 7" shoe @ 10570', fill pipe @ 3000' intervals. 15:00 - 15:30 0.50 DRILL P PROD1 Service top drive & crown. Install top drive blower hose. 15:30 - 16:00 0.50 DRILL P PROD1 RIH from 10570' to 11690'. Hole in good shape. Wash & ream from 11690' to btm @ 11783'. 16:00 - 00:00 8.00 DRILL P PROD1 Drill from 11783' to 12535'. UWT = 185K, DWT = 125K, RWT = 163K, torque on btm = 617000 ft. Ibs. @ 60 RPM, pump @ 280 gpm @ 2200/2400 psi. AST = 1.04 hrs, ART = 4.11 hrs. 3/20/2005 00:00 - 06:00 6.00 DRILL P PROD1 Directionaly drill 6 1/8" hole to TD @ 13072' MD. WOB = 20K, pump @ 280 gpm = 2400 psi, 245 rpm @ bit. 06:00 - 09:00 3.00 DRILL P PROD1 Pump high vis sweep, rotate @ 100 rpm, & circulate @ 280 gpm @ 2280 psi. Spot liner pill. Flow check, well stable. 09:00 - 10:30 1.50 DRILL P PROD1 POH to 10572', no over pull, hole in good shape. 10:30 - 11 :00 0.50 DRILL P PROD1 Drop dart & shear circ sub, CBU @ 519 gpm @ 1730 psi. Pump dry job. 11 :00 - 15:30 4.50 DRILL P PROD1 POH from 10572' to BHA @ 211 '. 15:30 - 18:30 3.00 DRILL P PROD1 UD BHA. Flush tools with fresh water, down load MWD, clear & clean rig floor. 18:30 - 21 :30 3.00 CASE P PROD1 PJSM. R/U casing tools. P/U float equip. & check floats. RIH with 4.5",12.6#, L-80, IBT-M liner to 2690'. 21 :30 - 22:00 0.50 DRILL P PROD1 Circulate drill pipe & liner volume. 22:00 - 00:00 2.00 DRILL P PROD1 RIH with liner on drill pipe. 3/21/2005 00:00 - 04:00 4.00 CASE P PROD1 RIH with 4.5", 12.6# L-80, IBT-M liner on 4" DP. 04:00 - 04:45 0.75 CEMT P PROD1 M/U cement head, break eire, tag bottom, CBU. 04:45 - 05:00 0.25 CEMT P PROD1 PJSM for cementing liner. BP, NAD, Baker, Schlumberger, Veco. 05:00 - 06:30 1.50 CEMT P PROD1 Batch mix cement slurry while circ & cond mud. Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 3/21/2005 06:30 - 06:45 0.25 CEMT P PROD1 Pressure test lines to 4500 psi. 06:45 - 07:00 0.25 CEMT P PROD1 Pump 20 bbls CW100 pre-flush followed by 30 bbls MudPush XL spacer at 9.6 ppg. 07:00 - 07:30 0.50 CEMT P PROD1 Pump 70.2 bbls (360 sx) Class G GasBlok slurry at 15.9 ppg. 5 bpm @ 1350 psi. Shut down pumping. Clear lines with 10 bbls perf pill washed up down a Tee to the flowtine. 07:30 - 08:00 0.50 CEMT P PROD1 Release DP wiper dart - OK. Displace with 69 bbls perf pill. Switch to FloPro and continue displacement - 5 bpm @ 2100 psi. Getting sticky once cement starts in annulus. Park pipe on bottom. Slow for liner wiper plug. PU liner wiper plug at 100 bbls away. Bump plug at 138.5 bbls displacement (vs 142 bbl calculated). Pressure up to 3500 psi to set liner hanger. CIP at 08:00 hrs. 08:00 - 08:15 0.25 CEMT P PROD1 Bleed off pressure and verify floats are holding. Slack off weight and rotate string 15 turns right. Put 1000 psi on DP and PU 7' until packoff came out of sealing area and pressure dropped off. Circulate at 500 gpm to move cement up hole away from liner top. Pull up 2' to expose dog sub & slack off 50 klbs to set L TP. Rotate to ensure fully set. 08:15 - 10:00 1.75 CEMT P PROD1 Circulate at 525 gpm to clear excess cement from hole. Reciprocate pipe while pumping. Estimate got back 10-15 bbls cement to surface. Dislpace to clean seawater @ 9 BPM @ 2000 psi. 10:00 - 10:30 0.50 CEMT P PROD1 Break out & lay down cement head. Rig down cement lines. 10:30 - 12:00 1.50 CEMT P PROD1 Slip & cut drill line. Service top drive. 12:00 - 19:00 7.00 CEMT P PROD1 POH LDDP from 10391', break & UD XO & liner running tool. 19:00 - 21 :30 2.50 CEMT P PROD1 M/U mule shoe & RIH with 29 stands of drill pipe from derrick. POH LDDP. 21 :30 - 22:30 1.00 WHSUR P RUNCMP Pull wear ring. Clear & clean rig floor. 22:30 - 23:30 1.00 RUNCO RUNCMP RlU tubing tongs & handling equipment. 23:30 - 00:00 0.50 RUNCO RUNCMP RlU & test casing to 4000 psi, record on chart, OK. 3/22/2005 00:00 - 11 :30 11.50 RUNCO RUNCMP RIH with 4.5" 12.6 #, L-80, TCII, completion string. Torque turn pipe, M/U = 3850 ft. Ibs. BakerLock all connections below packer. 11 :30 - 13:30 RUNCMP Space out tubing, run pup joints 1 joint down. Make up hanger & land tubing, RILDS. 13:30 - 16:30 RUNCMP RlU lines to annulus, reverse circulate 331 bbl of inhibited seawater @ 3 bpm @ 200 psi. Dry rod 2 way check valve & test to 1000 psi from below. 16:30 - 18:30 RUNCMP Blow down lines & nipple down BOPE. 18:30 - 23:00 WHDTRE Prepare wellhead, N/U adaptor flange & tree. Test void to 5000 psi, OK. Test tree, not holding, R/U DSM & pull 2 way check valve. Dry rod new TWC valve & test to 5000 psi, OK. Pull TWC & RID lubricator. 23:00 - 00:00 1.00 RUNCMP RlU circ. lines to Hot Oil Service truck. Test lines to 4500 psi. Pump 155 bbl of diesel freeze protect. 3/23/2005 00:00 - 02:30 2.50 RUNCMP Pump diesel freeze protect down annulus. U-tube to tubing. Freeze protect to +- 2300'. 02:30 - 04:30 RUNCMP Set 4.5" X 7" Baker packer with 4200 PSI and test tubing. R/U Printed: 3/28/2005 8:05:37 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-33 03-33 REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 3/7/2005 Rig Release: 3/23/2005 Rig Number: 2 Spud Date: 7/26/1984 End: 04:30 - 05:00 05:00 - & test annulus to 4000 psi, record on chart, OK. Witness of test waived by Chuck Scheve with the AOGCC. Test witnessed by WSL James Willingham. RUNCMP Set back pressure valve. RUNCMP RID DSM & Little Reds Hot Oil Service. Secure well. Release rig @ 0600 hrs. Printed: 3/28/2005 8:05:37 AM . . 03-33B Prudhoe Bay Unit 50-029-21142-02-00 205-018 Accept: Spud: Release: Ri: 03/08/05 03/14/05 03/23/05 Nabors 2ES POST RIG WORK 03/28/05 VALVE CREW PULLED BPV. PULLED BALL & ROD FROM 10372' SLM. PULLED RHC FROM 10379' SLM. DRIFTED WI 10' X 27/8" DUMMY GUN TO 10974' SLM (-79 DEGREES DEV.) 04/01/05 MU BOT MHA WIPDS MEM GR/CCL IN 2.375" OD CARRIER W/3.0" OD JSN AND RIH TO 4500', SWAP BACKSIDE TO 60/40 AND CONTINUE RIH. TAG BOTTOM AT 12991' CTD, LOG TIE IN PASS I JEWELRY FROM 12991' TO 10000'. MU 25' GUN, SWS 2.875" PJ HMX, 6 SPF. 04/02105 ADD PERF, RIH WITH SWS GUN #1,25' OF 2.875" PJ HMX, 6 SPF, TIE INTO FLAG, TAG AT 12977' ELMD, DECISION MADE TO SHOOT GUN HIGH, SHOOT INTERVAL 12950' - 12976'. MU GUN #2, 25' OF 2.875" PJ HMX, 6 SPF. CORRECT TOP SHOT AT FLAG AND RIH. TAG AT 12949'. DECISION MADE TO SHOOT SECOND INTERVAL FROM 12923' - 12949' AND POOH WHILE KEEPING WELL FULL. AT SURFACE PERFORM SHORT INJECTIVITY TEST W 60/40 METHANOL WATER 0.5 BPM AT 1127 PSI. (EST HYDROSTATIC PRESSURE = -3650 PSI). MU GUN # 3,25' OF 2.875" PJ HMX, 6 SPF. TAG AT 12941', SHOOT THIRD INTERVAL FROM 12905' -12930'. MU GUN #4, 25' OF 2.875" PJ HMX, 6 SPF. 04/03/05 PERF I FCO, MU GUN #4, 25' OF SWS 2.875" PJ HMX, 6-SPF, SHOOT INTERVAL FROM 12880' - 12905'. POOH, PERFORM PRE FCO INJECTIVITY TEST, 1.0 BPM AT 1480 PSI, INCREASED RATE TO 1.5 BPM AND WHP WAS STILL INCREASING AT 2000 PSI WHP. MU 2.25" OD JSN, RIH FOR SOFT TAG AT 12,955' CTM. CLEANED OUT TO 12,978' CTM AND HAD HARD TAG. COULD NOT MAKE ANY HOLE. THIS LOOKS TO BE THE BAKER LANDING COLLAR W/PLUG. LAUNCHED FLO PRO SWEEP AND CHASED OUT AT 40% THROUGH HORIZONTAL SECTION AND THEN 80% OOH. COIL PIN-HOLED WHILE POOH, FP WITH 60/40 METHANOL WATER. BLOW COIL DOWN FOR REEL SWAP. 04/04/05 DRIFT COIL, PERFORM BOP TEST, PUMP 1.25" BALL, LOST SAME, FOUND BALL IN CHOKE, RIH WI 2.25" JSN PREPPING WELL FOR ACID TREAT. 04/05/05 TREATMENT, RIH WI 2.25" JSN, TAG AT 12975' CTM, SWAP HOLE TO FILTERED 1% KCL, ESTABLISH INITIAL INJECTIVITY DOWN COIL WI FILTERED 1% KCL 1.4 BPM AT 1650 PSI WHP (NORMALIZED INJECTIVITY 0.98 BPD/PSI). PUMP 25 BBLS NH4CL, 2~L§ßO/2gJg~£.PADAÇ!Q, 25 BBLS 9:1 MUD ACID, 40 BBLS NH4CL, 10 BBLS OIL SEEKER DIVERTER, 10 BBLS NH4CL, 25 BBLS DApAyID, 25BBLSJy1LJD . ACID, 100 BBLS NH4CL FLUSH. WHP DROPPED TO 20 PSI AND THEN SLÓWL Y CLIMBED BACK T0300 PSI WHILE PUMPING NH4CL OVER FLUSH. OVER DISPLACED ENTIRE JOB WITH 25 BBLS NH4CL FOLLOWED BY 390 BBLS FILTERED 1% KCL. FINAL INJECTIVITY 4.3 BPM AT 950 PSI. (NORMALIZED INJECTIVITY 4.5 BPD/PSI). FREEZE PROTECTED TUBING W/38 BBLS 60/40 METHANOL WATER. CONTACT DSO WIFINAL WELL STATUS. COMPLETE FREEZE PROTECT TAG AND HANG ON TUBING. HANG CAUTION TAG ON IA TO WATCH FOR THERMAL EXPANSION. CONTACT EOC WIFINAL WELL STATUS. WELL LEFT SHUT-IN. JOB COMPLETE. DEFINITIVE Halliburton Sperry-Sun North Slope Alaska BPXA 03-33 - 3-33B . Job No. AKZZ3591175, Surveyed: 20 March, 2005 Survey Report 8 April, 2005 Your Ref: API 50029211420200 Surface Coordinates: 5936277.89 N, 714114.38 E (70013' 43.7851" N, 148016'18.1355" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 56.39ft above Mean Sea Level . SPE!I""'I""'Y-SUf1 OFULLtNG SeAVn:eS A Halliburton Company Survey Ref: svy4514 Halliburton Sperry-Sun Survey Report for 03-33 - 3-33B Your Ref: API 50029211420200 Job No. AKZZ3591175, Surveyed: 20 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9494.39 44.100 78.300 7875.37 7931.76 2126.15N 3453.68 E 5938501.21 N 717506.32 E 4024.98 Tie On Point MWD+IIFR+MS 9594.00 43.520 78.890 7947.25 8003.64 2139.78 N 3521.28 E 5938516.76 N 717573.50 E 0.712 4086.27 Window Point 9619.51 44.470 83.000 7965.60 8021.99 2142.57 N 3538.77 E 5938520.04 N 717590.91 E 11 .793 4101.67 9713.98 44.510 83.570 8033.00 8089.39 2150.31 N 3604.52 E 5938529.64 N 717656.41 E 0.425 4157.84 9805.64 43.070 84.130 8099.16 8155.55 2157.11 N 3667.58 E 5938538.23 N 717719.26 E 1.627 4211.32 . 9899.88 41.330 80.670 8168.98 8225.37 2165.44 N 3730.31 E 5938548.34 N 717781.72 E 3.080 4265.51 9993.49 40.700 82.990 8239.62 8296.01 2174.18 N 3791 .11 E 5938558.80 N 717842.25 E 1.760 4318.44 10085.02 40.870 83.250 8308.92 8365.31 2181.34 N 3850.47 E 5938567.64 N 717901.38 E 0.263 4369.26 10177.94 42.750 83.510 8378.18 8434.57 2188.48 N 3912.00 E 5938576.53 N 717962.68 E 2.032 4421.76 10271.38 44.270 82.670 8445.94 8502.33 2196.23 N 3975.86 E 5938586.08 N 718026.30 E 1.740 4476.46 10364.68 43.400 82.440 8513.25 8569.64 2204.60 N 4039.93 E 5938596.27 N 718090.11 E 0.948 4531.71 10458.08 42.140 81.730 8581.81 8638.20 2213.33 N 4102.75 E 5938606.78 N 718152.65 E 1 .444 4586.21 1 0522.40 42.440 81.580 8629.39 8685.78 2219.61 N 4145.57 E 5938614.27 N 718195.28 E 0.492 4623.57 10596.95 42.710 81.020 8684.29 8740.68 2227.24 N 4195.43 E 5938623.31 N 718244.90 E 0.624 4667.26 10690.23 43.690 80.340 8752.28 8808.67 2237.58 N 4258.43 E 5938635.44 N 718307.59 E 1.163 4722.92 10724.36 47.490 80.840 8776.16 8832.55 2241.56 N 4282.48 E 5938640.10 N 718331.51 E 11.183 4744.19 10755.58 51.860 81.000 8796.36 8852.75 2245.32 N 4305.98 E 5938644.52 N 718354.90 E 14.003 4764.88 10783.29 55.930 82.000 8812.69 8869.08 2248.62 N 4328.12 E 5938648.45 N 718376.93 E 14.974 4784.23 10815.60 59.910 80.450 8829.84 8886.23 2252.81 N 4355.17 E 5938653.40 N 718403.85 E 12.971 4807.96 10847.52 63.230 77.180 8845.04 8901.43 2258.26 N 4382.69 E 5938659.64 N 718431.21 E 13.758 4832.86 10877.62 67.580 75.690 8857.57 8913.96 2264.68 N 4409.29 E 5938666.81 N 718457.61 E 15.136 4857.64 10908.97 71.540 74.590 8868.51 8924.90 2272.22 N 4437.68 E 5938675.15 N 718485.77 E 13.052 4884.51 . 10941.51 75.390 71.760 8877. 77 8934.16 2281.25 N 4467.52 E 5938685.03 N 718515.35 E 14.473 4913.46 10970.76 79.440 69.760 8884.15 8940.54 2290.66 N 4494.47 E 5938695.20 N 718542.02 E 15.370 4940.37 11001.36 83.940 67.520 8888.57 8944.96 2301.69N 4522.66 E 5938707.02 N 718569.88 E 16.392 4969.27 11033.62 88.460 65.880 8890.71 8947.10 2314.42 N 4552.21 E 5938720.59 N 718599.07 E 14.901 5000.30 11064.63 88.580 64.540 8891.51 8947.90 2327.42 N 4580.35 E 5938734.38 N 718626.83 E 4.337 5030.40 11096.12 88.830 59.820 8892.22 8948.61 2342.11 N 4608.19 E 5938749.85 N 718654.24 E 15.006 5061.31 11127.44 90.310 54.970 8892.46 8948.85 2358.98 N 4634.56 E 5938767.46 N 718680.12 E 16.189 5092.44 11157.68 91.850 50.720 8891.88 8948.27 2377.23 N 4658.65 E 5938786.39 N 718703.68 E 14.946 5122.66 11189.46 91.480 45.310 8890.96 8947.35 2398.47 N 4682.26 E 5938808.30 N 718726.68 E 17.056 5154.36 11221.52 90.310 40.090 8890.46 8946.85 2422.02 N 4703.99 E 5938832.45 N 718747.73 E 16.684 5186.04 11251.97 89.510 35.610 8890.51 8946.90 2446.06 N 4722.67 E 5938857.01 N 718765.72 E 14.945 5215.64 11282.41 90.490 29.340 8890.51 8946.90 2471.73 N 4739.00 E 5938883.13 N 718781.32 E 20.848 5244.43 11314.09 90.560 25.480 8890.22 8946.61 2499.85 N 4753.59 E 5938911.65 N 718795.10 E 12.186 5273.39 8 April, 2005 - 10:30 Page 2 of4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 03-33 - 3-33B Your Ref: API 50029211420200 Job No. AKZZ3591175, Surveyed: 20 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11344.90 90.560 21.360 8889.92 8946.31 2528.11 N 4765.83 E 5938940.25 N 718806.53 E 13.372 5300.61 11377.60 91.600 15.800 8889.30 8945.69 2559.09 N 4776.24 E 5938971.51 N 718816.06 E 17.295 5328.09 11409.92 90.800 11.150 8888.62 8945.01 2590.50 N 4783.77 E 5939003.13 N 718822.69 E 14.596 5353.60 11438.04 90.800 10.690 8888.23 8944.62 2618.11 N 4789.10 E 5939030.88 N 718827.23 E 1.636 5375.01 11530.79 91.850 14.300 8886.08 8942.47 2708.62 N 4809.15 E 5939121.92 N 718844.71 E 4.052 5447.22 11624.43 90.560 14.240 8884.11 8940.50 2799.35 N 4832.23 E 5939213.27 N 718865.21 E 1.379 5521.93 . 11718.89 91.300 16.040 8882.58 8938.97 2890.52 N 4856.89 E 5939305.10 N 718887.27 E 2.060 5598.15 11811.50 92.41 0 15.630 8879.58 8935.97 2979.56 N 4882.15 E 5939394.83 N 718909.99 E 1.278 5673.51 11905.45 91.730 15.980 8876.19 8932.58 3069.90 N 4907.72 E 5939485.85 N 718932.99 E 0.814 5749.92 11999.18 93.080 14.890 8872.26 8928.65 3160.17 N 4932.65 E 5939576.79 N 718955.34 E 1.851 5825.78 12092.53 91.110 14.030 8868.84 8925.23 3250.50 N 4955.94 E 5939667.74 N 718976.06 E 2.302 5900.41 12185.88 91.050 14.790 8867.08 8923.47 3340.89 N 4979.17 E 5939758.76 N 718996.71 E 0.817 5975.03 12279.60 91 .480 15.600 8865.02 8921.41 3431.31 N 5003.72 E 5939849.84 N 719018.70 E 0.978 6050.70 12373.17 92.040 16.340 8862.14 8918.53 3521.23 N 5029.46 E 5939940.45 N 719041.86 E 0.991 6126.97 12466.55 91.050 16.310 8859.62 8916.01 3610.81 N 5055.69 E 5940030.74 N 719065.55 E 1.061 6203.43 12560.39 89.140 16.820 8859.47 8915.86 3700.75 N 5082.45 E 5940121.41 N 719089.74 E 2.107 6280.51 12650.04 89.750 16.800 8860.34 8916.73 3786.57 N 5108.37 E 5940207.92 N 719113.22E 0.681 6354.38 12744.37 90.120 17.020 8860.44 8916.83 3876.82 N 5135.81 E 5940298.92 N 719138.08 E 0.456 6432.19 12835.85 90.190 17.100 8860.20 8916.59 3964.27 N 5162.65 E 5940387.10 N 719162.43 E 0.116 6507.79 12930.83 89.940 17.040 8860.09 8916.48 4055.07 N 5190.53 E 5940478.65 N 719187.72 E 0.271 6586.29 13002.84 90.000 16.290 8860.13 8916.52 4124.05 N 5211.18 E 5940548.19 N 719206.40 E 1.045 6645.51 13072.00 90.000 16.290 8860.13 8916.52 4190.44 N 5230.58 E 5940615.10 N 719223.91 E 0.000 6702.14 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 51.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13072.00ft., The Bottom Hole Displacement is 6702.14ft., in the Direction of 51.300° (True). 8 April, 2005 - 10:30 Page 3 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 03-33 - 3-33B Your Ref: API 50029211420200 Job No. AKZZ3591175, Surveyed: 20 March, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastíngs (ft) (ft) (ft) Comment 9494.39 9594.00 13072.00 7931.76 8003.64 8916.52 2126.15N 2139.78 N 4190.44 N 3453.68 E 3521.28 E 5230.58 E Tie On Point Window Point Projected Survey . Survey tool program for 03-33 - 3-338 From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9494.39 0.00 9494.39 7931.76 13072.00 7931.76 Tolerable Gyro - BOSS-GYRO (03-33) 8916.52 MWD+IIFR+MS (3-33B) . 8 April, 2005· 10:30 Page 4 of4 DrillQuest 3.03.06.008 ~, Halliburton Sperry-Sun North Slope Alaska BPXA 03-33 - 3-33B (rowd) . Job No. AKMW3591175, Surveyed: 20 March, 2005 Survey Report 8 April, 2005 Your Ref: API 500292114202 Surface Coordinates: 5936277.89 N, 714114.38 E (70013'43.7851" N, 148016' 18.1355" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 56.39ft above Mean Sea Level . spE!r"'ray-suf"'! DAILLING 'SeAVICeS A Halliburton Company Survey Ref: svy4515 Halliburlon Sperry-Sun Survey Report for 03-33 - 3-33B (mwd) Your Ref: API 500292114202 Job No. AKMW3591175, Surveyed: 20 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 9494.39 44.100 78.300 7875.37 7931.76 2126.15 N 3453.68 E 5938501.21 N 717506.32 E 4024.98 Tie On Point MWD Magnetic 9594.00 43.520 78.890 7947.25 8003.64 2139.78 N 3521.28 E 5938516.76 N 717573.50 E 0.712 4086.27 Window Point 9619.51 44.470 83.000 7965.60 8021.99 2142.57 N 3538.77 E 5938520.04 N 717590.91 E 11 .793 4101.67 9713.98 44.510 77.430 8033.02 8089.41 2153.81 N 3603.96 E 5938533.12 N 717655.75 E 4.131 4159.59 9805.64 43.070 84.150 8099.22 8155.61 2164.00 N 3666.49 E 5938545.08 N 717717.97 E 5.309 4214.78 . 9899.88 41.330 80.140 8169.05 8225.44 2172.61 N 3729.17 E 5938555.47 N 717780.38 E 3.402 4269.10 9993.49 40.700 82.570 8239.68 8296.07 2181.85N 3789.89 E 5938566.43 N 717840.82 E 1.832 4322.28 10085.02 40.870 83.680 8308.99 8365.38 2189.00 N 3849.25 E 5938575.27 N 717899.95 E 0.814 4373.10 10177.94 42.750 83.850 8378.25 8434.64 2195.73 N 3910.83 E 5938583.74 N 717961.31 E 2.027 4425.38 10271.38 44.270 82.740 8446.01 8502.40 2203.25 N 3974.72 E 5938593.07 N 718024.96 E 1.821 4479.95 10364.68 43.400 82.180 8513.31 8569.70 2211.73N 4038.77 E 5938603.36 N 718088.75 E 1.021 4535.27 10458.08 42.140 82.480 8581.87 8638.26 2220.19 N 4101.63 E 5938613.61 N 718151.34 E 1.367 4589.63 10522.40 42.440 81.360 8629.46 8685.85 2226.28 N 4144.48 E 5938620.91 N 718194.00 E 1.261 4626.89 10596.95 42.710 81.020 8684.35 8740.74 2234.00 N 4194.32 E 5938630.04 N 718243.60 E 0.476 4670.63 10690.23 43.690 80.530 8752.35 8808.74 2244.24 N 4257.35 E 5938642.07 N 718306.31 E 1.110 4726.23 10724.36 47.490 80.940 8776.23 8832.62 2248.16 N 4281.40 E 5938646.67 N 718330.25 E 11.167 4747.47 10755.58 51.860 81.070 8796.43 8852.82 2251.88 N 4304.91 E 5938651.05 N 718353.64 E 14.001 4768.14 10783.29 55.930 82.030 8812.75 8869.14 2255.17 N 4327.05 E 5938654.97 N 718375.68 E 14.952 4787.48 10815.60 59.910 80.550 8829.91 8886.30 2259.32 N 4354.10 E 5938659.88 N 718402.60 E 12.915 4811.20 10847.52 63.230 77.250 8845.11 8901.50 2264.73 N 4381.64 E 5938666.08 N 718429.97 E 13.813 4836.08 10877.62 67.580 75.780 8857.63 8914.02 2271.12 N 4408.24 E 5938673.22 N 718456.38 E 15.118 4860.84 10908.97 71.540 74.270 8868.58 8924.97 2278.71 N 4436.61 E 5938681.61 N 718484.53 E 13.413 4887.74 . 10941.51 75.390 71.700 8877.84 8934.23 2287.85 N 4466.43 E 5938691.59 N 718514.07 E 14.046 4916.72 10970.76 79.440 69.780 8884.21 8940.60 2297.26 N 4493.37 E 5938701.77 N 718540.74 E 15.256 4943.64 11001.36 83.940 67.600 8888.64 8945.03 2308.27 N 4521.57 E 5938713.57 N 718568.61 E 16.307 4972.53 11033.62 88.460 65.780 8890.77 8947.16 2321.00 N 4551.12 E 5938727.13 N 718597.79 E 15.099 5003.56 11064.63 88.580 64.450 8891.57 8947.96 2334.05 N 4579.24 E 5938740.97 N 718625.53 E 4.305 5033.67 11096.12 88.830 59.020 8892.29 8948.68 2348.95 N 4606.96 E 5938756.65 N 718652.81 E 17.257 5064.62 11127.44 90.310 54.210 8892.52 8948.91 2366.18 N 4633.10 E 5938774.62 N 718678.46 E 16.067 5095.80 11157.68 91.850 50.300 8891.95 8948.34 2384.68 N 4657.01 E 5938793.79 N 718701.82 E 13.894 5126.02 11189.46 91 .480 44.390 8891.03 8947.42 2406.20 N 4680.36 E 5938815.96 N 718724.56 E 18.625 5157.70 11221.52 90.310 39.350 8890.53 8946.92 2430.06 N 4701.75 E 5938840.42 N 718745.26 E 16.136 5189.31 11251.97 89.510 35.110 8890.57 8946.96 2454.30 N 4720.16 E 5938865.17 N 718762.98 E 14.170 5218.83 11282.41 90.490 29.690 8890.57 8946.96 2479.99 N 4736.47 E 5938891.32 N 718778.55 E 18.094 5247.62 11314.09 90.560 25.820 8890.28 8946.67 2508.02 N 4751.22 E 5938919.75 N 718792.50 E 12.217 5276.65 8 April, 2005 - 10:23 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 03-33 - 3-33B (mwd) Your Ref: API 500292114202 Job No. AKMW3591175, Surveyed: 20 March, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 11344.90 90.560 21.740 8889.98 8946.37 2536.21 N 4763.64 E 5938948.28 N 718804.11 E 13.242 5303.95 11377.60 91.600 16.180 8889.37 8945.76 2567.11 N 4774.26 E 5938979.48 N 718813.85 E 17.295 5331.56 11409.92 90.800 11 .370 8888.69 8945.08 2598.49 N 4781.95 E 5939011.06 N 718820.65 E 15.084 5357.17 11438.04 90.800 10.920 8888.30 8944.69 2626.07 N 4787.38 E 5939038.79 N 718825.30 E 1.600 5378.65 11530.79 91.850 14.910 8886.15 8942.54 2716.43 N 4808.10 E 5939129.70 N 718843.44 E 4.447 5451.28 11624.43 90.560 14.800 8884.18 8940.57 2806.92 N 4832.10 E 5939220.83 N 718864.87 E 1.383 5526.56 . 11718.89 91.300 16.490 8882.65 8939.04 2897.87 N 4857.57 E 5939312.46 N 718887.74 E 1.953 5603.27 11811.50 92.410 16.100 8879.65 8936.04 2986.71 N 4883.54 E 5939402.01 N 718911.18 E 1.270 5679.06 11905.45 91.730 16.420 8876.26 8932.65 3076.84 N 4909.83 E 5939492.85 N 718934.90 E 0.800 5755.90 11999.18 93.080 15.350 8872.32 8928.71 3166.91 N 4935.46 E 5939583.61 N 718957.97 E 1.837 5832.19 12092.53 91.110 14.400 8868.91 8925.30 3257.07 N 4959.41 E 5939674.41 N 718979.34 E 2.343 5907.22 12185.88 91.050 15.170 8867.15 8923.54 3347.31 N 4983.23 E 5939765.29 N 719000.59 E 0.827 5982.20 12279.60 91.480 16.020 8865.08 8921.47 3437.55 N 5008.42 E 5939856.22 N 719023.21 E 1.016 6058.26 12373.17 92.040 16.740 8862.21 8918.60 3527.28 N 5034.79 E 5939946.66 N 719047.03 E 0.975 6134.92 12466.55 91.050 16.590 8859.69 8916.08 3616.71 N 5061.56 E 5940036.80 N 719071.25 E 1.072 6211.69 12560.39 89.140 17.170 8859.54 8915.93 3706.50 N 5088.81 E 5940127.33 N 719095.93 E 2.127 6289.07 12650.04 89.750 17.530 8860.40 8916.79 3792.07 N 5115.54E 5940213.63 N 719120.23 E 0.790 6363.41 12744.37 90.120 17.690 8860.51 8916.90 3881.98 N 5144.08 E 5940304.31 N 719146.20 E 0.427 6441.87 12835.85 90.190 17.540 8860.26 8916.65 3969.17 N 5171.76E 5940392.25 N 719171.40 E 0.181 6517.96 12930.83 89.940 17.400 8860.16 8916.55 4059.76 N 5200.27 E 5940483.62 N 719197.33 E 0.302 6596.83 13002.84 90.000 16.750 8860.19 8916.58 4128.60 N 5221.42 E 5940553.03 N 719216.51 E 0.906 6656.35 13072.00 90.000 16.750 8860.19 8916.58 4194.83 N 5241.35 E 5940619.79 N 719234.55 E 0.000 6713.29 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. . Vertical depths are relative to Well. Northings and Eastings are relative to Well. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well and calculated along an Azimuth of 51.330° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 13072.0Oft., The Bottom Hole Displacement is 6713.29ft., in the Direction of 51.329° (True). 8 April, 2005 - 10:23 Page 3 of4 DríllQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for 03·33 - 3-33B (mwd) Your Ref: API 500292114202 Job No. AKMW3591175, Surveyed: 20 March, 2005 North Slope Alaska BPXA Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9494.39 9594.00 13072.00 7931.76 8003.64 8916.58 2126.15N 2139.78N 4194.83 N 3453.68 E 3521.28 E 5241.35 E Tie On Point Window Point Projected Survey . Survey tool prOgram for 03-33 - 3-338 (mwd) From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9494.39 0.00 9494.39 7931.76 13072.00 7931.76 Tolerable Gyro - BOSS-GYRO (03-33) 8916.58 MWD Magnetic (3-338 (mwd)) . 8 April, 2005 - 10:23 Page 4 of 4 DríllQuest 3.03.06.008 . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 . DEFINITIVE Re: Distribution of Survey Data for Well 3-338 Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,494.39' MD 9,594.00' MD 13,072.00' MD (if applicable) 24-Apr-05 PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ;Z 7 ~,(C) d 5- Signed Û IJfLeA I- Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Altachment(s) ~ f) 7 - ~ó { ~ . . AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well 3-338 MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,494.39' MD 9,594.00' MD 13,072.00 I MD (if applicable) PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLlBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ) 74pÀDif\ Signed ~~oiÁ) I Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) 24-Apr-05 ;Æòr--D1'ß . . ((ù ,~, i¡"'\1.''U.' ~~ FRANK H. MURKOWSKI, GOVERNOR A1tASIiA. OIL AlQ) GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay 03-33B BP Exploration (Alaska) Inc. Permit No: 205-018 Surface Location: 215' NSL, 821' EWL, SEC. 11, TI0N, RI5E, UM Bottornhole Location: 4403' NSL, 783' EWL, SEe. 12, TlON, RI5E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above service well. This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission t 'tness any required test. Contact the Commission's petroleum field inspector at 907 659 ager). DATED this~y of February, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. { . STATE OF ALASKA . ALAS~OIL AND GAS CONSERVATION ~MMISSIO~ PERMIT TO DRILL j"i( \lJGA- '4'1/2-005 o Drill IBI Redrill 1 a. Type of work 0 Re-Entry 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 4a. Location of Well (Governmental Section): Surface: 215' NSL, 821' EWL, SEC. 11, T10N, R15E, UM Top of Productive Horizon: 2522' NSL, 103' EWL, SEC. 12, T10N, R15E, UM Total Depth: 4403' NSL, 783' EWL, SEC. 12, T10N, R15E, UM 4b. Location of Well (State Base Plane Coordinates): Surface: X-714114 y- 5936278 Zone- ASP4 16. Deviated Wells: Kickoff Depth: 9650 feet Maximum Hole Angle: 92 decrees 20 AAC 25.005 FEB U4 ¿UûJ 11 b. Current Well ClaÖ Stratigraphic Test i ~~~?~:to~R;Y::;;:::;.~~s..>S¡~Ö~~~~;~n 5. Bond: if Blanket 0 Single Well 11. Well N~~.Çll)d~mber: , Bond No. 2S100302630-277 'PBO~-33B / 6. Proposed Depth: 12. Field / Pool(s): MD 13089 TVD 8916 Prudhoe Bay Field / Prudhoe Bay 7. Property Designation: Pool ADL 028327 8. Land Use Permit: 13. Approximate Spud Date: March 1, 2005 /" 14. Distance to Nearest Property: 15,850' 9. Acres in Property: 2560 18... casing Program: Size. Casino 7" 7" 4-1/2" Hole 8-1/2" N/A 6-1/8" Weioht 26# 26# 12.6# Specifications Grade Couolino L-80 BTC-M L-80 BTC-M L-80 IBT-M Lenoth 1053' 6500' 2686' 10. KB Elevation Planned 15. Distance to Nearest Well Within Pool (Height above GL): 56.4 feet 09-20 is 873' away at 12,885' MD ,..' 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3250 Surface: 2380 To;ettlng DéPt~ttom '. UU(~?f~~r°Ja~~~ént MD TVD MD TVD Jincluding staoe data) 9500' 7932' 10553' 8710' 29 sx Class 'G' 0/ 3000' 2992' 9500' 7932' 95 sx Class 'G', 136 sx Class 'G' ,- 10403' 8600' 13089' 8916' 20 sx Class 'G' ,. 19. PRESENT WELL CONDITION SUMMARY (To bè completedfot RednllAND Ré"'entry operâtiOO$) Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): IEffective Depth TVD (ft): 13150 8902 11350 11350 8933 I Casino Length Size Cement Volume MD ~trlJr.t1J r;:¡ I Conductor Junk (measured): 11290 TVD I Pr .... "i n Liner 110' 2506' 10374' 20" 13-3/8" 9-5/8" 1910# Poleset 2300 sx CS III, 400 sx CS II 500 sx Class 'G', 300 sx CS I 110' 2506' 10374' 110' 2506' 8706' Liner 237' 3016' 7" 2-7/8" 00 sx Class 'G' 118 sx Class 'G' 10165' - 10402' 10134' - 13150' 8500' - 8734' 8470' - 8902' Perforation Depth MD (ft): 10520' - 131M' 20. Attachments if Filing Fee, $100 0 BOP Sketch o Property Plat 0 Diverter Sketch IPerfOration Depth TVD (ft): 8848' - 8899' if Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis o Seabed Report if Drilling Fluid Program if 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Printed Name BiIIlsaacson Title Senior Drilling Engineer Sionature L -Jk _ Phone 564-5521 Date 7-';'105 Commission Use Only Permit To Drill API Number: I Permit Approval I See cover letter for Number: ::::¡"O,S'- 0/ f 50- 029-21142-02-00 Date: other requirements Conditions of Approval: Samples Required 0 Yes ~No Mud Log Required 0 Yes ~No H~en Sulfide Measures ~es LJ No Directional Survey Required Ji(Yes 0 No Other:mTe ~t ß~~ 4-000 e~¿, M IT / ~ t4A~& 'I ¡,{AJ, ~ Ì?C¡ r'~u.b~ (I. p~ r.,,~· ~s (h}(I)¡ Q.,ltwH.c,-t~ '/Jof£- ìg D<1)pWJ&eJ, ., r~ ~~ '"" n R 1 ~ i \\ I A l APPROVED BY , //~.,. J /' AODroved-r:rv: ~ / Y -- \.. __ "\ I l"1 ¡ ¡ .. . THE COMMISSION Date _U /Y/ ~ Form 10-40~sed..,Itfá>04 SUbmit fn Duplicate Date: Contact Dave Wesley, 564-5153 Prepared By NameINumber. Terrie Hubble, 564-4628 . . I Well Name: I Well 03-33Bi I AFE Number: I PBD 4P2354 I Surface Location Target Location Bottom Location 03-338i Planned Well SUmmary Well Type Horizontal Sidetrack Injector Target Objective Zone 2 I API Number: I 50-029-21142-02 Offsets 214' FSL /821' FWL TRS 10N,15E,11 / Offsets 2,522' FSL / 103' FWL TRS 10 N, 15 E, 12 Offsets 877' FNL / 783' FWL TRS 10N,15E,12 ,/ I Planned KOP: I 9,650' md /8,045' tvd I Rig: I Nabors 2ES I / I Planned TD: 113,089' md / 8,916' tvd I I I 56.40' I RTE: I CBE: 127.90' Directional ProQram Wp05 Exit oint: 9,650' md I 7,989' sstvd -92.0° from -11,400' to -12,370' in the planned 6 1/8" production section. There are no close approach issues in drilling 3-33Bi. All surrounding wells ass ma'or risk criteria. Standard MWD with IIFR I Cassandra. Well 09-20, with center-to-center distance of -873' at 12,885' md. 15,850' to the nearest PBU ropert line. LOQQinQ PrOQram Hole Section: Required Sensors I Service 8 1/2" intermediate: Real time MWD Dir/GR/PWD throuahout the interval 6 1/8" production: Real time MWD Dir/GR/Res/ABI throughout the interval. Two sample catchers. Cased Hole: USIT to confirm 7" liner cement quality Open Hole: None planned 03-33Bi Sidetrack Page 1 . . Mud Pro~ram PV 10 -15 YP 40+ Tau 0 3-7 PV 12 -16 PV 8-12 CasinQ I Tubin~ Proaram Hole Casingrrubing Wt. Grade Connection Length Top Bottom Size Size md I tvd md I tvd 81/2" 7" 26.0# L-80 BTC-M 1,053' 9,500' I 7,932' 10,553' I 8,710' 8.681" 7" 26.0# L-80 BTC-M 6,500' 3,000' I 2,992' 9,500' I 7,932' 61/8" 4 Y2" 12.6# L-80 IBT-M 2,686' 10,403'/8,600' 13,089' I 8,916' Tubing 4 Y2" 12.6# L-80 TC- 10,403' Surface 10,403'1 8,600' Slurry Design Basis: Fluids Sequence I Volume: Slurry Design Basis: Fluids Sequence I Volume: Slurry Design Basis: Fluids Sequence I Volume: 03-33Bi Sidetrack Cementin~ ProQram 7", 26#, L-80, BTC-M drillin liner Lead slurry: None planned. Tail slurry: 903' of 7" X 81/2" annulus with 40% excess, plus -86' of 7", 26.0#, shoe track, plus 150' of 9 5/8" X 7" liner lap, plus 200' of 9 5/8" X 4" drill i e annulus. Pre-Flush None lanned S acer 35bbls MudPUSH at 11.4 Lead Slur None tanned Tail Slur 48.0bbl I 265cf I 229 sx Class 'G', 15.8 ; 1.16 cf/sk. ; 2.09 cf/sk. ; 1 .16 cf/sk. 41/2", 12.6#, L-80, IBT-M solid production liner Lead slurry: none planned Tail slurry: 2,536' of 41/2" X 61/8" annulus with 40% excess, plus 85' of 4 1/2",12.6# shoe track, plus 150' of 7" X 4 W' liner lap, plus 200' of 7" X 4" drill i e annulus. Pre-Flush 25bbls CW100 S acer 35bbls MudPUSH at 9.6 Lead Slur None lanned Tail Slur 69.0bbl 1383 cf I 320 sx Class 'G', 15.8 ; 1.20 cf/sk. /' Page 2 . . Casina I Formation Integrity Testing Test Test Point Test Type 30 min recorded FIT 30 min recorded FIT 30 min recorded Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: BOPE and drilling fluid system schematics are currently on file with the AOGCC. * Disposal Annular In'ection: Cuttings Handling: Fluid Handling: No annular injection in this well. Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at OS-04. An metal cuttin s should be sent to the North Slo e Borou h. All drilling and completion fluids and other Class 1/ wastes are to be hauled to OS-04 for in·ection. All Class I wastes are to be hauled to Pad 3 for dis osal. 03-33Bi Sidetrack Page 3 . . Geolo~lÌc Prognosis Formation MD TVDbkb TVDss Comments SV1 UG4 UG4A UG3 UG1 WS2 WS1 CM3 6,880 CM2 7,386 CM1 8,084 THRZ 8,423 BHRZ Truncated LCU Truncated TKNG Truncated TJG Truncated TJF Truncated TJE Truncated TJO Truncated TJC Truncated TJB Truncated TJA Truncated TSGR Truncated TSHA/TSAO 8,654 45SB 8,684 43N 8,704 43P 8,708 42N 8,730 42P 8,770 41N 8,774 41P 8,781 31N 8,792 31P 8,792 3,250psi @ 8,800'sstvd (-7.1pPQ EMW) 27N 8,836 27P 8,836 26N 8,900 26P 8,905 25N 8,908 MHO/HOT 8,988 p.S TD Criteria I TD Criteria: I Planned TO will be the given coordinates (Wp05). Fault Prognosis Fault Formation MD Intersect TVDss Estimated Direction of Uncertainty Encountered Intersect Throw Throw N/A 03-33Bi Sidetrack Page 4 . . Qperations Summary Pre-RiQ Operations: 1. The 5 W', 17.0#, L-80 PC tubing has a MERLA tubing patch installed over the #9GLM (deepest) at 10,023'. 2. An IA cement squeeze was performed 9/26/2000. The tubing was punched at -10,065'. Approximately 7bbls cement was squeezed into IA. Estimated cement top in IA is -9,950' md. 3. Last MIT-IA passed to 4,000psi on 11/02/2004. 4. Last MIT-OA passed to 2,000psi on 05/14/2002. Conduct an MIT-OA to 2,000psi. 5. Function all casing and tubing LDS and re-torque as recommended by Cameron. 6, R/U slick-line. RIH with lock-out tool and lock open the AVA TRSV. POOH. 7. R/U coiled tubing. RIH and plug and abandon the open perforations. Leave top of cement at -10,125'. The cement volume required is -17.0bbls. This is based upon 15' of 4 W', 12.6# tubing, and 1,212' of 27/8",6.5# liner, and approximately 10.0bbls to squeeze the open perforations. POOH. 8. Drift 5 W' tubing to top of cement plug at -10, 125'md, below the planned tubing cut depth of -9,700'md. POOH. 9. Pressure test cement plug to 1,000psi. 10. R/U SWS E-line. RIH with appropriate chemical cutter and cut the 5 W' tubing at -9,700'md. 11. Circulate the well to seawater through the tubing cut, until returns are clean. Conduct a CMIT T X IA to 3,000psi for 30 minutes. 12. Freeze protect to -2,200' MD with diesel. 13. Bleed casing and annulus pressures to zero. 14. Set a BPV. Secure the well. Level the pad as necessary. RiQ Operations: 1. MI I RU Nabors 2ES. 2. Pull BPV. Circulate out diesel freeze protection and displace the well to seawater. Install BPV. 3. Nipple down the tree. Inspect tubing hanger threads. Install "blanking plug" in hanger running thread. 4. Nipple up and test BOPE to 4,000psi. Pull blanking plug and BPV. 5. R/U. Pull the 5 W' tubing from the tubing cut at -9,700'md and above. Be prepared to spool up the AVA TRSV controlline. 6. M/U an 8 W' milling assembly and RIH, P/U 4" drill pipe. Tag the tubing stub at -9,700'. POOH. 7. R/U SWS E-line. M/U a HES 95/8" EZSV bridge plug. RIH with EZSV and set at -9,670'md. POOH and RID E-line. 8. R/U and pressure test the 9 5/8" casing to 4,OOOpsi for 30 minutes. Record the test. 9. N/D the BOPE stack and the tubing spool. CIO the 9 5/8" slips seal pack-off. N/U a new tubing spool. Test the pack-off. 10. N/U the BOPE stack and test. 11. a aker 9 5/8" whip stock assembly. RIH to the EZSV bridge plug. Orient as desired and set the whip stock on the EZSV. 12. Shear free from the whip stock. Displace the well to 10Appg LSND milling fluid. ..-i '_.' 13. Mill a window in the 9 5/8" casing at -9,650'md. Drill/mill approximately 20 feet beyond the middle of ./ I W\-(" \0 -4o( the window. offYOV~(. 14. Circulate the well clean. Pull into the 9 5/8" casing and attempt an FIT to 12.5ppg EMW. POOH. 15. M/U an 8 W' Dir/GR/Res/PWD assembly. RIH to the window. 16. Drill out and drill ahead, according to the directional program to section TD at the base of the HRZ I LCU. Circulate and condition the hole. POOH. 17. Run and cement the 7" liner. POOH with liner running tool. ,/ 18. R/U and run -6,500' of 7", 26.0#, L-80 scab liner. Tie into the drilling liner tie back sleeve. Cement the scab liner per Dowell program. POOH and UD liner running tool. - 19. M/U a 6 1/8" Dir/GR/Res/ABI drilling assembly. RIH to th~ab liner float equipment. 20. Test the casing X liner to 4,000psi. Record the test. 21. Drill out the scab liner float equipment. Continue RIH to the drilling liner float equipment. 22. R/U and test the casing X liner to 4,000psi for 30 minutes. Record the test. .// 03-33Bi Sidetrack Page 5 . . 23. Drill out the drilling liner float equipment to the liner shoe. Displace the well to 8.5ppg Flo-Pro drilling fluid. 24. Drill out the shoe plus -20 feet of new formation. Conduct an FIT to 10.0ppg EMW. 25. Drill ahead, per directional proposal, to the end of the high dogleg section at -11 ,500'md. POOH for /" horizontal BHA. 26. R/U SWS E-line. Run a USIT log from the 7" liner shoe to the top of the drilling liner at -9,500'md. /" POOH and RID E-line. 27. M/U a 61/8" Dir/GR/Res drilling assembly. RIH and drill ahead, per directional program, to section TO at -13,089'md. 28. Condition the hole for running 41/2",12.6#, L-80, IBT-M liner. POOH. / 29. Run and cement the 4 W' production liner, extending the liner lap to -150' above the 7" shoe. POOH. 30. R/U and pressure test the casing X liner to 4,000psi. Record the test. /" 31. R/U and run a 41/2", 12.6#, L-80, TC-II completion, stinging into the 41/2" liner tie back sleeve. ./ 32. Space out and land the completion. RILDS. 33. Install a TWC. 34. Nipple down the BOPE. Nipple up the tree and test to 5,000psi. Pull TWC. 35. Reverse circulate the well to seawater with Corrosion Inhibitor. 36. R/U LRHOS. Reverse in sufficient volume of diesel to freeze-protect the well to -2,200'md. Allow the diesel freeze protection fluid to U-tube to equilibrium. /" 37. Drop the ball and rod. Set the packer and individually test the tubing and annulus to 4,000psi for 30 minutes. Record each test. 38. Install SPY. Secure the well. 39. Rig down and move off. Post-Ria Operations: 1. MI I RU slick line. Pull the ball and rod I RHC plug from landing nipple below the production packer. 2. Install the well house, instrumentation, and flow line. 3. Post rig perforate via service coiled tubing per subsurface team. Estimated Pre-rig Start Date: 01/31/05 Estimated Spud Date: 03/01/05 Dave Wesley, Jr. Operations Drilling Engineer 564-5153 03-33Bi Sidetrack Page 6 . . Phase 1: Move In I Ria UP I Test BOPE Planned Phase Time 24 hours Planned Phase Cost $60,177 Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP Issues and Potential Hazards ~ No wells will require shut-in for the rig move onto 03-33A. However, 03-32 is 120.0' to the North, and 03-34 is 120.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. ~ During MI/RU operations, the 03-33A well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 5/14/2002 passed. ~ Prior to pulling the tree, verify there is a static column of brine to surface and that no pressure exists. ~ During ND/NU BOPE operations, the 03-33A well bore will be secured with the following barriers: o Tubing: the cement P&A plug, kill weight fluid, and a BPV/blanking plug. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. MIT-OA to 2,000psi on 5/14/2002 passed. ~ OS 03 is designated 8S an H:ß site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Closest well to SHL Latest H2S reading Closest well to BHL Latest H2S reading 03-32 470ppm 09-01 151 ppm 03-34 21 ppm 09-20 N/A The maximum level recorded of H2S on the pad was 470ppm, in 11/2001. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud 03-33Bi Sidetrack Page 7 . . Phase 2: De-complete Well Planned Phase Time 58 hours Planned Phase Cost $221,613 Reference RP .:. "De-completions" RP Issues and Potential Hazards ~ Monitor the well to ensure the fluid column remains static, prior to pulling the completion. ~ Have all wellhead and completion equipment NORM-tested, following retrieval. ~ Note that this wellhead is McEvoy Gen 3. The tubing hanger is likely a McEvoy Gen. 3, with 6 1/8" LH Acme top thread and 5 %" FMC 'ISA' SPV profile. It will be necessary to install a blanking plug for testing the SOPE. ~ Once the stack has been nippled down, verify the hanger thread and type in preparation for de- completion. Be prepared with the appropriate tubing spear, in the event it becomes necessary. ~ There is a 5112" AVA TRSV with a 14" control line. There were no records indicating the number of control lines bands used. ~ The 5 112" tubing X 9 5/8" casing annulus was squeezed with -7bbls cement on 9/27/2000. The cement squeeze was done to heal a suspected leak around the deepest (#1) GLM at 10,028'md. The estimated cement top in the annulus is -9,950'md. ~ Planned pre-rig work includes locking the TRSV open, permanently; to allow full 1.0. access should this be necessary for remedial tubing cutting during the de-completion phase. Phase 3: Run Whip Stock Planned Phase Time 35 hours ~ Planned Phase Cost $248,762 Reference RP .:. "Whip stock Sidetracks" RP Issues and Potential Hazards ~ No CBL data was available to determine the placement of cement behind the 9 5/8" casing. Based upon original cement job reports and volumetric calculations, it is likely that there is cement behind the 9 5/8" casing at the sidetrack point. ~ Once milling is complete, make sure all BOP equipment is operable. Follow standard rig procedure in thoroughly cleaning all areas in which metal cuttings may have settled 03-33Bi Sidetrack Page 8 . . Phase 5: Drill 8 1/2" Intermediate Hole Interval Planned Phase Time 47 hours Planned Phase Cost $258,080 Reference RP .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards ~ This well bore will exit the original well into the CM1 formation. This well bore will drill the remainder of the CM1 and HRZ to the LCU. The Kingak and Sag River formations are apparently truncated. The intermediate section will terminate at the LCU/lvishak transition. Previous DS 03 wells drilled the HRZ and Kingak with 9.8 to 10.6ppg mud weights. For this well, the HRZ will require a mud weight of 10.4ppg. Maintain mud weight at 10.4ppg, minimally, from above the HRZ to the 7" casing point. Follow all shale drilling practices to minimize potential problems. ~ n the worst-case scenario of 8.6ppg pore pressure at the Ivishak depth, a .Oppg at the 9 5/8" casing window, and 10.4ppg mud in the hole, the kick Phase 6: Run and Cement 7" Intermediate CasinQ Planned Phase Time 48 hours Planned Phase Cost $508,579 Reference RP .:. "Intermediate Casing and Cementing Guidelines" RP .:. "Freeze Protecting an Outer Annulus" RP .:. "Shale Drilling, Kingak and HRZ" RP Issues and Potential Hazards ~ Swab and surge pressure should be minimized with controlled casing running speeds and by breaking circulation slowly. Excessive swab / surge pressures could initiate HRZ / Kingak instability problems. ~ Differential Sticking is potentially a problem if lost circulation occurs or if the casing is left stationary across permeable formations. Proper casing centralization will facilitate minimizing the potential for differential sticking. ~ After running the intermediate drilling liner, a 7" scab liner will be run and cemented from /~ the existing 7" liner top at -9,500'md to -3,OOO'md. ~ It will be necessary to run a USIT log in the 7" drilling liner, to confirm adequate zonal isolation, as required for injection service. This log will be run during the first 6 1/8" interval bit trip. 03-33Bi Sidetrack Page 9 . . Phase 7: Drill 6 1/8" Production Hole Interval Planned Phase Time 145 hours Planned Phase Cost $806,246 Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" RP Issues and Potential Hazards ~ The parent well, 03-33, experienced no lost circulation events during drilling operations. ". There were no significant lost circulation events in any of the near surrounding wells. Þ- The planned well, 03-33Bi, is expected to cross no faults while drilling the production interval. ". If a request is made to extend the well bore beyond the planned TD coordinate, regardless the revised TD location relative to the polygon, contact the drilling engineer prior to drilling ahead. It will be prudent to confirm proximity clearance. Phase 9: Run 4%" Production Liner Planned Phase Time 33 hours Planned Phase Cost $238,173 Reference RP .:. "Modified Conventional Liner Cementing" RP Issues and Potential Hazards ~ The completion design is to run a 4 W', 12.6#, L-80 solid liner throughout the production interval. ~ Differential sticking is possible. The 8.6ppg Flo-Pro will be -600psi over balanced to the Ivishak Zone 2 formation. Minimize the time the pipe is left stationary while running the liner. ~ Sufficient 4 W' liner will be run to extend -150' back up into the 7" liner shoe. ~ Ensure the 4 W' liner top packer is set prior to POOH. Phase 12: Run 4 %" L-80 Completion Planned Phase Time 18 hours Planned Phase Cost $389,132 Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Issues and Potential Hazards ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. 03-33Bi Sidetrack Page 10 . . y The completion, as designed, will be to run a 4%", 12.6#, L-BO, TC-II production tubing string, stinging into the 4 %" liner tieback sleeve. Phase 13: ND/NU/Release Ria Planned Phase Time 21 hours Planned Phase Cost $64,155 Reference RP .:. "Freeze Protecting an Inner Annulus" RP Issues and Potential Hazards y No wells will require shut-in for the rig move off of 03-33Bi. However, 03-32 is 120.0' to the North, and 03-34 is 120.0' to the South. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. y During ND/NU tree operations, the 03-33Bi well bore will be secured with the following barriers: o Tubing: TWC and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. y During RD/MO operations, the 03-33Bi well bore will be secured with the following barriers: o Tubing: Non-perforated well and kill weight fluid above ball/rod. o IA: Annulus valves and kill weight fluid. o OA: Annulus valve and kill weight fluid. 03-33Bi Sidetrack Page 11 Pian: 3¡ù H) Creßt,w By: Digit¡¡! Business Client ther D¡¡te-: 1/28/200 50.!)!:) Checked: Date: --_._.,~,.,'~.._'^ Reviewed; -,~--_..~.- Date - - WELL DETAIL':> N;ml\.'" Lüngítwk -2991 .......... .. .- TARGET DETAILS Name TVD +N/-S +E/-W Northing Easting Shape S9li 9.52 Point 6.41 16.41 - .......... ......... rAILS See MD Iue TVD +N/-S DLcg TFacc VSec Target I 2147.05 2 3 4 5 03-33B Tlb 6 7 T2c S 9 03-33B Tlb INfORMATJÜN Rt; FORMATION TOP DETAILS No. TVDPath MDPath Formation 2 3 4 5 6 7 S 9 10 II 12 13 14 CASING DETAILS No. TVD MD Name Size 1 7" 2 41/2" - ~ '" '" ~ P AlIwcn B) Cre-.Jted By: Digital Busíne:'i$ Client User Date: Litirude LongihHil "]S.J36\~ TC VDPa Formation rSI - - - CASING DETAILS MD Name Size 7' 4 AILS I WELL Depth Fm Noith - . VSec TargcI 03-33B Tlb 03-33B Tlc SECTION DETAILS TVD +N!-S +E!- W Azi [ue MD 9650.00 See I 2 3 4 5 6 7 8 9 50, S! ~ . Sperry-Sun BP Planning Report . Principal: Yes Plan: 03-33B wp05 Date Composed: Version: Tied-to: 1114/2004 27 From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB DS 03 TR-10-15 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Well: 03-33 03-33 Well Position: Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2004 5939219.13 ft 712287.91 ft Latitude: 70 14 LongUude: 148 17 North Reference: Grid Convergence: 13.210 N 8.774 W True 1.61 deg Slot Name: +N/-S -2991.71 +E/-W 1743.02 Position Uncertainty: 0.00 Casing Points 10553.10 13089.00 Formations Diameter in ft Northing: 5936277.82 ft Latitude: 70 13 43.784 N ft Easting : 714114.38 ft Longitude: 148 16 18.136 W ft Name 8.500 7" 6.125 41/2" Lithology 7.000 4.500 9779.05 10239.41 10553.10 10593.84 10621.00 10626.43 10656.31 10711.00 10716.70 10726.86 10743.37 10743.37 10818.96 10818.96 TV» ft 0.00 0.00 8140.40 8479.40 8710.40 8740.40 8760.40 8764.40 8786.40 8826.40 8830.40 8837.40 8848.40 8848.40 8892.40 8892.40 0.00 0.00 0.00 0.00 CM3 CM2 CM1 THRZ TSHA-TSAD 45SB 43N 43P 42N 42P 41N 41P 31N 31P 27N 27P 26N 26P 25N MHO/HOT J)ipAngJe då9 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Dip DireetÎoí1 d~ 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Map NorthiDg ft. 03-33B T1b 8916.40 4190.44 5940614.99 70 14 24.979 N 148 13 45.921 W 03-33B T2c 8916.40 3496.10 5043.54 5939915.49 719056.41 70 14 18.152 N 148 1351.542W 03-33B Poly 8916.40 1728.56 3255.16 5938097.99 717319.01 70 14 0.778 N 148 14 43.544 W -Polygon 1 8916.40 1728.56 3255.16 5938097.99 717319.01 70 14 0.778 N 148 14 43.544 W -Polygon 2 8916.40 2118.70 4983.01 5938536.99 719035.01 70 14 4.606 N 148 13 53.327 W -Polygon 3 8916.40 4405.08 5675.21 5940841.99 719662.01 70 14 27.087 N 148 13 33.161 W -Polygon 4 8916.40 4662.21 5005.21 5941079.99 718985.01 70 14 29.621 N 148 13 52.633 W -Polygon 5 8916.40 2709.76 4461.55 5939112.99 718497.01 70 14 10.422 N 148 14 8.471 W -Polvoon 6 8916.40 2286.12 3032.88 5938648.99 717081.01 70 14 6.262 N 148 14 49.997 W . Sperry-Sun BP Planning Report . Plan Section Infonnation 9650.00 41.07 78.89 8045.05 2147.05 3558.25 0.00 0.00 0.00 0.00 9670.00 42.10 82.16 8060.01 2149.23 3571.35 12.00 5.12 16.36 66.00 9699.09 42.58 83.74 8081.52 2151.63 3590.79 4.00 1.65 5.41 66.28 10692.28 42.58 83.74 8812.89 2224.95 4258.73 0.00 0.00 0.00 0.00 11044.91 90.00 68.00 8951.40 2309.30 4559.63 14.00 13.45 -4.46 -20.94 03-33B T2b 11424.82 91.75 14.83 8945.16 2584.02 4802.02 14.00 0.46 -13.99 -87.82 12368.77 91.75 14.83 8916.40 3496.10 5043.54 0.00 0.00 0.00 0.00 03-33B T2c 12417.39 89.94 15.55 8915.69 3543.00 5056.27 4.00 -3.72 1.48 158.30 13089.42 89.94 15.55 8916.40 4190.44 5236.43 0.00 0.00 0.00 0.00 03-33B T1b 9650.00 41.07 78.89 8045.05 7988.65 2147.05 3558.25 0.00 5938524.89 717610.09 Start Dir 12/10 9670.00 42.10 82.16 8060.01 8003.61 2149.23 3571.35 12.00 5938527.44 717623.11 Start Dir 4/100 9699.09 42.58 83.74 8081.52 8025.12 2151.63 3590.79 4.00 5938530.40 717642.48 End Dir : 9699 9700.00 42.58 83.74 8082.19 8025.79 2151.70 3591 .40 0.00 5938530.48 717643.09 MWD+IFR+MS 9779.05 42.58 83.74 8140.40 8084.00 2157.53 3644.56 0.00 5938537.82 717696.06 CM1 9800.00 42.58 83.74 8155.83 8099.43 2159.08 3658.65 0.00 5938539.77 717710.10 MWD+IFR+MS 9900.00 42.58 83.74 8229.46 8173.06 2166.46 3725.90 0.00 5938549.06 717777.11 MWD+IFR+MS 10000.00 42.58 83.74 8303.10 8246.70 2173.84 3793.16 0.00 5938558.34 717844.13 MWD+IFR+MS 10100.00 42.58 83.74 8376.74 8320.34 2181.23 3860.41 0.00 5938567.63 717911.14 MWD+IFR+MS 10200.00 42.58 83.74 8450.38 8393.98 2188.61 3927.66 0.00 5938576.92 717978.15 MWD+IFR+MS 10239.41 42.58 83.74 8479.40 8423.00 2191.52 3954.16 0.00 5938580.58 718004.56 THRZ 10300.00 42.58 83.74 8524.02 8467.62 2195.99 3994.91 0.00 5938586.21 718045.16 MWD+IFR+MS 10400.00 42.58 83.74 8597.66 8541.26 2203.37 4062.17 0.00 5938595.49 718112.18 MWD+IFR+MS 10500.00 42.58 83.74 8671.30 8614.90 2210.76 4129.42 0.00 5938604.78 718179.19 MWD+IFR+MS 10553.10 42.58 83.74 8710.40 8654.00 2214.68 4165.13 0.00 5938609.71 718214.78 7" 10593.84 42.58 83.74 8740.40 8684.00 2217.68 4192.53 0.00 5938613.50 718242.08 45SB 10600.00 42.58 83.74 8744.93 8688.53 2218.14 4196.67 0.00 5938614.07 718246.20 MWD+IFR+MS 10621.00 42.58 83.74 8760.40 8704.00 2219.69 4210.80 0.00 5938616.02 718260.28 43N 10626.43 42.58 83.74 8764.40 8708.00 2220.09 4214.45 0.00 5938616.53 718263.92 43P 10656.31 42.58 83.74 8786.40 8730.00 2222.29 4234.54 0.00 5938619.30 718283.94 42N 10692.28 42.58 83.74 8812.89 8756.49 2224.95 4258.73 0.00 5938622.64 718308.04 Start Dir 14/10 10700.00 43.59 83.18 8818.53 8762.13 2225.55 4263.97 14.00 5938623.39 718313.26 MWD+IFR+MS 10711.00 45.03 82.41 8826.40 8770.00 2226.52 4271.59 14.00 5938624.57 718320.85 42P 10716.70 45.78 82.03 8830.40 8774.00 2227.06 4275.61 14.00 5938625.23 718324.86 41N 10726.86 47.12 81.38 8837.40 8781.00 2228.13 4282.90 14.00 5938626.50 718332.11 41P 10743.37 49.31 80.37 8848.40 8792.00 2230.08 4295.05 14.00 5938628.80 718344.20 31P 10800.00 56.86 77.36 8882.39 8825.99 2238.87 4339.43 14.00 5938638.85 718388.31 MWD+IFR+MS 10818.96 59.41 76.47 8892.40 8836.00 2242.52 4355.11 14.00 5938642.94 718403.88 27P 10871.79 66.53 74.21 8916.40 8860.00 2254.45 4400.60 14.00 5938656.15 718449.01 03-33B Poly 10900.00 70.34 73.11 8926.7T 8870.37 2261.83 4425.77 14.00 5938664.25 718473.95 MWD+IFR+MS 11000.00 83.90 69.53 8949.01 8892.61 2293.06 4517.85 14.00 5938698.08 718565.11 MWD+IFR+MS 11044.91 90.00 68.00 8951.40 8895.00 2309.30 4559.63 14.00 5938715.49 718606.41 03-33B T2b 11100.00 90.29 60.29 8951.26 8894.86 2333.30 4609.17 14.00 5938740.89 718655.25 MWD+IFR+MS 11200.00 90.81 46.30 8950.30 8893.90 2392.92 4689.14 14.00 5938802.75 718733.49 MWD+IFR+MS 11300.00 91.27 32.31 8948.47 8892.07 2470.09 4752.32 14.00 5938881.68 718794.45 MWD+IFR+MS 11400.00 91.66 18.31 8945.90 8889.50 2560.24 4794.95 14.00 5938973.00 718834.50 MWD+IFR+MS 11424.82 91.75 14.83 8945.16 8888.76 2584.02 4802.02 14.00 5938996.97 718840.90 End Dir : 1142 11500.00 91.75 14.83 8942.87 8886.47 2656.66 4821.26 0.00 5939070.12 718858.06 MWD+IFR+MS 11600.00 91.75 14.83 8939.82 8883.42 2753.28 4846.84 0.00 5939167.43 718880.89 MWD+IFR+MS 11700.00 91.75 14.83 8936.77 8880.37 2849.90 4872.43 0.00 5939264.73 718903.72 MWD+IFR+MS 11800.00 91.75 14.83 8933.73 8877.33 2946.53 4898.01 0.00 5939362.04 718926.55 MWD+IFR+MS 11900.00 91.75 14.83 8930.68 8874.28 3043.15 4923.60 0.00 5939459.34 718949.39 MWD+IFR+MS 12000.00 91.75 14.83 8927.63 8871.23 3139.78 4949.18 0.00 5939556.65 718972.22 MWD+IFR+MS 12100.00 91.75 14.83 8924.59 8868.19 3236.40 4974.77 0.00 5939653.96 718995.05 MWD+IFR+MS 12200.00 91.75 14.83 8921.54 8865.14 3333.02 5000.35 0.00 5939751.26 719017.88 MWD+IFR+MS - - - - - - - -- -. - - - - -- - ----- --- --- . Sperry-Sun BP Planning Report . 12500.00 89.94 15.55 8915.77 8859.37 3622.59 5078.42 0.00 5940042.92 719087.69 MWD+IFR+MS 12600.00 89.94 15.55 8915.88 8859.48 3718.93 5105.23 0.00 5940139.98 719111.75 MWD+IFR+MS 12700.00 89.94 15.55 8915.99 8859.59 3815.27 5132.04 0.00 5940237.03 719135.81 MWD+IFR+MS 12800.00 89.94 15.55 8916.09 8859.69 3911.61 5158.84 0.00 5940334.09 719159.88 MWD+IFR+MS 12900.00 89.94 15.55 8916.20 8859.80 4007.95 5185.65 0.00 5940431.15 719183.94 MWD+IFR+MS 13000.00 89.94 15.55 8916.30 8859.90 4104.29 5212.46 0.00 5940528.20 719208.00 MWD+IFR+MS 13089.00 89.94 15.55 8916.40 8860.00 4190.03 5236.32 0.00 5940614.58 719229.42 41/2" 13089.42 89.94 15.55 8916.40 8860.00 4190.44 5236.43 0.00 5940614.99 719229.52 03-338 T1b TREE: McEVOY GEN3 WELLHEAD: McEVOY ACTUATOR: 3000' 969' 10536' 8800'8S o Y NOTES: FISH IN HOLE - HORIZONTAL WELL - 70° @ 10709' AND 90° @ 10800' Pre III 19 GAS LIFT I'v1ANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 133/8",72#, L-80, 1 3002 3000 40 MMIG RK Casing 2 4342 4221 43 MMIG RK 3 6085 5502 43 MMIG RK 4 7425 6444 42 MMIG RK Minimum 10 ::::: 2.00" @ 13100' 5 7537 6522 42 MMIG RK XO Fl4S PIN X STl BOX 6 8794 7426 40 MMIG RK 7 8906 7508 40 MMIG RK 8 9917 8267 23 MMIG RK 9 10028 8369 20 MMIG RKP PERFORA TION SUMI'v1ARY REF LOG: BHCS ON 8/9/1984 ANGLEATTOPÆRF: 25@ 10520' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2" 4 10520 - 10540 0 03/29/04 2" 4 10550 - 10570 0 03/29/04 2" 4 11220 -11290 0 02/05/00 2" 4 11770 -11840 C 02/18/99 2-1/8" 4 12375 -12440 C 03/26/98 2-1/8" 4 12970 - 13020 C 05/04/97 2-1/8" 4 13075-13114 C 05/04/97 15 1/2" X 4 1/2" XO 10123' H 4-1/2" G SETTING SLV I I Top of 2 7/8" Liner H 3-1/2" X 2-7/8" XO I 10138' H I 10206' 4-1/2" OTIS XN NIP (BEHIND LNR), 10: 3.72" I Top of T' Liner 10165' H I 10218' 4-1/2" BOT SHEA ROUT SUB (BEHIND LNR) 4 1/2", 12.6#, L-80, H 4-112" TBG TAIL (BEHIND LNR) I PC- Tbg 10219' 10264' 95/8",47#, L-80, Î 10314' Casing Sidetrack Window Î 10402' 7",29#, L-80, liner, -i 10936' I 10 : 6.184" I DATE 03/86 04/30/97 12/13/00 03/27/01 02103/02 03/29/04 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK NVERTED TO CANVAS CONVERTED TO CANVAS CORRECTIONS ADÆRFS SIS- TP RNITP H CIBP 13115' I DATE 1/13/05 REV BY dew COMMENTS Proposed pre rig work PRUDHOE SA Y UNIT WELL: 03-33A ÆRMIT No: 197-0390 API No: 50-029-21142-01 SEC 11, T10N, R15E, 2658' FEL & 1515.13' FNL Sf> Exploration (Alaska) 03-33 .. I 13 ~/8", 72#, L-80, -I 2506' Casing I 7",26.0#, L-80, Scab Liner Sidetrack Window tion TREE = McEVOY GEN3 D = McEVOY ACTUA TOR::: AXELSON KB. ELEV ::: 56.40' GL ELEV ::: 27.89' KOP ::: 3000' 100 @ 10969' 10536' 8800' SS posed Com -2200 1-1 4 1/2" 'X' landing nipple 3,000 9 5/8" X 7" Baker Flex-Lock liner hanger, ZXP liner top packer w / TBS 9,500 9 5/8" X 7" Baker HMC liner hanger, ZXP liner top packer wI TBS 10,330 H 41/2" 'X'landing nipple I 10,350 H 7"X41/2'''BakerS-3Pkr I 10,370 H 41/2" 'X' landing nipple I 10,390 1-1 41/2" 'XN'landing nipple 7" X 5" Baker HMC liner hanger, ZXP liner top packer w / TBS 95/8" X 51/2" BOT I 10,553 H 7",26.0#, L-80 BTC-M liner 3-H Packer Top of T' Liner H I Tag cement (4/18/97) H 10264' 95/8",47#, L-80, 1 10374' Casing Sidetrack Window Î 10402' I 7",29#, L-80, liner, Î 10936'1 10 ::: 6.184" _ _ DATE 03/86 04/30/97 12/13/00 03/27/01 02/03/02 03/29/04 REV BY COMMENTS ORIGINAL COMPLETION SIDETRACK CONVERTED TO CANVAS CONVERTED TO CANV AS CORRECTIONS ADÆRFS SIS-JLH TP RNITP MJA/KK I 13,089 H 4 1/2", 12.6#, L-80 IBT-M liner I I 2-7/8" LNR, 6.5#, L-80, 0.0058 bpf, 10::: 2.441" H DATE 01/28/05 REV8Y dew COMMENTS oposed Completion (Wp05) PRUDHOE 8A Y UNIT WELL: 03c338i PERMIT No: API No: 50-029-21142-02 SEe 11, nON, R15E, 2658' FEL & 1515.13' FNL SP Exploration (Alaska) · POST THIS NOTICE IN THE DOGHISE 03-33Bi Rig site Summary of Drilling Hazards / ../ Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 470 ppm, measured in November 2001. ./ ../ NORM test all retrieved well head and completion equipment. ../ The closest neighboring wells, at surface, are 03-32 and 3-34. Well 03-32 is approximately 120' to the North. Well 03-34 is approximately 120' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. ../ The Kingak, Sag River, and Shublik are truncated in this area of the field. Be patient and take necessary measures to determine the intermediate casing point at the LCU/lvishak interface. ../ There are no planned fault crossings in drilling either the intermediate or the production interval. ../ Differential sticking may be encountered. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. ../ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. CONSULT THE DS 03 PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. 03-33Bi Winton; Because the Sag River Fm. is part of the Prudhoe Pool and this well may (?) at some point be completed in the Sag River Fm.1 suggest the Sag river wells be included in the AOR. I've changed the spreadsheet accordingly let me know if you object BC -------- Original Message -------- Subject: 03-33Bi, 17-13Ai 1/4 mile proximity wells within injection zone. Date: Wed, 09 Feb 2005 12:42:20 -0900 From: Wesley, Dave E <WesleyDE(â¿BP.com> To: bob crandall(â¿admin.state.ak.us Mr. Crandall, I have included the proximity scans, along with the depths of the zones of interest, for each of the wells. The proximity reports give the tabular listing of the depths and point-to-point closest approach of the surrounding wells. I have summarized the data below: _03-33BL (Ivishak injector) / TSAD -10,555' md /-8,710' tvd as drilled in Wp05 1"1104-( '" Only well 09-20 is within 1/4 mile of the planned well within the Ivishak (injection interval). Its closest approach is 877' at 12,955' md of the drilling well (Wp05). _17-13Ai_ (Sag River irJjector) TSGR -10,910' md /-8,740' tvd; (BSGR -8,765' tvd) as drilled in Wp06 11~ Q14/ Well 12-06 is at 1,205' seperation, within the Sag River, at 12,440' md of the drilling well. This is below the 12-06A sidetrack point in the abandoned portion of the 12-06 well. IH OS1---8' Well 12-06A i~ at 768' seperation, within the Sag River, at 12,570' md of the drilling well. !~ Ib(, ./ Well 12-25 is at 340' seperation, within the Sag River, at 13,600' md of the drilling well. «03-33B wp05 Anti-Collision.ZIP» «17-13A wp06 AC report. pdt» Please call with any questions. Thanks and regards, Dave Wesley, Jr. Operations Drilling Engineer GPB Rotary Drilling 564-5153 office 440-8631 cell 564-4040 fax · e 177 89-6/1252 DATE Mastercard· Check G e~ 'l.., TERR'E lHUBBLE BPEXPlORATION AK.'NC POSQX196612M87_S . .. ANCHQRAGE,AK .99519-6612 '" ':¡~5~ 0 00 GO.: q .q¡... . . TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/P ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME r:1~4 3-3~g PTD# 20S - ð/<?' Development Service Exploration Stratigraphic CHECK WßA T ADD-ONS ~'CLUE"· APPLIÈS (OPTIONS) MULTI The permit is for a new weUboresegment of LATERAL existing well . Permit No, API No. . (If API Dum ber ProductioD. should conti Due to be reponed as last two. (2) digits a function ·of tbe original API number. stated are between 60-69) above. PILOT HOLE )n accordance with . 20 AAC 25.005(1), all (PH) records, data and logs acquired .for tbe pilot bole must be clearly differentiated In botb name (name on permit plus PH) .. and API Dum ber (50 - 70/80) from records, data and )ogs acquired for well (name on permit). SPACING Tbe permit is approved subject ·to fuD EXCEPTJON compliance witb 20 AAC 2S..0SS~ Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spa cing ex ception. (Companv Name) assumes tbe liability of any prot est to tbe spacing .elception tbat may occur. : DRY DITCH AU dry ditcb sample sets submitted to tbe SAMPLE Commission must be in no greater ·tban 30' .. sample intervals from below tbe permafrost or from where samples are first caught and ] 0' sample iJiter:vals tbrougb target zones. .. . - D D Well bore seg Annular Disposal - Field & Pool PRUDHOE BAY. PRUDHOE OIL - 640150 Well Name: AY UNIT 03-33B Program SER. PLORATION (ALASKA) INC Initial ClasslType SER / WAGIN GeoArea 890 Unit 11650 On/Off Shore On iiii Administration Pß(lTlit fee attache.d. - - - - - - - - - - - - - - - " . . . YßS 2 .Leasß .number .apprOPJiíite. - - - - -- - - - - - - YßS - - - - - - - - - - - - - - - - 3 .Unique weltn.arnß.aod rwmb.er . . . . . . . . . . . . . . . . . . . . . . ........ Yßs - - - - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - - - - 4 Well JQcíitßd in.a. d.efioe.dpool. . . - - -- - - - - - - Yßs - - - - - - 5 WelUQcatßd proper distance. from driJling uoitb.ouod~¡:y. . Yßs - - - - - - 6 Well Jocíitßd pr.oper .distance. from otber WßlJs. - - - - · Yes - - - - - - - - - - - - - - - - - - - 7 .Sutficieot .acrßag.e.aYail<lble in dJilJiog unjt. . . YßS - - - - - - - - - - - - - - - 8 Jtdßviated. js. weJlbQre platiocJu.ded . - - - - - - - - - - YßS 9 .Operator OOly affected party . - - - - - - - - - - - - - ...... YßS 10 .Oper.ator bas.appropriate-'~ond inJorce . . . . . . . . . . . . . . . . . ........ YßS - - - - - - - - - - - - - - - - - - . . - - - - - - - - - - - - - - -- 11 Permit can be issu.ed withQut conservatioo order Yes - - - - - - - - - - - Appr Date 12 Pß(lTlit C<!n be issued witbout admioistrativ:e.approvaJ . · YßS - - - - - - - - - - - - RPC 2/9/2005 13 Can permit be approved before 15-day wait Yes 14 WelUQcatßd withio area and.stratíi .authorized byJojectioo Ordßr # (puUO# lncor:nrn.eots). (For YßS .. . . .810AC - - - - 15 AJIWßlJs.withln.1l4.mile.area.ofreyißwidßotified(Forservj(;ßwellooly)............... YßS .1?6U 09-2Q Uvjstlak) J~6.U. t2,Q6, 12.-Q6Aa.nd .:12-25 (S.ag River) 16 Pre-produced iojector; .duratio.nof pre·pro.duGlioo Ißss than. 3 mooths. (Forservlce well QnJy) .NA - - - - - - - - - - - 17 AÇMP fiodjngof Conslsteocy h.as been .issued. for. this pr.oject NA Engineering 18 Cooductor stÖllgprQvided . - - - - - - NA 19 .S.urfacßcasiogpJoteQts alLknowll USDWs . . - - - - - - NA 20 .CMT vol adequate to circulate.oncood.uctor. & SUJtC$g . NA - - - - - - 21 .CMT. v.ol adequate to tie-inJQngstring to surf cs.g. . · NA - - - - - - - - - - -- 22 CMT. will coyerafl koow.n .productiye hori~on.s . . . .... Yßs 23 .C.asiog designs adequate for CoT. B& permafrost . Yßs 24 A.dequ<lle .tankage. OJ re.serve pit . YßS f\labors.2.ES, . 25 Jtare-.drilt hasa to-403 fOJ íibandonment beßO approved. .. Yes 1/27'/20.05. 26 A.dequatewe!lbore separíitio.npropo!¡ed. . . . . . . . . . . . . . . . . . . .... Yßs - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - -- 27 Jtdiv~rter req.uired, dQes it meet reguJatioos. . . - - - - - - .NA · . . . . Sidetraçk. . - - - - -- Appr Date 28 .DJiUiog fJujdprogram SQhematic& eq.uipJistadequíite. . .. Yßs · . . . . MaxMWH>A.ppg. - - - - - - WGA 2/9/2005 29 BOPEs.dothey meet reguJatioo . . Yßs - - - - - - - - - - 30 .BOPEpress ra.liog appropriate; .testlo.(put psig incommeots) . . . . . YßS · . . . . TestloAOQOpsi. .MSF' 23.80 psi.. . . 31 C.ho~eroanifQld complies w/APt RP-53 (May 84). . - - - - .. Yes - - - - - - - - - - - - - - - - - 32 Wor~ will occ).J( wilhoutoperatjon .shutdow.n. - - - - - - .. YßS - - - - - - - - - - - - - - - - 33 .Is presence. Qf H2S gas. prQb.able. . . . Yes . . 47.0.ppr:nH2S.onpad.. . - - -- 34 MeçbanicaLcoodjtioo otweJls withio J\OR yerifìed (Fors.ervice WßIJ only) '. Yß$ . . Cmtng recor.ds indicate rn~ch iot of all J\QR welts.. Geology 35 Pßrrnit c.ao be issued w[o bydr.ogen s.ulfide measJ,Jres. . . . . . . No. 36 .D.ata.preseoted on pote.ntial oveJpressuœzooes. . NA Appr Date 37 .Sßismicanalysjs. Qf sbaJlow gas.zooes . . . . . . . . . · .NA - - - - - - RPC 2/8/2005 38 Sßabed .cooditioo survey.(if Off-!¡ho(e) . . . . .... .NA - - - - - 39 . Conta.ct oamelphOlleJorweelsly progress.reports [explorato¡:yooIYl .NA - - - - - - Geologic Date: Engineering Date Date Commissioner: Commissioner: Orr ¿/ fO Is ~YÓr . . 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 Drilling Services LIS Scan Utility . .t} -- -- (JL \? 0DJ # ) )7? $Revision: 3 $ LisLib $Revision: 4 $ Thu Aug 18 15:30:55 2005 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 05/08/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number.... ..01 Previous Reel Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/08/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA 3-33B 500292114202 BP Exploration (Alaska) Inc. Sperry Drilling Services 18-AUG-05 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 2 MW0003591175 N. WHITE D. MASKELL MWD RUN 3 MW0003591175 N. WHITE D. MASKELL MWD RUN 4 MW0003591175 N. WHITE D. MASKELL # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 11 10N 15E 215 821 56.39 27.89 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE BIT SIZE (IN) 8.510 6.125 CASING SIZE (IN) 9.625 7.000 DRILLERS DEPTH (FT) 9596.0 10572.0 # . . REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. THIS WELL WAS DRILLED OFF OF A WHIPSTOCK IN THE 3-33 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 9595'MD/8004'TVD. 4. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL¡ DUAL GAMMA RAY (DGR) UTILIZING GEIGER- MUELLER TUBE DETECTORS¡ AND PRESSURE WHILE DRILLING (PWD). UPHOLE MAD SGRC TIE-IN DATA ACQUIRED WHILE RIH FOR RUN 2 WERE MERGED WITH RUN 2 MWD SGRC DATA. 5. MWD RUNS 3 & 4 COMPRISED DIRECTIONAL¡ DGR¡ ELECTROMAGNETIC WAVE RESISTIVITY- PHASE 4 (EWR4) ¡ AND AT-BIT INCLINATION (ABI). 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A GAMMA RAY RUN IN 3-33B, PROVIDED BY D.DORTCH (SAIC/BP) ON 16 AUGUST 2005. LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1 - 4 REPRESENT WELL 3-33B WITH API#: 50-029-21142-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13072'MD/8917'TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME. SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/18 Maximum Physical Record. .65535 File Type................LO Previous File Name..... ..STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR ROP FET 1 and clipped curves¡ all bit runs merged. .5000 START DEPTH 8689.0 9615.0 10523.0 STOP DEPTH 13012.5 13066.0 13019.5 RPD RPM RPS RPX $ . 10523.0 10523.0 10523.0 10523.0 13019.5 13019.5 13019.5 13019.5 . # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH ------. BASELINE DEPTH 8689.0 9594.0 9607.0 9624.5 9669.5 9673.5 9681.5 9723.0 9732.0 9765.5 9774.5 9783.5 9787.5 9792.0 9809.0 9817.5 9839.5 9850.5 9854.5 9863.0 9870.0 9879.5 9896.5 9909.0 9920.0 9926.5 9937.5 9967.5 9973.5 10001.5 10016.0 10027.5 10046.5 10056.0 10071.5 10083.0 10086.0 10093.5 10107.0 10109.5 10119.5 10127.0 10131.0 10134.5 10148.0 10155.0 10157.5 10159.5 10173.5 10178.0 10180.0 10188.0 10190.5 10192.5 10195.0 10200.0 10209.5 10223.0 GR 8698.5 9603.5 9615.0 9632.0 9678 . 0 9682.5 9690.5 9731.0 9741.0 9772.5 9782.5 9792.0 9796.5 9801.0 9817.5 9826.0 9849.0 9859.0 9862.5 9871.0 9877.5 9888.0 9905.5 9916.5 9929.5 9935.5 9947.0 9977.0 9982.5 10011.5 10024.5 10036.5 10055.5 10063.5 10079.5 10092.5 10094.5 10101.0 10115.5 10118.0 10128.0 10135.5 10140.0 10143.5 10157.0 10163.5 10165.5 10167.0 10180.5 10185.5 10188.0 10195.5 10198.0 10200.0 10202.5 10208.0 10217.5 10229.5 10238.0 10243.5 10251.5 10259.5 10277.0 10282.0 10296.5 10299.0 10301.5 10304.5 10308.0 10314.0 10317.5 10326.0 10330.0 10342.0 10356.5 10363.0 10371.5 10373.5 10376.5 10382.0 10384.0 10387.0 10395.0 10412.5 10417.5 10423.0 10425.5 10436.0 10442.5 10445.5 10450.5 10457.0 10463.0 10468.5 10471.0 10486.0 10488.0 10491. 5 10505.5 10507.0 10511.0 10522.5 13066.0 $ . 10244.5 10250.5 10258.5 10267.0 10284.5 10288.5 10303.5 10306.0 10308.5 10311.5 10315.0 10321.0 10325.0 10333.5 10337.0 10349.0 10363.5 10369.5 10379.0 10381.0 10383.0 10389.5 10391.0 10394.0 10402.0 10419.5 10425.0 10429.5 10432.5 10443.0 10450.0 10453.0 10458.0 10464.5 10470.0 10475.5 10479.5 10494.5 10496.5 10499.5 10512.5 10514.0 10518.5 10528.5 13072.0 . # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 2 3 4 MERGE TOP 8698.5 10572.0 11783.0 MERGE BASE 10572.0 11783.0 13072.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O . . Name Service Order 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 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8689 13066 10877.5 8755 8689 13066 ROP MWD FT/H 1.18 340.94 102.599 6903 9615 13066 GR MWD API 12.33 417.35 73.8605 7290 8689 13012.5 RPX MWD OHMM 1. 62 702.78 4.17288 4994 10523 13019.5 RPS MWD OHMM 1. 72 1577.3 5.96163 4994 10523 13019.5 RPM MWD OHMM 1. 39 2000 19.414 4994 10523 13019.5 RPD MWD OHMM 1. 68 2000 30.8566 4994 10523 13019.5 FET MWD HOUR 0.25 70.04 2.36457 4994 10523 13019.5 First Reading For Entire File......... .8689 Last Reading For Entire File.......... .13066 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/18 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..... ..05/08/18 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR ROP $ 2 header data for each bit run in separate files. 2 .5000 START DEPTH 8698.5 9623.0 STOP DEPTH 10540.5 10572.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE 14-MAR-05 . 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 VENDOR TOOL CODE DGR $ BOTTOM) TOOL TYPE DUAL GAMMA RAY # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD020 GR MWD020 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code Insite 66.18 Memory 10572.0 9622.0 10572.0 . 40.7 44.5 TOOL NUMBER 103770 8.510 9596.0 LSND 10.50 48.0 9.1 2900 3.6 .000 .000 .000 .000 .0 145.4 .0 .0 Offset o 4 8 Channel 1 2 3 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8698.5 10572 9635.25 3748 8698.5 10572 ROP MWD020 FT/H 8.22 197.29 107.781 1899 9623 10572 GR MWD020 API 44.9 417.35 167.993 2327 8698.5 10540.5 . First Reading For Entire File......... .8698.5 Last Reading For Entire File.......... .10572 File Trailer Service name. ........... .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/18 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..... ..05/08/18 Maximum Physical Record..65535 File Type.......... .. . . . . LO Previous File Name..... ..STSLIB,002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE FET RPD RPM RPX RPS GR ROP $ 3 . header data for each bit run in separate files. 3 .5000 START DEPTH 10529.0 10529.0 10529.0 10529.0 10529.0 10541.0 10572.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 11739.5 11739.5 11739.5 11739.5 11739.5 11732.5 11783.0 TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 # BOREHOLE AND CASING DATA 18-MAR-05 Insite 66.37 Memory 11 783.0 10572.0 11783.0 42.7 91. 9 TOOL NUMBER 62456 130910 . OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction............... ..Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 6.125 10572.0 . Flopro 8.40 54.0 9.8 3500 6.0 .810 .410 1.520 .870 74.0 153.5 74.0 74.0 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 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10529 11 783 11156 2509 10529 11783 ROP MWD030 FT/H 1.18 232.48 57.5447 2422 10572.5 11783 GR MWD030 API 15.49 173.85 34.2036 2384 10541 11732.5 RPX MWD030 OHMM 1. 62 702.78 4.81768 2422 10529 11739.5 RPS MWD030 OHMM 1. 72 1577.3 8.59634 2422 10529 11739.5 RPM MWD030 OHMM 1. 39 2000 36.3151 2422 10529 11739.5 RPD MWD030 OHMM 1. 68 2000 60.0452 2422 10529 11739.5 FET MWD030 HOUR 0.46 70.04 3.59858 2422 10529 11739.5 First Reading For Entire File......... .10529 Last Reading For Entire File.......... .11783 File Trailer . Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/18 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...... .05/08/18 Maximum Physical Record. .65535 File Type... . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 4 . header data for each bit run in separate files. 4 .5000 START DEPTH 11733.0 11740.0 11740.0 11740.0 11740.0 11740.0 11783.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ STOP DEPTH 13018.5 13025.5 13025.5 13025.5 13025.5 13025.5 13072.0 20-MAR-05 Insite 66.37 Memory 13072.0 11783.0 13072.0 89.8 93.1 BOTTOM) TOOL TYPE DUAL GAMMA RAY Electromag Resis. 4 TOOL NUMBER 62456 130910 # 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): 6.125 10572 .0 FloPro 8.40 45.0 . 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: 9.8 4000 7.5 . .900 .500 1.950 .930 72.0 136.4 72.0 72.0 # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value... . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 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 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11733 13072 12402.5 2679 11733 13072 ROP MWD040 FT/H 5.25 340.94 141.154 2578 11783.5 13072 GR MWD040 API 12.33 70.47 25.1943 2572 11733 13018.5 RPX MWD040 OHMM 1. 83 9.43 3.56567 2572 11740 13025.5 RPS MWD040 OHMM 1.8 10.11 3.48058 2572 11740 13025.5 RPM MWD040 OHMM 1. 81 11.42 3.49861 2572 11740 13025.5 RPD MWD040 OHMM 1. 83 7.97 3.37032 2572 11740 13025.5 FET MWD040 HOUR 0.25 20.36 1.20253 2572 11 740 13025.5 First Reading For Entire File......... .11733 Last Reading For Entire File.......... .13072 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .05/08/18 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.005 . . Physical EOF Tape Trailer Service name............ .LISTPE Date.................... .05/08/18 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .05/08/18 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name..... . . . . . .UNKNOWN Comments...,........... ..STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
