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Home My WebLink About204-069 XHVZE e e Image Project Well History File Cover Page 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 g.. 0 f¡ q Well History File Identifier D Two-sided III" 111111111 II III Organizing (done) D Rescan Needed 11/" 1I1111 II 11I111 R~CAN ¥Jolor Items: ¢ Greyscale Items: l p~ o Poor Quality Originals: DI~TAL DATA \Ø'" Diskettes, No. \ D Other, NolType: OVERSIZED (Scannable) D Maps: D Other Items Scannable by a Large Scanner D Other: OVERSIZED (Non-Scannable) D Logs of various kinds: NOTES: D Other:: BY: ~ Date (g I~ BY: '111111111111111111 wW 151 re r + /5 = TOTAL PAGES 4-5 (Count does not include cover sheet) 151 Project Proofing BY: ~ Scanning Preparation Date: b Production Scanning 1111111111111111111 r BY: Page Count from Scanned File: Lj- ro (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES ~ Date:~/:Ýo/Ob Stage 1 If NO in stage 1, page(s) discrepancies were found: Stage 1 NO YES 151 W\ P NO BY: Maria Date: 151 III "111111I111111I Scanning is complete at this point unless rescanning is required. ReScanned III 111111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked III "1111111 "1111I 10/6/2005 Well History File Cover Page.doc . • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSIPN WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended lb. Well Class: 2OAAC 25. 105 2OAAC 25.110 ■ Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: d 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 1/5/2011 204 - 069 310 - 374 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 5/17/2004 50 029 21649 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 5/20/2004 PBU F -28A 2359' NSL, 2193' WEL, SEC. 02, T11 N, R13E, UM 8. KB (ft above MSL): 66.70' 15. Field / Pool(s): Top of Productive Horizon: 2896' NSL, 1293' WEL, SEC. 02, T11 N, R13E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 3671' NSL, 554' WEL, SEC. 02, T11 N, R13E, UM 9660' 9058' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 652650 y 5973893 Zone ASP4 10819' 9049' ADL 028280 TPI: x - 653538 y 5974448 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 654260 y - 5975239 Zone ASP4 N/A 18. Directional Survey: 0 Yes MI No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: SGRC Combined GR & EWR, MGR / CCL / CNL 9075' 8898' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVO HOLE ' AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Conductor Surface 110' Surface 110' 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 2675' Surface 2675' 17 -1/2" 3274 cu ft AS III. 465 cu ft AS II 9-5/8" 47# L -80 Surface 8593' Surface 8457' 12-1/4" ,575 cu ft Class 'G' 7' " 26# L -80 8321' 9075' 8209' 8898' _ 8-1/2" 374 cu ft Class 'G' 3 -1j2 x,3/16' x 2 9 i 6.2# i 6.5# L -80 8349' 10819' 8235' 9049' _4-114x3-314" 146 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD / TVD) None 4-1/2", 12.6#, L -80 8390' 8283' / 8175' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ., 1\4AR 9 8 Z C DEPTH INTERVAL (MIA AMOUNT AND KIND OF MATERIAL USED 9660' Set Whipstock 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER-BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period .♦ Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes C."4 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 a y�y,p i s per 20 AAC 250.071. None MAR 01. 2011 RBDMS MAR 0 2 2011 = - Ike Gil & Ga: f t'. .�.$ Form 10-407 Revised 12/2009 CONTINUED ON REVERSE 3 7 / t RIrhOTd� Sub it Original Only 29. GEOLOGIC MARKERS (List all formations and markScountered): 30. F•IATION TESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 22N 9117' 8935' None 21N 9174' 8980' Zone 1B / 14N 9296' 9042' 14P 9302' 9043' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. �3) Signed: Terrie Hubble , Title: Drilling Technologist Date: / I PBU F - 28A 204 310 - 374 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Amanda Rebol, 564-5543 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 la: Classification of Service Wells: Gas Injection, Water Injection, Water- Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50-029- 20123 - 00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • F -28A, Well History (Pre Rig Sidetrack) Date Summary 11/11/2010 T /I /O = 2100/1900/100. Temp = 46 °. IA & OA FLs (SL). IA & OA FLs @ surface. Installed cellar containment. Pin hole in Furmanite wrap detected @ 7 o'clock position of tree. Marked with yellow paint pen. Small amount of dark fluid sitting on top of blue goo, inside flute © 7 o'clock position of tree. Operator notified. 11/11/2010 T /I /O= 2200/2200/1050 Temp =SI Freeze Protect (Eval high IAP (DSO call in IA over MOASP 10/27/10) Pumped 2 bbls neat and 38 bbls crude down the tubing. Pumped 11 bbls of neat and 99 bbls of crude up the flowline to freeze protect per the +60% pumping program. Pressured up FL to 1500 psi. Final WHP = 1700/2400/120. 11/11/2010 DRIFTED TO DEVIATION @ 9305' SLM W/ 2.50" CENT, 1 -1/2" S.BAILER, NO SAMPLE. PULLED 1.5" GENERIC DESIGN FROM ST #6 & #7. SET RK -DGLV IN ST #7 @ 2961' SLM/2978' MD. DISCOVERED SURFACE CASING LEAK WHILE TRYING TO LOAD IA. 11/12/2010 LOADED IA W/ 300 BBLS OF CRUDE. SET RM -DGLV IN ST #7 @ 2961' SLM / 2978' MD. LRS PERFORMS PASSING MIT -IA TO 2500 #. PULLED EMPTY C -SUB FROM 4968' SLM. MADE 1 ATTEMPT TO SET 4 -1/2" PX PLUG BODY IN X- NIPPLE @ 8307' SLM / 8325' MD, REC. 1 CUP OF IPC. 11/13/2010 SET 4-1/2" PX PLUG IN X- NIPPLE @ 8307' SLM / 8325' MD ON SECOND ATTEMPT. TURN WELL OVER TO LRS FOR MIT -T. 11/13/2010 T /I /O = 800/20/50. Temp. = SI Assist SL Load and Test Tbg, MIT T PASSED to 3000 psi. (on 2nd attempt) Pumped 74 bbls of diesel to reach test pressure. Tubing lost 80 psi. in the 1st 15 min. and 0 psi. in the 2nd 15 min. for a total Toss of 80 psi. in a 30 min. test. Bled back 28 bbls to Final WHP = 520/20/40. 11/14/2010 T /I /O= SSV /0 +/50. Temp =SI. MITOA to 1200 psi (FAILED) (eval SH leak). No AL. OA FL near surface. Bled OAP from 50 psi to 0+ psi (FTS). Used 2.5 bbls diesel to pressure OA to 1200 psi. OAP decreased 30 psi in 1st 15 mins, 10 psi in 2nd 15 mins, for a total of 40 psi in 30 mins (see log for details). Note: The Furmanite wrap exhibited an active (weeping) leak during testing. Bled back to 0+ psi (54 gals returns). Final T /I /O= SSV /0 +/0 +. Job is Complete. 12/18/2010 LATCHED AND PULLED P -PRONG @ 8,307' SLM. LATCHED AND PULLED 4 1/2" PX PLUG BODY @ 8,312. LEFT WELL SHUT -IN. 12/19/2010 Objective: Drift for whipstock to 9660'. Perform weekly BOP test. RIH w/ 2.625" BOT dummy whipstock. Start Toad well with KCL. 12/20/2010 T /I /O = SSV /vac/15. Temp = SI. Eval for cellar containment. Installed heater in cellar. No well house or flow line. Cellar containment installed. 12/20/2010 Scope; drift w/ dummy whipstock. Continue RIH w/ BOT2.625" dummy whipstock. Sat down on 3 3/16" x 2 7/8" crossover @ 9663' up wt. (target 9660'). Pooh. Load well w/ 280 bbl KCL and 38 bbls of 60/40 meth. Bleed IA and OA to 0 psi. Job complete. Page 1 of 1 • t ..c,., `'"` r Q Ai3't @FI ��'"ate 2 ` S ?' O �. aP Operatioja Sumimary Re_porp Common Well Name: F -28 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/1/2011 End Date: 1/8/2011 X3- 00Y26 -C: (1,140,201.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/19/1986 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292164900 Active Datum: 29 : 28 9/19/1986 00:00 @66.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/1/2011 00:00 - 02:30 2.50 MOB P PRE RIG RELEASED FROM F -27B AT MIDNIGHT. PREP RIG TO MOVE OFF OF F -27B 02:30 - 04:00 1.50 MOB P PRE PJSM ON RIG MOVE. PULL OFF OF WELL AND STAGE AT EDGE OF PAD FOR PAD PREP 04:00 - 16:00 12.00 MOB P PRE CONDUCT MAINTENANCE WHILE PAD IS PREPPED 16:00 - 18:45 2.75 MOB P PRE WHILE PREPARING TO MOVE RIG OVER WELL, CHECK WAS MADE ON WELL PRESSURE. GAUGE SHOWED 2000 PSI. WSL CONTACTED TO VERIFY PRESSURES. WSL HAD CREW BLEED DOWN; BLEED TO ZERO TOOK 5 MINUTES WITH LIQUID FOLLOWED BY ASSUMED GAS. 'PRESSURE BUILT UP OVER 5'MINUTE SPAN.; WSL HAD CREW MAKE UP MANIFOLD TO ALLOW BLEED LINE AND GAUGE TO BE MADE UP TO BLEED VALVE. BLED DOWN ONCE AGAIN MONITORING PRESSURE OVER TIME. BLEED OFF TO 0 PSI TOOK 5 MINUTES AGAIN. CREW CHANGED OUT, DAY WSL BRIEFED NIGHT WSL ON STATUS. CALL OUT VALVE CREW TO MOBILIZE TO OPEN SSV WITH POSSIBILITY OF RE- CONFIRMING PRESSURE TEST AGAINST TWC. 18:45 - 20:00 1.25 MOB P PRE CONDUCT PJSM ON STATUS OF TREE PRESSURE. PJSM ADDRESSED WHAT TOOK PLACE PRIOR TO OUR CREWS ARRIVAL, THE POTENTIAL HAZARDS, AND THE POTENTIAL AREAS THAT COULD BE CAUSING THE PRESSURE. IT ALSO ADDRESSED THE CONCERNS WITH THE PINHOLE LEAK FROM THE STARTING HEAD AND HOW OUR CREWS WILL MONITOR IT. CREW BROKE FROM PJSM AND WENT TO TREE. 0 PSI WITH NO BLEED OFF ON OA GAUGE AND ON TREE CAP GAUGE WITH MASTER AND SWAB VALVE OPENED. MONITOR GAUGES WHILE WAITING ON VALVE CREW. 20:00 - 21:00 1.00 MOB P PRE PJSM ON RIGGING UP AND OPENING SSV. DISCUSS DETAILS OF WHAT PRESSURE WAS SEEN. CLOSE SWAB AND MASTER, INSTALL BURST DISK INTO SSV. RIG UP AND OPEN SSV. OPEN MASTER, SWAB VALVES. 0 PSI ON GAUGES. CONSULT WITH FIELD SUPERINTENDENT, DISCUSS PRESSURES. MOST LIKELY THERMAL EXPANSION FROM FLUID PACK PREVIOUS NIGHT ( -35 TO -40 DEG, HEATER ON TREE FOR 36 HOURS). DECIDE TO RD VALVE CREW AND MOVE RIG ON WELL. 21:00 - 22:30 1.50 MOB P PRE PJSM ON RIG MOVE. MOVE RIG OVER F -28B. 22:30 - 00:00 1.50 MOB P PRE PREPARE RIG FOR OPERATIONS. CELLAR BUTTONED UP. ADAPTER FLANGE MOBILIZED. BOP READY FOR NU. RIG ACCEPT AT MIDNIGHT. 1/2/2011 16:45 - 21:00 4.25 MOB P WEXIT PJSM ON COIL MANAGEMENT. PULL COIL TUBING ACROSS AND STAB. MU REEL LINES FOR CIRCULATING. Printed 1/17/2011 10:57:55AM ottb America ALAS S Paged o 7 op era #ion maty Common Well Name: F -28 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/1/2011 End Date: 1/8/2011 X3- 00Y26 -C: (1,140,201.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/19/1986 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292164900 Active Datum: 29 : 28 9/19/1986 00:00 @66.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 21:30 0.50 RIGU P WEXIT CONDUCT PRE -SPUD WITH NIGHT CREW 23:30 - 00:00 0.50 RIGU P WEXIT REVERSE CIRCULATE E -LINE FOR PRESSURE BULKHEAD MU 00:00 - 04:00 4.00 BOPSUR P PRE NU TREE ADAPTER FLANGE. NU BOP. DOUBLE CHECK TORQUE ON TREE NUTS AFTER NU, ALL GOOD. 04:00 - 14:30 10.50 BOPSUR P PRE TEST BOP TO 250 LOW. 3500 PSI HIGH WITH 2 3/8" TEST JOINT. AOGCC REP BOB NOBLE Q ry e WAIVED WITNESS OF TEST (PHASE 2, LEVEL D 2 CONDITIONS). TEST WITNESSED BY WSL ROB O'NEAL AND TOURPUSHER TOM KILFOYLE. AFTER CHANGEOUT, TEST WITNESSED BY WSL ROB MIELKE AND TOOLPUSHER JAY MURPHY. 14:30 - 15:30 1.00 BOPSUR P PRE TEST TREE AGAINST TWC TO 3500 PSI. TEST AGAINST MASTER VALVE AND SWAB VALVE. GOOD TESTS. 15:30 - 16 :45 1.25 MOB P WEXIT CONDUCT PRE -SPUD WITH DAY CREW 21:30 - 23:30 2.00 RIGU P WEXIT CLEAN RIG, PREP FOR OPERATIONS WHILE WAITING ON METHANOL TO ARRIVE ON LOCATION (WEATHER) 1/3/2011 00:00 - 04:00 4.00 RIGU P WEXIT REVERSE CIRCULATE E -LINE FOR PRESSURE BULKHEAD MU. BREAK CONNECTION AT REEL. NO E -LINE. RECONNECT. ATTEMPT AGAIN. NO GO. RECONNECT AND RE- ATTEMPT. FIFTH TIME A GO. TAKE ON KCL INTO PITS WHILE CONDUCTING SLACK MANAGEMENT. 04:00 - 13:30 9.50 RIGU P WEXIT MU PRESSURE BULKHEAD. CONDUCT SLACK MANAGEMENT. CUT COIL. MU AND TEST BHI CONNECTOR. 17:00 - 18:45 1.75 RIGD P WEXIT RD LUBRICATOR 13:30 - 15:30 2.00 RIGU P WEXIT PJSM ON RU OF LUBRICATOR AND PULLING TWC. RU DSM LUBRICATOR. 15:30 - 17:00 1.50 RIGU P WEXIT PRESSURE TEST LUBRICATOR. PULL TWC. BLEED OFF LUBRICATOR. 18:45 - 19:00 0.25 KILLW P WEXIT PJSM ON BULLHEAD OPERATIONS. Printed 1/17/2011 10:57:55AM art A ert�d ALASKA B#' ?a9 3 of7 Operation Summary Report Common Well Name: F -28 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/1/2011 End Date: 1/8/2011 X3- 00Y26 -C: (1,140,201.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/19/1986 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292164900 Active Datum: 29 : 28 9/19/1986 00:00 @66.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:30 1.50 KILLW P WEXIT "WHP = 0 PSI. IAP = 0 PSI (CONFIRMED W/ MANUAL GAUGE IN CELLAR). OAP = 0 PSI (CONFIRMED W/ MANUAL GAUGE IN CELLAR). PUMP 10 BBLS NEAT METH SPEAR DOWN WELLBORE, BULLHEADING W/ NO RETURNS. SWAP TO KCL. ONLINE W/ 2% KCL BULLHEADING DOWN BACKSIDE W/ NO RETURNS. INITIAL RATE IS -4.3 BPM AT 0 PSI WHP. POSITIVE WHP AT 16 BBLS AWAY; PUMP AT 4.3 BPM 10 BBLS AWAY: 4.3 BPM AT 3600 PSI. 30 BBLS AWAY: 4.3.BPM AT 3700 PSI. 50 BBLS AWAY: 4.3 BPM AT 3720 PSI. 70 BBLS AWAY: 4.3 BPM AT 3750 PSI. 90 BBLS AWAY: 4.3 BPM AT 3780 PSI. 110 BBLS AWAY: 4.3 BPM AT 3810 PSI. 130 BBLS AWAY: 4.3 BPM AT 4000 PSI. 135 BBLS AWAY: 4.3 BPM AT 3800 PSI. 145 BBLS AWAY: 4.3 BPM AT 3610 PSI. 150 BBLS AWAY: 4.3 BPM AT 3700 PSI. 170 ■/ • BBLS AWAY: 4.3 BPM AT 3720 PSI. 175 BBLS AWAY: 4.3 BPM AT 3770 PSI. 190 BBLS AWAY: 4.3 BPM AT 3830 PSI. 195 BBLS AWAY: 4.3 BPM AT 3810 PSI. 210 BBLS AWAY: 4.3 BPM AT 3810 PSI. 230 BBLS AWAY: 4.3 BPM AT 3710 PSI. 250 BBLS AWAY: 4.3 BPM AT 3700 PSI. 260 BBLS AWAY: 4.3 BPM AT 3700 PSI. 280 BBLS AWAY: 4.3 BPM AT 3690 PSI. 300 BBLS AWAY: 4.3 BPM AT 3700 PSI. 305 BBLS AWAY: 4.3 BPM AT 3700 PSI" 20:30 - 22:15 1.75 KILLW P WEXIT SHUT DOWN PUMPS. FLOW CHECK. RETURNS STARTED AT 1.4 BPM BUT QUICKLY REDUCED TO .8 BPM, 1084 PSI. RETURNS GRADUALLY DROPPED TO .22 BPM AND LEVELED OUT THERE. CHECK SURFACE EQUIPMENT, FIND VALVE ISOLATING PUMP 1 FROM PUMP 2 IS BLEEDING BY. ISOLATE KILL LINE FROM PUMPS AND OUT FLOW NOW AT 0 BPM. PUMP ACROSS TOP TO FILL. CONDUCT ANOTHER FLOW CHECK AND CALCULATE 6 BPH LOSSES. 22:15 - 00:00 1.75 STWHIP P WEXIT CONDUCT PRE -SPUD WITH NEW CREW. PJSM ON MU, RUNNING WHIPSTOCK. MU 3 3/16" BAKER PACKER WHIPSTOCK WITH BAKER HYDRAULIC SETTING TOOL BHA. MU INJECTOR, CONDUCT MEG CONTINUITY TEST. FILL WELL THROUGH COIL. RIH. 1/4/2011 100:00 - 02:00 2.00 STWHIP P WEXIT RIH WITH 3 3/16" BAKER PACKER WHIPSTOCK WITH BAKER HYDRAULIC SETTING TOOL TO 9050'. LOSSES CALCULATED AT APPROXIMATELY 8 BPH WHILE RIH. 02:00 - 02:30 0.50 STWHIP P WEXIT CONDUCT TIE -IN PASS AT 9080'. -10' CORRECTION. Printed 1/17/2011 10:57:55AM , orth America ALASKA BP ` •=aye 4of7 Operation Summary Report Common Well Name: F -28 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 1/1/2011 End Date: 1/8/2011 X3- 00Y26 -C: (1,140,201.00 ) Project: Prudhoe Bay Site: PB F Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 9/19/1986 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: 500292164900 Active Datum: 29 : 28 9/19/1986 00:00 @66.70ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:30 - 03:30 1.00 STWHIP P WEXIT CONTINUE TO RIH. ORIENT WHIPSTOCK ASSEMBLY TO 70 DEG LOHS BEFORE ENTERING 3 3/16" LINER. RIH AND CONDUCT CCL LOG FROM 9600' TO 9400'. CORRELATE CCL TO MCNL LOG. NO COLLARS IN PROPOSED WHIPSTOCK SETTING DEPTH. 03:30 - 03:45 0.25 STWHIP P WEXIT CONTINUE PICKING UP TO CONDUCT TIE -IN AT 9080'. +1/2' CORRECTION. 03:45 - 04:15 0.50 STWHIP P WEXIT RIH TO 9669.25'. PU TO NEUTRAL WEIGHT.k. CLOSE EDC, INCREASE PUMPS. POSITIVE INDICATION OF SHEAR AT 3250 PSI. SLACK ; OFF WITH 5K TO CONFIRM SET. WHIPSTOCK ON SETTING DEPTH OF 70 DEG LOHS AT 9669'. TOP OF WHIPSTOCK AT 9660'. 04:15 - 05:15 1.00 STWHIP P WEXIT PUH TO 9630'. CONDUCT PRESSURE TEST OF PACKER TO 250 PSI LOW AND 2400 PSI HIGH ON CHART. 05:15 - 08:00 2.75 STWHIP P WEXIT DISPLACE KCL TO 8.6 PPG GEO -VIS MUD SYSTEM. 08:00 - 10:00 2.00 STWHIP P WEXIT POOH W/ WHIPSTOCK RUNNING TOOL 10:00 - 11:00 1.00 STWHIP P WEXIT LD WS SETTING BHA AND MU WINDOW MILLING BHA 11:00 - 13:00 2.00 STWHIP P WEXIT RIH W/ WINDOW MILLING BHA. 13:00 - 13:30 0.50 STWHIP P WEXIT LOG TIE -IN. CORRECT -8' 13:30 - 21:00 7.50 STWHIP P WEXIT MILL WINDOW FROM 9660.2' BOTTOM OF WINDOW NOTED AT 9665.4' MILL ADDITIONAL 10' OF RAT -HOLE. REAM WINDOWAREA 3 TIMES AND DRY DRIFT WITHOUT ANY SET DOWNS FORMATION SAND NOTED IN BOTTOMS UP SAMPLES 21:00 - 23:00 2.00 STWHIP P WEXIT POOH. PERFORM IN/OUT JOG NEAR SURFACE. 23:00 - 00:00 1.00 STWHIP P WEXIT PJSM. UD WINDOW MILLING BHA. GUAGE STRING MILL 2.73" NO GO, 2.74" GO. GUAGE WINDOW MILL. 2.72" NO GO, 2.73" GO. WELL STABLE. 1/5/2011 00:00 - 01:00 1.00 DRILL P PROD1 M/U 2.4 DEG MOTOR AND BUILD ASSEMBLY AS PER BAKER DD. P ,A 01:00 - 02:30 1.50 DRILL P PROD1 RIH W/ BUILD ASSEMBLY TO 8635 LOGGING DEPTH. 02:30 - 04:00 1.50 DRILL P PROD1 LOG TIE IN FROM 8635' TO 8795', -9' CORRECTION. TOW @ 9660.5', BOW @ 9665.5'. 114261N 04:00 - 06:00 2.00 DRILL P PROD1 CONTINUE IN HOLE, SHUT DOWN PUMP p � THRU WINDOW, CLEAN, TAG @ 9676'. 26K V UP, 17K DOWN, 2800 PSI FREE SPIN @ 1.5 BPM. TF 70 DEG LEFT OF HS. WOB 1 K, -;815 225 225 PSI MOTOR WORK. COMMENCE DRILLING BUILD SECTION 06:00 - 06:30 0.50 DRILL P PROD1 WIPER TRIP TO WINDOW FROM 9750' 06:30 - 07:15 0.75 DRILL P PROD1 DRILL AHEAD AT 2720 PSI AND 1.55 BPM 07:15 - 08:30 1.25 DRILL P PROD1 STANDBY FOR QUESTIONABLE DD SURVEYS(DLS > 80 DEGREES) 08:30 - 10:15 1.75 DRILL P PROD1 SORT OUT BAD SURVEY AND DRILL AHEAD FOR ADDITIONAL SURVEY POINTS. Printed 1/17/2011 10:57:55AM TREE= - 4" CIW SAFETY NOT •WELL ANGLE> 70° @ 9291' *** AIR SH LEAK-DO NOT FC TUA OR = AX SON PJC D RA F -2 $ B OVER 1200 PSE TO DESIGNED PRESSURE RA 1 G KB. ELEV = 66.7' REPAIR AND DO NOT PUMP METH OR METH BLEND INTO BF. ELEV = 38' OA DUE TO CHEM INCOMPATIBILITY W /EPDXY RESIN IN KOP = 6700' WRAP*** Max Angle = 97 °@ 10082' Datum MD = 9041' 2085' H4 -1/2" OTIS SSSV NIP, ID = 3.813" I . Datum TVD = 8800' SS 1 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2675' '7 v 2978 2978 v 1 OTIS DOME RM V 16 02/13/11 r 6 x 4774 4774 r 0 OTIS SO RM r 20 02/13/11 r 5 5904 5903' 1 OTIS DMY RA r 0 05/20/04 '4 x 6640 6638 8 OTIS DMY RA ' 0 05/20/04 r 3 '7180 `7161 r 18 OTIS DMY RA r 0 05/20/04 Minimum ID = 1.995" @ 9597' 2 7758 7698 24 OTIS DMY RA 0 05/20/04 TOP OF 2 -3/8" SLOTTED LINER 1 8140 8045 25 OTIS DMY RA 0 05/20/04 1 8209' 1H 4 -1/2" OTIS XA SLIDING SLV, ID = 3.813" I ) ( 8268' H TM/ TBG SEAL ASSY I 8283' I- 19 -5/8" X 4 -1/2" TM/ HHBP PKR, ID = 4.750" I 8288' H MILL OUT EXTENSION, ID = 6.004" I 'TOP OF 7" LNR I—I 8321' I-- I 8321' 1-17" BROWN SHORTY HYD. LNR HNGR 1 8325' H4-1/2" OTIS X NIP, ID = 3.813" I itni 1 8349' H3.7" BKR DEPLOYMENT SLV, ID = 3.0" I 8357' I 4 -1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND CT LNR) I I 8369' 1-13-1/2" HES X NIP, ID = 2.813" I 4-1/2" TBG, 12.6 #, L -80 BUTT, .0152 bpf, ID = 3.958" IH 8391' I--- I I 8391' 1-1 4-1/2" WLEG (BEHIND CT LNR) I3 -1/2" LNR, 8.81 #, L -80 STL, .0087 bpf, ID = 2.992" H 8401' I ■ z 1 8401' 1-13-1/2" X 3- 3/16" XO, ID = 2.786" I 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8591' N • 8845' I4 ESTIMATED CEMENT TOP •• • • �•• •• �� 7" MILLOUT WINDOW (F-28A) 9073' • 17" LNR, 26 #, L -80 TC45, .0383 bpf, ID = 6.276" H -9073 F I 9209' Hr. MARKER JOINT 'TOP OF 2 -3/8" LNR I 9590' 9590' -1 2.70" BTT DEPLOYMENT SLV, ID = 2.250" I v' I3- 3/16" BKR PKR WHIPSTOCK (01/04/11) H 9660' I3- 3/16" LNR, 6.2 #, L -80, .0076 bpf, ID = 2.80" H 9678' L L \ 3- 3/16" MILLOUT WINDOW (F -28B) 9660' - 9665' \ PERFORATION SUMMARY REF LOG: 1 \ ANGLE AT TOP PERF: ° @ ' - �Z 7 A -- x .216 Note: Refer to Production DB for historical perf data ` SIZE SPF INTERVAL Opn /Sqz DATE l 2 -3/8" SLOT 9597 - 11130 SLTD 01/14/11 ` 1 2 -3/8" SLTD LNR, 4.40 #, L -80 STL, .0039 bpf, ID = 1.995" I 11130' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/86 N18E ORIGINAL COMPLETION WELL: F -28B 05/22/04 NORDIC 1 CTD SIDETRACK (F -28A) PERMIT No: F 2001620 01/16/11 NORDIC 1 CTD SIDETRACK (F -28B) API No: 50- 029 - 21649 -02 02/05/11 PJC DRLG DRAFT CORRECTIONS SEC 2, T11 N, R13E, 2359' FSL & 2193' FEL 02/26/11 VVWR/PJC GLV C/O (02/13/11) 02/26/11 TQ /PJC SFTY NOTE (COMPOSITE WRAP) BP Exploration (Alaska) NOT OPERABLE: ProdnocrF-2Q/k 040640) Confirmed Starting Hea pouc l of Regg, James B (DOA) | �| From: AK. D&CVVoU integrity CoordinmborJKDCVVaU|ntaghty��oondinabzr8�bp.00ml N|DU Sent: Sundny.Noven�bar14.2O1O11:O7PyW � ^° To: Maunder, Thomas E(DOA); Regg James B(OOA); Schwartz Guy L(OOA);AK, OPGGC1 O8W1;AK, OPS GC1 Field O&M TL; AK, {}PGGC1 VVeUpad Lead; AK, OPG Prod Controllers; Qomooki, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GP13 Central Prod Opt Engr; /\K. RES GPB East Wells Opt Engr; Kominshi, Alice; AK, OPSVVe|| Pod OFT N2 Cm: /\K. O8CVVeU Integrity Coordinator; Janowski, Carrie � Subject: NOT OPERABLE: Producer F-28A (PTD#2040690) Confirmed Starting Head Leak � � AU. Producer F-28A (PTD #2040690) was identified as having a confirm%L� �head h The U was currently Under Evaluation for breaking MOASP on the IA on 10/27/2010. The well passed an MIT-IA on 11/1 2/201 0 confirming the presence of two competent barriers. During the testing, the carbon fiber repair of the starting head was observed to be we�t�d through the wrap. An MIT-OA to 1200 psi passed on 11/14/2010, but fluid was again confirm'ed seeping through the wrap. With an observed leak to surface, the well has been reclassified as NOT 9PERABLE. The plan forward: 1. DHO: Remove existing carbon fiber wrap. 2.Furmanite: Re-apply carbon fiber wrap tn starting head. -- — ----- Please call if you have questions orconcerns. Thank you, NOV � ^`w, � Gerald Murphy (a|LTorinRoanhingar) Well Integrity Coordinator � Office (9O7)G5S-5102 � Cell (QO7)752-O755 � Pager H9O7>G5S'51OO Ext. 1154 From: AK, uxC Well Integrity Coordinator Sent: Saturday, October 30,2010 1m7pm To: 'maunder, Thomas s(oOA)';'Regg, James a(moA)'/^Schwanz, Guy (ooA'} AK, Op5sC1OSM/ AK, Up3GCz Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D&C Well Services Operations Team Lead; AK, D&C Wireline Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Kaminski, Alice; AK, OPS Well Pad opTmZ Co AK, uxC Well Integrity Coordinator; Janowski, Carrie Subject: UNDER EVALUATION: Producer F'zux(pTo#zo*oeeo) Sustained m Pressure Above noAsr AU, ProduoerF'2BA ((PTD#2D4O8SO) has confirmed sustained IA casing pressure above K8OASP. The wellhead pressures were tubing/|A/OA equal bo80O/2OG0/88on1O/37/2O1O. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. S|iok|ina: Install dummy goo lift valves 2. FuUbono: MIT-IA to 3500 psi ll/]5/2Ol0 NOT OPERABLE: Producer F -28A (P#2040690) Confirmed Starting Head4k Page 2 of 2 40 3. Electric line: Leak detect log (pending results of MIT -IA) A TIO plot and wellbore schematic have been included for reference. Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/15/2010 • • • ALASKA SEAN PARNELL, GOVERNOR XLA►7KA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION CO MMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. L- b P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU F -28A Sundry Number: 310 -374 Dear Mr. McMullen:D NCN �� 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 5 day of November, 2010. Encl. STATE OF ALASKA (/ p ALASKOL AND GAS CONSERVATION COMMAN )�'� , j� APPLICATION FOR SUNDRY APPROVAL 1 20 AAC 25.280 1. Type of Request: ❑ Abandon ® Plug for Redrill - ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ® Development - ❑ Exploratory 204 -069. 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 21649 - 01 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU F -28A - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028280 I 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 TVD (ft): Plugs (measured): Junk (measured): 10819' - 9049' 10782' 1 9051' 10062' None Casing Len th Size MD TVD Burst Collapse Structural Conductor 11 110 110 Surface 2675' 13-3/8" 2675' 2675' 5380 2670 Intermediate Production 9 - 5 /8" 8457' 6870 47 Liner 754' 7" 8321'- 9075' 8209' - 8898' 7240 541 Liner 2470' 3 -1/2" x 3- 3/16" x 2 -7/8" 8349'- 10819' 8235'- 049' 10570 11160 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9770'-9924' 9054'- 9045' 4 -1/2 ", 12.6# L -80 8390' Packers and SSSV Type: 9 -5/8" TIW HHBP Packer I kers and SSSV 8283'/ 8175' (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑Exploratory ® Service Development ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 17, 2010 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. S6 � Contact Amanda Rebol 564 -5543 Printed Name John A en Title Engineering Team Leader Prepared By Name/Number: Signature Phone / Date (( 3 o Elizabeth Barker, 564 -4628 Commission Use Onl Conditions of pproval: Notify Commission so that a representative may witness 3 ( o --5 Lf Plug Integrity 1;14 Sundry Number: J J� El Plu Int ri OP Test ❑Mechanical Inge city Test ❑ Location Clearance 3So� Ps Bd 1/2 e s -� / Other: 7' l E OE IE> A - c- e.,�..�..x ��(?��''�� / Z" ' Z6- �zt3�3 2010 Subsequent Form Required: l p " Y � / 4 . 3 Oil & r83 cons. APPROVED BY O Approved By: COMMISSIONER THE COMMISSION Date ,�/ _J�5 Form 10-403 Revi 0V 05 -20 O RIGINAL Submit In Duplicate To: Alaska Oil & Gas Conservation Commission O bp From: Amanda Rebol CTD Engineer Date: October 26, 2010 Re: F -28A Sundry Approval Sundry approval is requested for F -28A. F -28A was a 2004 coil sidetrack targeting Zone 1B sands after the parent well, F -28, gassed out. F -28A was completed with a 3 -1/2" x 3- 3/16" x 2 -7/8" tapered solid liner that was cemented and ties back into the existing 4 -1/2" tubing. 520' of initial perforations were shot. After the sidetrack, F -28A produced full -time until 2008 when GORs began to rise. When shut -in, F- 28A healed enough to make in an economic cycler from 2008 -2009. In 2009, the well was shut -in for bubbling in the cellar and a starting head leak. The starting head leak was repaired in Jan 2010 with a composite wrap, furmanite, making it operable again. However, once POP'd, F -28A went to high GORs. In March 2010, a CIBP was set at 10,062', effectively shutting off all of the existing perforations. Adperfs were shot from 9,770- 9,800', 9,894- 9,924' and 9,812- 9,842' MD — the adperfs were effective at adding production for a short time before oil rates declined rapidly. A diesel /xylene bullhead stimulation treatment was pumped in August 2010 in the hopes of mobilizing the MHO/HOT and allowing for greater fluid influx to the wellbore. However, this stimulation was unsuccessful and the well was shut if for low PI. REASON FOR SIDETRACK Given the low oil rates and lack of any additional future wellwork opportunities, F -28A is a good candidate for a coil sidetrack. The proposed sidetrack will target 1450' of Zone IA and will provide additional offtake in a —250 acre drainage target in central F -Pad. The proposed plan for F -28B is to drill a through tubing sidetrack with the SLB/Nordic 1 Coiled Tubing Drilling rig on or around December 3, 2010 The existing perforations will be isolated beneath a packer whipstock set in the 3- 3/16" tubing. The sidetrack, F -28B, will exit the existing 3- 3/16" liner and kick off in zone, intentionally drilling just in the MHO/HOT for the first portion of the wellbore to maximize gas standoff and leave options for future sidetracks. 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. -r- i 1( �i g ar i ey l j� 9 j CorCv- , Pre -Rig Work: (scheduled to begin November 17, 2010) 14fr y C y aef 1. O MIT -IA 3000psi 4s" 3 �� ¢ f �eW l'lfe l rTe 2. O MIT -OA 2000psi 3. F PPOT -T /IA C.04' O� qt 4. C Drift for whipstock to 9,675' d fc"Ilt "0 5. W Check lock -down screws; torque to spec V, ell *,ld ,'Able !e covr�? 6. V Set TWC, pressure test tree, pull TWC A,'rkb., ej� 1 4P ea 7. O Remove wellhouse, level pad, remove flow line 8. V Set TWC (within 24 hours of MIRU Nordic 1) Rig Work: (scheduled to begin on December 3, 20 10) W In ;ps 1. MIRU and test BOPE to 250 psi low and 3500 psi high. iz! s Sej t - k.. Wttio r A , k 2. Mill 2.74" window at 9,660' through 3- 3/16" liner ce 7G6o' 3. Drill Build: 3" OH, 450' (35 deg /100 planned) 4. Drill Lateral: 3" OH, 1000' (12 deg /100 planned) 5. Run 2 -3/8" slotted liner, leaving TOL at 9,600' 6. Freeze protect well, RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Pull TWC Amanda Rebol CTD Engineer 564 -5543 CC: Well File Sondra Stewman/Terrie Hubble I' TREE = . 4" CIW SAFETY NOTES: COMPOSITE WRAP REPAIR SH WELLHEAD = MCEVOY LEAK -NT PUMP METH OR METH BLEND INTO ACTUATOR = AXELSON • F OA DU CHEM INCOMPATIBILITY W /EPDXY KB. ELEV = 66.7' RESIN IN WRAP BF. ELEV = _. 38 KOP = ...... _ 6700' Max Angle = 94 @ 9515' 2085 4 -1/2" OTIS SSSV NIP, ID = 3.813" Datum MD = 9041' Datum TV D = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" 2675' GAS LIFT MANDRELS STI MD I TVD DEV TYPE VLV LATCH SIZE DATE Minimum ID = 2.380" @ 9678' 7 2978 2978 1 OTIS DOME RM 16 06/29/10 3- 3/16" X 2-7/8" XO 6 4774 4774 0 OTIS SO RM 20 06/29/10 5 5903 5903 1 OTIS DMY RA 0 4 6639 6638 6 OTIS DMY RA 0 3 7180 7161 17 OTIS DMY RA 0 2 7758 7698 24 OTIS DMY RA 0 1 8140 8045 25 OTIS DMY RA 0 8208' OTIS XA SLIDING SLV, ID = 3.813" 8268' T TBG SEAL ASSY 8283 9 -5/8" TIW HHBP PKR, ID = 4.750" 8288' MILL OUT EXTENSION, ID = 6.004" 8321' 7" BROWN SHORTY HYD. LNR HNGR 8325 4 -1/2" OTIS X NIP, ID — 813 7 8349' 3.7" BKR DEPLOYMENT SLV, ID = 3.0" 8357' 14-1/2" OTIS XN NIP, M ILLED ID = (BEHIND CT LNR) 4 -1/2" TBG, 12.6 #, L-80_0152 bpf, ID = 3.958" 8390' 8369' 3 -1/2" HES X NIP, ID = 2.813" 3 -1/2" LNR 8.81 #, L-80,.0087 bpf, ID = 2.992" 8401' 8390 4 -1/2" WLEG (BEHIND CT LNR) 9 -5/8" CSG, 47 #, L -80, ID = 8.681" 8591' 8401 3 -1/2" X 3- 3/16" XO, ID = 2.786" 8845' ESTIMATED CEMENT TOP TOP OF WHIPSTOCK 9069' 7" LNR, 26 #, L-80_0383 bpf, ID = 6.276" 9073' TOP OF WINDOW (F -28A): 9073' PERFORATION SUMMARY 9678 3- 3/16" X 2 -7/8" XO, ID = 2.380" REF LOG: ANGLE AT TOP PERF: 95° @ 9770' 10062 2- 7/8 "C1BP(03/21/10) Note: Refer to Production DB for historical pert data SIZE SPF I INTERVAL Opn /Sqz DATE 2" 6 9770-9800 0 03/21/10 10782 PBTD 2" 6 9812-9842 0 03/21/10 2" 6 9894- 9924 0 03/21/10 2" 6 10080 - 10300 C 05/22/04 3- 3/16" LNR, 6.2 #, L-80_0076 bpf, ID = 2.80" 9678' 2" 6 10350 - 10520 C 05/22/04 2" 6 1 10640 - 10770 C 05/22/04 2 -7/8" LNR, 6.4 #, L-80_0058 bpf, ID = 2.441" 10819 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10112/86 ORIGINAL COMPLETION 03/22/10 SV GLV TVDCORRECTIONS WELL: F -28A 05/22/04 KAK CTD SIDETRACK (F -28A) 06/29/10 JLJ /PJC GLV C/0 (06/29/10) PERMIT No: 2040690 06/01/04 RMH/KAK GLV C/O 09/23/10 PJC SAFETY NOTE UPDATE API No: 50- 029 - 21649 -01 12/08/09 ?/ PJC SET PX PLUG (11/18/09) SEC 2, T11 N, R1 3E, 2359' FSL & 2194' FEL 03/02/10 SEW /RPC PX PLUG PULLED (02/14/10) 03/22/10 ACB /SV SET CIBP /ADPERF (03/21/10) BP Exploration (Alaska) TREE = 4" CIW SAFETY NOTES: COMPOSITE WRAP REPAIR SH WELLHEAD = McEVOY LEAK- DUE PUMP METH OR METH BLEND INTO - - .----T OA DUETd CHEM INCOMPATIBILITY W /EPDXY ACTUATOR = AXELSON • F-28B KB. R EV = 66. 7' Proposed CTD Sidetrack ---- - - - - -- -- RESIN IN WRAP BF. ELEV = 38' KOP = 6700' Max Angle = 94 9515' 2085' 4 -1/2" OTIS SSSV NIP, ID = 3.813" Datum MD = 9041' O Datum TVD = 8800' SS 13 -3/8" CSG, 72#, L -80, ID = 12.347" 2675' GA S LIFT MA NDRELS STI MD I TVD DEV TYPE VLV LATCHI SIZE DATE Minimum ID = 2.786" @ 8401' 7 2978 2978 1 OTIS DOME RM 16 06/29/10 6 4774 4774 0 OTIS SO RM 20 06/29/10 3-1/2" X 3- 3/16" XO 5 5903 5903 1 OTIS DMY RA 0 4 6639 6638 6 OTIS DMY RA 0 3 7180 7161 17 OTIS DMY RA 0 2 7758 7698 24 OTIS DMY RA 0 1 1 8140 8045 25 1 OTIS DMY RA 0 8208' OTIS XA SLIDING SLV, ID = 3.813" $268' 4i TBG SEAL ASSY $2$3' 9 -5/8" TIW HHBP PKR, ID = 4.750" $2$$' MILL OUT EXTENSION, ID = 6.004" 8321' 7" BROWN SHORTY HYD. LNR HNGR 8325' +-1/2" OTIS X NP, ID= 3.813" $349' 3.7" BKR DEPLOYMENT SLV, ID = 3.0" 8357' 41/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND CT LNR) 4-1/2" TBG, 12.6#, L-80_0152 bpf, ID = 3.958" 8390' 8369 3-1/2" HES X NIP, ID = 2.813" 3 -1/2" LNR, 8.81 #, L-80_0087 bpf, ID = 2.992" 8401' 8390' 4-1/2" WLEG (BEHIND CT LNR) 9 -5 /8" CSG, 47 #, L -80, ID = 8.681 " 8591' 8401' 3 -1 /2" X 3- 3/16" XO, ID = 2.786" TOP OF WHIPSTOCK 9069' 8845' ESTIIMTED CBVIENT TOP 7" LNR, 26#, L-80_0383 bpf, ID = 6.276" 9073' TOP OF WINDOW (F -28A): 9073' 3- 3/16" Packer Whipstock _Top of Liner - 9600 ' PERFORATION SUMMARY REF LOG: 3- 3/16" LNR, 6.2#, L-80_0076 bpf, ID A NGLE AT TOP PERF: 95° @ 9770' 2 -3 /8" slotted liner - 11,110' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 88' 2" 6 9770-9800 O 03/21/10 2" 6 9812-9842 O 03/21/10 2" 6 9894-9924 O 03/21/10 2" 6 10080 - 10300 C 05/22/04 9678' 3- 3116" X 2 -7/8" XO, ID = 2.380" 2" 6 10350 - 10520 C 05/22/04 10062' 2 -7/8" CIBP (03/21 /10) 2" 1 6 1 10640 - 10770 C 05/22/04 2 -7/8" LNR, 6.4#, L -80, .0058 b f p, ID = 2.441" 10819' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/86 ORIGINAL COMPLETION 03/22/10 SV GLV TVD CORRECTIONS WELL: F -28r 05/22/04 KAK CTD SIDETRACK (F -28A) 06/29/10 JLJ /PJC GLV C/O (06/29110) PERMIT No: 2040690 06/01/04 RMH/KA K GLV C/O 09/23/10 PJC SAFETY NOTE UPDATE A PI No: 50- 029 - 21649 -<i t 12/08/09 ?/ PJC SET PX PLUG (11/18/09) 10/05/10 AER PROPOSED CTD SIDETRACK SEC 2, T11 N, R13E, 2359' FSL & 2194' FEL 1 03/02/10 SEW /RPC PX PLUG PULLED (02/14!10) 03/22/10 ACB /SV SETCIBP /ADPERF(03 /21/10) I I I BP Exploration (Alaska) NORDIC- CALISTA RIG 1 CHOKE / REEL/CIRCULATION MANIFOLD DIAGRAM V12 V14 t 7-1115" 5000 psi GOP's ID = 7.06" V15 V71 7 tne" bow p4. RY�e Transducers ORB`:: 1 V V2 V1 V18 GAS$ list•: WwM BOP sae "aaw r« tan wiled "IM dalli VB r,ns• taelf . Rxre V10 V17 NCR IC IK OK To Poor Boy Gas Buster V4 5 V7 V13 Y ins^ i000 p 1, W[,2t B.Otl" 6000 Pet NCq' V$ All atne" eaoo pN CNECK • Manual Choke tlAlV3 MCB Alk tlelw x woo pl MEOH /DI.sel P LIM CoFIeX Hose 1/4 Turn Halco 1OWOG To Production Tree or Cross Over m transducers CoFlex Hose Nll ;CV12 _ To Coiled Tubing „' m Bleed OH Inner Reel Valve CV 33._.._ Leve I Cement Line M Ground l Tle-In Milan 111111111 lnunigilnillilliill !,N10_ CV3 CV2 TStentl Pipe Manual Choke • Pressure Truretlucere CV9 t CV17 CV1 ;CVS Tiger Tank Mud Pump 2 In From O Baker + MP 1 6 MP 2 ® Choke Kill CV14 to Pits Line Rig Flow J + Mud Pump el V,5 Revers -Girt t M ChCT To Manifold CV15 1-Jun-2010 CoFNZ Hose r w Page 1 of 1 Schwartz, Guy L (DOA) From: Rebol, Amanda [reboa2@BP.com] Sent: Friday, November 05, 2010 9:41 AM To: Schwartz, Guy L (DOA) Subject: Re: F -28A P &A ( PTD - 204 -069) Guy - Due to deviation at the whipstock set depth, we'll be doing it with the rig. It'll be our first operation once we're over the well. F -27B will be doing the same. Thanks - Amanda On Nov 5, 2010, at 9:21 AM, "Schwartz, Guy L $DOA $" <guy.schwartz@alaska.gov> wrote: Amanda, In reviewing the procedure for F -28A I don't see a step for setting the whipstock. Is E -line setting it or Coil pre rig ?? Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) 11/5/2010 UNDER EVALUATION: Producer 8A (PTD #2040690) Sustained IA Presibe Above MOASP Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Sent: Saturday, October 30, 2010 1:07 PM �z 111410 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Field O &M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB Central Prod Opt Engr; AK, RES GPB East Wells Opt Engr; Kaminski, Alice; AK, OPS Well Pad DFT N2 Cc: AK, D &C Well Integrity Coordinator; Janowski, Carrie Subject: UNDER EVALUATION: Producer F -28A (PTD #2040690) Sustained IA Pressure Above MOASP Attachments: Producer F -28A (PTD #2040690) TIO Plot.doc; Producer F -28A (PTD #2040690) wellbore schematic.pdf All, Producer F -28A ((PTD #2040690) has con firmed sustained IA casing pressu above MOASP. The wellhead pressures were tubing /IA/OA equal to 860/2060/80 on 10/27/2010. The well has been reclassified as Under Evaluation. The well may remain online while work is conducted to attempt to restore integrity. Plan forward: 1. Slickline: Install dummy gas lift valves 2. Fullbore: MIT -IA to 2500 psi 3. Electric line: Leak detect log (pending results of MIT -IA) � A TIO plot and wellbore schematic have been included for reference. <<Producer F -28A (PTD #2040690) TIO Plot.doc>> <<Producer F -28A (PTD #2040690) wellbore schematic.pdf>> Please call if you have any questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/1/2010 PBU F -28A PTD #2040690 10/30/2010 TIO Pressures Plot Well: F -28 I 4,000 I 1 l j 3,000 3 0 Tbg f- IA 2,000 OA OOA OOOA On 3 s i 1,000 i 1 07/31110 08/14/10 08128110 09/11/10 09/25/10 10/09110 10123x10 i i TREE = 4" CIW SAIFET&TES: COMPOSITE WRAP REPAIR SH WELLHEAD = McEVOY LEAK-T PUMP METH OR METH BLEND INTO ACTUATOR= AXR SON F-28A DIMO CA DUE TO CHEM INCOM PATIBILITY VIP /EPDXY KB. R EV = 66.7' RESIN IN WRAP BF. R EV = 38' KOP = 6700', Max A ngle = 94 @-9515' 2085' _]+-1/2" OTIS SSSV NIP. 0=181i Datum MID = 9041' Datum TVD = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" GAS LIFT MANDREL ST I MID I TVD DEV TYPE VLV LATCH SIZE DATE r - --- Minimum ID = 2.380" @ 9678' 7 '2978 r 2978 '1 OTIS DO RM 16 06/29/10 r 6 4774 4774 ' 0 OTIS SO RM 20 06/29/10 3-3/16" X 2-7/8" XO r 5 5903 5903 ' 1 OTIS DMY RA 0 "4 6639 6638 " 6 OTIS DMY RA r 0 r 3 7180 F 7161 17 OTIS DMY RA 0 2 7758 7698 24 OTIS DMY RA 0 1 1 8140 18045 25 OTIS DMY RA 0 8208' -1 OTIS XA SLIDING SLV, ID = 3.817 268' - 4 - Trw -- TBG SEAL Ass 9-5/8" TIW HHBP PKR, ID = 4.750" 8288' MILL OUT EXTENSION, ID = 6.004" 8321 7" BROWN SHORTY HYD. LNR HNGR F8325; F OTIS X NIP, ID 8349' -� 3.7" BKR DEPLOYMENT SLV, ID 835T 4 -1/2" OTIS XN NIP, MILLED ID= 3.80" (BEHIND CT LNR) 4-112" TBG, 12,6#, L-80-0152 bpf, ID = 3.958" 8390' 8369' j-43-1/THESX NIP ID=2,813" I 13-1/2" LNR, 8.81#,L-80,.0087 bpf, ID=2.992" --F 840 -4 -1/2 WLEG (BEHIND CT LNR) - j9-5/8"CSG,47#,L-80,ID=8.681 71 - F - 8591' 3-1/2" X 3-3/16" XO, ID = 2.786" --------------- rESTIMATED CEMENT TOP --L ------------------------- ITOP OFWHIPSTOCK - r -- 90 - 69 — ' - ]— 7" LNR, 26#, L-80_0383 bpf, ID TOP OF WINDOW (F-28A): 9073' PERFORATION SUMMARY 967$' -j 3-3/16" X 2-718" XO, ID = 2.380" REF LOG: A NGLE AT TOP PERF: 95' @ 9770' Note: Refer to Production DB f or historical perf data 10062' -f 2 -7/8" - - CI BP70 3 /21 / - 1051 — SIZE SPF INTERVAL Opn/Sqz DATE ---I 2" 6 9770-9800 0 03/21/10 10782 4 2" 6 9812-9842 0 03/21/10 2" 6 9894-9924 0 03/21/10 2" 6 10080 - 10300 C 05 13-3/16" LNR, 6.2#,L-80,.0076 bpf, :1D =2�80" 9678' 1 2" 6 10350 - 10520 C 05/22/04 2" 1 6 1 10640 - 10770 C 05/22/04 12-7/8" LNR, 6.4#, L-80, .0058 bpf 10819' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10112186 ORIGINAL COM PLETION 103/22110 SV GLV TV CORRECTIONS WELL: F-28A - 051 - 22/04 KAK CTD SIDETRACK (F-28A) 06/29/10 JLJ/PJC GLV C/O (06/29110) PERMIT No: F 2040690 06/01/04 RMH/KAK GLV C/O 09/23/10 PJC SAFETY NOTE UPDATE API No: 50-029-21649-01 . 12/08/09 . ?/PJC SETPX PLUG (11/18/09) SEC 2, T1 N, R1 3E, 2359' FSL & 2194' FEL EW/RPCI PX PLUG PULLED (02/14/1 03/22/101 ACB/SV ISEFCIBP/ADPERF(03/21/10) BP Exploration (Alaska) ont 3/t o • Schlumherger Alaska Data & Consulting Services 2525 Gambell Street, Suae 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.5561 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD N-09 3-27/M-33 GNI-03 BCZ2-00013 BBSM-00024 AY1 M-00049 PRODUCTION PROFILE PRODUCTION PROFILE STATIC PRESSURE SURVEY a 7/09/10 07/08/10 07/10/10 i 1 1 1 1 1 C-20C 02-108 F-28A BAUJ-00009 BCRJ-00013 BD88-00002 MCNL RST - MCNL C 03/07/10 05/07/10 03/20M0 1 1 1 1 1 1 BP Exploration (Alaska) Inc. Pelrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street. Suite 400 Anchorage, AK 99503-2838 ~~~ ~lJl., ~. ~ 2Q1~1 t.~ OPERABLE: Producer F-28 (PTD #040690) Tubing integrity restored • Page 1 of 1 Regg, James B (DOA) From: AK, D&C Well Integrity Coordinator [AKDCWeIIlntegrityCoordinator@bp.com] ~ r ~ JI~II~ Sent: Tuesday, June 29, 2010 3:33 PM ~ I To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK, OPS GC1 Facility OTL; AK, OPS GC1 Field O&M TL; AK, OPS GC1 Wellpad Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: AK, D&C Well Integrity Coordinator; Janowski, Carrie; Isakson, Shawn Subject: OPERABLE: Producer F-28 (PTD #2040690) Tubing integrity restored All, Producer F-28 (PTD #2040690) passed an MITIA after the as lift valves were dummied off. The passing test verifies that tubing integrity has been restored. The well has been rec asst le as Derable and may be placed on production when convenient for operations after the GC1 turn-around. Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659-5102 Harmony Radio x2376 Cell (406) 570-9630 Pager (907) 659-5100 Ext. 1154 ~ .Y a ~) ~I (~ ~~~ From: AK, D&C Well Integrity Coordinator Sent: Wednesday, June 09, 2010 11:05 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy (DOA)'; AK, OPS GCl OSM; AK, OPS GCl Facility OTL; AK, OPS GCi Field O&M TL; AK, OPS GCl Wellpad Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; Cismoski, Doug A; Engel, Harry R; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, D&C Well Integrity Coordinator; AK, RES GPB East Production Optimization Engineer; AK, RES GPB West Production Optimization Engineer Cc: Quy, Tiffany; Prowant, Josh L (CH2M Hill); Holt, Ryan P (ASRC) Subject: UNDER EVALUATION: Producer F-28 (PTD #2040690) Sustained Casing Pressure on the IA All, Producer F-28 (PTD #2040690) has confirmed sustained IA ressure to TxIA communication. The wellhead pressures were tubing/IA/OA equal to 158/2 80/20 on 6/7/2010 with the IA brea Ing MOASP. The well has been reclassified as Under Evaluation. Plan Forward: 1. DHD: TIFL when well is brought back online A wellbore schematic and TIO plot are included for reference. =~ « File: Producer F-28 06-09-2010 TIO Plot.doc » Please call if you have questions or concerns. Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 7/15/2010 PBU F-28 PTD #2040690 6/9/2010 TIO Plot ,: 4,~i1~0 ~,00~ ~r~~~ 1.~i~0 _. bell: F-28 l~~L ~~ :~~7 I~ ~]3~2~~ 7 0 04~10~7 0 ll4 ~~4r"7 0 05~'0~}10 0~~~~}1 ~ X6/05/10 ~~ T ~g ~- 1,4 ~~ ~~ 0~~ -~__ 0~~~ On r TREE = 4" CIW - ---- - WELLHEAD = -- McEVOY ACTUATOR = AXEISON KB. ELEV..- 66.T BF. ELEV = 38' KOP = 6700' Max Angle = 94 @ 9515' Datum MD = 9041' Datum TVD = 6800' SS ~ 13-3/8" GSG, 72#, L-80; ID = 12.347" ~ ~ F-28A Minimum ID = 2.380" @ 9678' 3-3/16" X 2-718" X4 SAFETI~TES: 4-112" OTIS SSSV NIP. ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 7 2978 2978 1 OTIS DOME RM 16 06!01 /04 6 4774 4774 0 OTIS SO RM 20 06!01 /04 5 5903 5903 1 OTIS DMY RA 0 4 6639 6638 6 OTIS DMY RA 0 3 7180 7161 17 OTIS DMY RA 0 2 7758 7698 24 OTIS DMY RA 0 1 8140 8045 25 OTIS DMY RA 0 OTIS XA SLIDING SLV, ID = 3.813" 826$' -jTNV TBG SEAL ASSY 8283' 9-5I8" TIW HHBP PKR, ID = 4.750" $288' MILL OUT EXTENSION, ID = 6.004" $321' 7" BROWN SHORTY HYD. LNR HNGR $325' 4-112" OTIS X NIP, ID = 3.813" $34g' 1-13.7" BKR DEPLOYMENT SLV, ID = 3.0" 835?' 4-1/2" OTIS XN NIP, MILLED ID = 3.80" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ $390' 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" $401' 9-518" CSG, 47#, L-80, ID = 8.681" $591' TOP OF WHIPSTOCK 9069' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9073' PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 95° @ 9770' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9770 - 9800 O 03121!10 2" 6 9812 - 9842 O 03!21(10 2" 6 9894 - 9924 O 03!21/10 2" 6 10080 - 10300 C 05122104 2" 6 10350 - 10520 C 05122(04 2" 6 10640 - 10770 C 05122/04 ' (BEHIND CT LNR} 8369' 3-1/2" HES X NIP, ID = 2.813" $390' 4-112" WLEG (BEHIND CT LNR) i $401' 3-112" X 3-3116" XO, ID = 2.786" L $$45' ESTIMATED CEMENT TOP 'i TOP OF WINDOW (F-28A): 9073 967$' 3-3116" X 2-7i8" XO, ID = 2.380" 10062' -{2-718" CIBP (03121110) 10r 7$2' ~ PBTD 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" (°j 9678' I 2-718" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" 1081 DATE REV BY COMMENTS DATE REV BY COMMENTS 10!12!86 ORIGINAL COMPLETION 03122/10 SV GLV TVDCORRECTIONS 05/22/04 KAK CTD SIDETRACK (F-28A) 06!01!04 RMWKA GLV CIO 12/08!09 ?( PJC SET PX PLUG (11!18109} 03!02/10 SEW/RPC PX PLUG PULLED (02114/10) 03/22/10 ACB/SV SET CIBP/ADPERF (03(21!10) PRUDHOE BAY UNff WELL: F-28A PERMIT No: 2040690 API No: 50-029-21649-01 SEC 2, T11 N, R13E, 2359' FSL & 2194' FEL BP Exploration (Alaska) ~~~~,~I.~n STATE OF ALASKA ALASK~ AND GAS CONSERVATION COMMISS~ MAR ~ 0 2Ba~PORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon Well ^ Plug Perforations Stia ulate^ Other ~ SET Pertormed: ~.~~~~ubing^ Perforate New Pool ^ N.y'~Waiver^ Time Extension ^ BRIDGE PLUG Change Approved Prq~lOperat. Shutdown^ Perforate Q Re-e ter Suspended Well ^ C~BP 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development Q Exploratory ^ 204-0690 3. Address: P.O. Box 196612 Stratigraphic^ Service .API Number: Anchorage, AK 99519-6612 50-029-21649-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028280 ~ PBU F-28A 10. Field/Pool(s): PRUDH OE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10819 feet Plugs (measured) 10062' feet true vertical 9049.27 feet Junk (measured) None feet Effective Depth measured 10782 feet Packer (measured) 8208 true vertical 9051.34 feet (true vertical) 8107 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" Surtace - 110 Surtace - 110 Surtace 2675 13-3/8" 72# L-80 Surface - 2675 Surface - 2675 4930 2670 Intermediate 8593 9-5/8" 47# L-80 Surface - 8593 Surface - 8457 6870 4760 Liner 754 7" 26# L-80 8321 - 9075 8209 - 8898 7240 5410 Liner 1277 3-3/16" 6.2# L-80 8401 - 9678 8282 - 9058 Liner 1141 2-7/8" 6.4# L-80 9678 - 10819 9058 - 9049 10750 11160 Pertoration depth: Measured depth: SEE ATTACHED - _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 8390 SURFACE - 8272 Packers and SSSV (type, measured and true vertical depth) 9-5/8" TIWHHBP PKR 8208 8107 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~~~~ ~~~ ~` ~~~ ~` ~ ~ ~ ~ ~ ~ Treatment descriptions including volumes used and final pressur e: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: Subsequent to operation: 14. Attachments: 1 Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GS OR ^ WAG ^ GINJ ^ WINJ ^ 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: N/A Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 3/26/2010 Form 10-404 Re ised 7/2009 R~DM~ rIN~ ~ ~ 20'~ ~~ Submit Original Only F-28A 204-069 DGDC ATTA~`I-IMFNT Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-28A 5/21/04 PER 10,080. 10,300. 9,050.93 9,051.7 F-28A 5/21/04 PER 10,350. 10,520. 9,053.35 9,052.49 F-28A 5/21/04 PER 10,640. . 10,770. 9,051.8 9,051.85 F-28A 7/10/08 BPS 8,325. 10,770. 8,213.07 9,051.85 F-28A 7/23108 BPP 8,325. 10,770. 8,213.07 9,051.85 F-28A 11/18/09 BPS 8,296. 10,080. 8,186.77 9,050.93 F-28A 2/14110 BPP 8,296. 10,080. 8,186.77 9,050.93 F-28A 3/21/10 APF ~/' 9,812. 9,842. 9,049.44 9,046.37 F-28A 3/21/10 APF 9,894. 9,924. 9,044.62 9,045.4 F-28A 3/21/10 BPS 10,062. 10,063. 9,049.67 9,049.74 F-28A 3/22/10 APF 9,770. 9,800. 9,054.25 9,050.93 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 F-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 3/20/2010 CTU #9 w/ 1.5" CT Job Scope: Depth/MCNL Log, Set CIP, Adperf «InterAct Publishing» Travel to location, MIRU, MU Memory GR/CCL and ;CNL in 2.20" carrier OAL 25.7'. RIH. Pump 180 bbls (1.5 wellbore volumes) 1 `KCL @ 5 bpm @ 400 psi. reduce rate to 1 bpm and log CNL 9550' to 8500' ~60 fpm. RBIH and log CNL repeat and GR/CCL 10,200' - 8100' @ 60 fpm. paint flag @ 9999.8. cont log to 8100'. Pooh. no data revovered. MU and RIH w/ same to repeat Memory Logs. **job in progress** 3/21/2010~CTU 9 w/ 1.5" CT Job Scope: MCNL/Set CIBP/Adperf (Cont. from WSR `03-20-10) «InterAct Publishing» Continue RIH with repeat GR,CCL, MCNL.Notified the SLB IT recovered data from previous run. Pooh. MU &RIH 'w/ Halliburton 2 7/8" CIBP. Tie in to flag and set plug @ 10,062'. POH and LD HES. MU and RIH w/Gun #1. Test CIBP 2500 psi (pass) Continue RIH and ;perforate 9,894' - 9,924'. POH and LD gun. RIH w/ Gun #2, Qerforate 9,812' - ~9.842'. POH RIH w/gun#3 **job continued on WSR 03-22-10** Perforate w/ 2.0" Power Jet, 6 spf, 60 deg phsg, .23" EHD, and 19" TTP Correlate depths to top of CIBP @ 10,062' . 3/22/2010¢CTU 9 w/ 1.5" CT Scope; MCNL/Set CIBP/ Adperf (Cont. from WSR 03-20-10) I«interact publishing» Cont circ ball to seat on Gun#3 and shoot pert interval X9770-9800'. pooh. all shots fired. well freeze protected with 43 bbls of 60/40 ameth. ** job complete**. FLUIDS PUMPED BBLS 290 1 %KCL XS 98 60/40 METH 388 Total 1 Ktt = „ 4" I:IVV WELLHEAD = McEVOY ACTUATOR = AXELSON KB. ELEV = 66.7' BF. ELEV = 38' KOP = 6700' Max Angle = 94 aC1 9515' Datum MD = 9041' Datum TV D = 8800' SS ~ F-28A 13-3/8" CSG, 72#, L-80, ID = 12.347" I-) 2675` Minimum ID = 2.380" @ 9678' 3-3/16" X 2-7/8" XC? SAFEt'Y S: 4-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 7 2978 2978 1 OTIS DOME RM 16 06/01/04 6 4774 4774 0 OTIS SO RM 20 06/01/04 5 5903 5903 1 OTIS DMY RA 0 4 6639 6638 6 OTIS DMY RA 0 3 7180 7161 17 OTIS DMY RA 0 2 7758 7698 24 OTIS DMY RA 0 1 8140 8045 25 OTIS DMY RA 0 OTIS XA SLIDING SLV, ID = 3.813" 826 -~TM! TBG SEAL ASSY i $283` 9-518" TM! HHBP PKR, ID = 4.750" 8288` MILL OUT EXTENSION, ID = 6.004" 8321 ` 7" BROWN SHORTY HYD. LNR HNGR 8325` 4-1/2" OTIS X NIP, ID = 3.813" 4-112" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 8390` 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" 8401' 9-5/8" CSG, 47#, L-80, ID = 8.681" 8591' TOP OF WHIPSTOCK 9069` 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 9073` PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 95° @ 9770' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9770 - 9800 O 03/21/10 2" 6 9812 - 9842 O 03/21/10 2" 6 9894 - 9924 O 03121110 2" 6 10080 - 10300 C 05/22/04 2" 6 10350 - 10520 C 05/22/04 2" 6 10640 - 10770 C 05/22/04 $~--~3.7" BKR DEPLOYMENT SLV, ID = 3.0" 8357` 4-1/2" OTIS XN NIP, MILLED ID = 3.80" (BEHIND CT LNR) 83$9' 3-1 /2" HES X NIP, ID = 2.813" 8390' 4-112" WLEG~(BEHIND CT LNR) $401' 3-1/2" X 3-3/16" XO, ID = 2.786" 8845' ESTIMATED CEMENT TOP TOPOF WINDOW {F-28A): 9073' 9678' 3-3/16" X 2-7/8" XO, ID = 2.380" \ ~ 10062' 2-7i8" CIBP (03!21110) 10782' H PBTD 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" (-{ 967$` 2-7/8" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" ~ 10$19` DATE REV BY COMMENTS DATE REV BY COMMENTS 10!12/86 ORIGINAL COMPLETION 03/22/10 SV GLV TVDCORRECTIONS 05!22/04 KAK CTD SIDETRACK (F-28A) 06(01!04 RMH/KA GLV C/O 12/08(09 ?/ PJC SET PX PLUG (11118/09} 03!02!10 SEW/RPC PX PLUG PULLED (02/14(10) 03!22/10 ACB/SV SET CIBP/ADPERF (03121!10) PRUDHOE BAY UNIT WELL: F-28A PERMTf No: 2040690 API No: 50-029-21649-01 SEC 2, T11 N, R13E, 2359' FSL & 2194' FEL BP Exploration {Alaska) STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMISS REPORT OF SUNDRY WELL OPERATIONS R~C~l~ED FHB 4 4 "2Q10 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ ~ ISS Pertormed: Alter Casing ^ Pull Tubing^ Perforate New Pool ^ Waiver^ Time Extension ^ Anchet~P 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 ^ 204-0690 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. PI Number: Anchorage, AK 99519-6612 50-029-21649-01-00 8. Property Designation (Lease Tlumber) : 9. Well Name and Number: \\ ADLO-028280 '~ PBU F-28A 10. Field/Pool(s): POOL PRUDHOE BAY FIELD / PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured ~ 10819 feet Plugs (measured) 8296 feet true vertical 9049.27 feet Junk (measured) None feet Effective Depth measured 10782 feet Packer (measured) 8208 true vertical 9051.34 feet (true vertical) 8107 Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20" Surface - 110 Surface - 110 Surface 2675 13-3/8" 72# L-80 Surface - 2675 Surface - 2675 4930 2670 Intermediate 8593 9-5/8" 47# L-80 Surface - 8593 Surface - 8457 6870 4760 Liner 754 7" 26# L-80 8321 - 9075 8209 - 8898 7240 5410 Liner 1277 3-3/16" 6.2# L-80 8401 - 9678 8282 - 9058 Liner 1141 2-7/8" 6.4# L-80 9678 - 10819 9058 - 9049 10750 11160 Pertoration depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ - Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# L-80 SURFACE - 8390 SURFACE - 8272 Packers and SSSV (type, measured and true vertical depth) 9-5/8" TIWHHBP PKR 8208 8107 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~{~ ((~~ pp'~~ 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: 476 28747 27 1124 Subsequent to operation: 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development 0 Service ^ 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. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 2/3/2010 Form 10-404 R ised 7/2009 ~ ~~ ,Z. 5/. ~ p Submit Original Only .~ ~g'~/D F-28A 204-069 oror nrrer~u~urt~T • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base F-28A 5/21/04 PER 10,080. 10,300. 9,050.93 9,051.7 F-28A 5/21/04 PER 10,350. 10,520. 9,053.35 9,052.49 F-28A 5/21/04 PER 10,640. 10,770. 9,051.8 9,051.85 F-28A 11/18109 BPS 8,296. 10,080. 8,186.77 9,050.93 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 • • • F-28A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 1/13/2010T/I/0= SSV/20/80. Temp= SI. Remove composite grating & clean SH, bleed IA & OA to 0 psi (Furmanite prep). No AL. Heater installed in cellar. Removed floor kit, stacked floor kit behind wellhouse. Cleaned SH. Cellar is 3' 8" deep. j IA & OA FL's near surface. Bled IAP & OAP to 0 psi. SI, monitored for 30 mins. IAP & OAP unchanged @ 0 psi. ***See log for details*** FWHPs= I SSV/0/0. SV, WV, SSV= C. MV= O. IA, OA= OTG. NOVP. ~ 4/2010 T/I/0= SSVNAC/25 Temp SI. Assist w/ sandblasting, Assist w/ Furmanite wrap (Furmanite prep). No AL. CCI sandblasted SH. Furmanite applied E- Glass layer of composite wrap. Composite rap incomplete. Maintaine open '_ _~ bleed on OA until relieved by night crew. **"See log for details*** FWHPs= SSVNAC/0. Night crew has control of wellhead. i 1/14/2010 T/I/O=SSVNac/0. Temp=S1. Install N2 cap on OA. No AL. OA FL @ surface. ,Installed 25 psi N2 cap on OA. Installed 20" containment. Job complete. Final WHPs=SSV/0/25. ;SV, WV, SSV=Closed. MV=Open. IA & OA=OTG. NOVP. 1/15/2010~T/I/0= SSVNAC/0. Temp= SI. Assist Furmanite w/ wrap (Furmanite prep). No AL. Assisted Furmanite w/ wrapping SH, maintained open bleed on OA until shift change. Furmanite Techs applied 1st set of carbon fiber layers to the composite wrap._*'`*See log for details*** Job incomplete. FWHPs= 'SSVNAC/0. Night crew has control of wellhead. 1/15/2010~T/I/O=SSVNac/O. Temp=S1. Maintain open bleed on OA (Furmanite wrap) No AL. Maintained continuous bleed on OA for 12 hours, no fluid returns. Job in progress. Final WHPs=SSVNac/0. _~ DHD day crew in control of well 1/16/20101T/I/O=SSVNac/0. Temp=S1 Maintain open bleed on OA (Furmanite wrap). ' No AL. Maintained continuous bleed on OA for 12 hours, no fluid returns. Job ~in progress. Final WHPs=SSVNac/0. :DHD day crew in control on the well. • C~ 1/16/2010 SSVNAC/0+. Temp ~SI. Maintain open bleed on OA (Furmanite wrap). Nc AL. Added another heater (two total) in WH to maintain temperature for Furmanite wrap. Maintained open bleed on OA until relieved by night crew. Furmanite Techs applied 2nd set of carbon fiber layers to composite wrap. ;.incomplete. Final WHPs=SSVNAC/0+. Night crew has control of well. 1 /17/2010' Job TIO=ssv/vac/0+. Temp=S1. Maintain open bleed on OA (Furmanite wrap). No AL. Maintained continuous bleed on OA for 12 hours, no fluid returned. Job in progress. Final WHPs=SSVNac/0+ DHD day crew in control of well. 1/17/2010 T/I/0= SSVNac/0+. Temp= SI. Maintain open bleed on OA (Furmanite wrap). No AL. Furmanite applied final layers of composite wrap. Composite Wrap Ecompleted @ -9:30 am. Begin curing period. Maintained open bleed on OA 3until relieved by night crew. Final WHPs= SSVNac/0+. ""Job in progress** ;Night crew has control of well on departure. .~ ~__.r,_.____ ~ . , _ . __ _.._ 1/18/2010 TIO=ssv/vac/0+. Temp=S1. Maintain open bleed on OA (Furmanite wrap). No AL. Maintained continuous bleed on OA for 12 hours, no fluid returned. Job in progress. Final WHPs=SSVNac/0+ i DHD day crew in control of well. 1/18/20101T/I/O =SSVNac/0+. Temp SI. Open bleed OA (Furmanite). CO w/ nights. '[Maintained open bleed on OA. FWHPs =SSVNac/0+. [SV, WV, SSV = C. MV = O. IA = OTG. • 1/19/2010 T1O=SSVNAC/0+. Temp=S1. Maintain open bleed on OA (Furmanite wrap). No AL. SI bleed @ 09:30. OAP @ 5 psi @ 13:30. Continue fo 12 hour monitor. Changed out with night shift. Final WHP's= SSVNAC/8.5. ""'Job in progress*" DHD has control of valves. 1/19/2010TI0=ssv/vac/0+. Temp=S1. Maintain open bleed on OA (Post Furmanite wrap). No AL. Maintained continuous bleed on OA for 12 hours, no fluid returned. Job in progress. Final WHP's=SSVNac/0+ .DHD day crew in control of well. i 1/20/2010`TIO=ssv/vac/9. Temp=S1. Maintain open bleed on OA (Post Furmanite wrap). No AL. Change out with day crew, OA SI @ needle valve monitor OA BUR. =Open OA and maintained continuous bleed for 9.5 hours, no fluid returned. SI bleed @ 0600, start OA BUR, (see log). Job in progress. Final W HP's=SSVNac/0+ DHD day crew in control of well. 1 /20/2010 ~~n~~~~ ~ s ~, T/I/O=SSVNac/2.5. Temp=S1. Maintain open bleed on OA (Furmanite wrap). No AL. OA bleed SI @ 0600. Monitor BUR (see log). Turned over to night shift. .~~ ~~..m__._ .. _ _~___ ~_ ~ ___ _.._.__-- 1/21/2010~T/I/0= SSVNAC/6. Temp= SI. Maintain open bleed on OA (Furmanite wrap). 3BIed OAP from 6 psi to 0+ psi in 10 min. SI bleed as per WIE. Monitor for 7 ?hrs. OAP increased to 7 psi. Bled OAP from 7 psi to 0+ psi in 5 min @ 3:30 yam. Monitored for 30 min. OAP increased 3 psi. Final WHPs= SSVNAC/3. SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. 1 /22/2010 ~J 1 /22/2010 • T/I/0= SSVNAC/9. Temp= SI. WHPs, bleed OA if needed (eval Furmanite wrap) One of the heaters not working upon arrival. Called for new to be delivered. Temp in wellhouse is 40 degrees. Bled OAP from 9 psi to 0 psi in 20 min. Monitored for 30 min. OAP increased 1 psi. Final WHPs= SSVNAC/1. ***New heater installed on well.*** SV, WV, SSV= Closed. MV= Open. IA, OA= OTG. NOVP. T/I/0= SSVNAC/8.m Temp mSl. WHP's (Eval Furmanite wrap). (12:30 PM) .Bled OAP to bleed trailer from 8 psi to 0 psi in 5 minutes (all gas). Held open ;bleed for 30 minutes. SI, 30 minute monitor. OAP increased 1 psi. Final ,WHP's= SSVNAC/1. **Job complete** ESV,WV,SSV=C. MV=O. IA,OA=OTG. NOVP. 1/23/2010!T/I/O -SSVNAC/11. Temp = SI. WHPs (eval Furmanite~wrap). Bled OAP @ E0740 from 11 psi to 0 psi in 6 minutes (all gas). Final WHPs SSVNAC/0. **Job complete"" jSV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 1/24/2010T/I/O =SSVNAC/13. Temp = SI. WHPs (Eval Furmanite wrap) call in OAP to WIE & bleed to 0 psi in needed. No AL. OA FL near surface. Furmanite wrap looks good, no signs of leaks or saturation. Bled OAP from 13 psi to 0 psi in 8 mins. Monitored for 30 mins. OAP increased to 2 psi. Final WHPs = SSVNAC/2. *Job complete* SV, WV, SSV =Closed. MV =Open. IA & OA = OTG. NOVP. TREE = 4" CNV WELLHEAD= McEVOY ACTUATOR = AXELSON KB. ELEV = 66.7' BF. ELEV = 38' KOP = 6700' Max Angle = 94 @ 9515' Datum MD = 9041' Datum TV D = 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" ~ F-28A Q Minimum ID = 2.380" @ 9678' 3-3116" X 2-7i8" XO 2085' 1--14-1/2" OTIS SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 7 2978 2911 1 OTIS DOME RM 16 0&/01104 6 4774 4708 0 OTIS SO RM 20 06!01)04 5 5903 5836 1 OTIS DMY RA 0 4 6639 6572 6 OTIS DMY RA 0 3 7180 7094 17 OTIS DMY RA 0 2 7758 7631 24 OTIS DMY RA 0 1 8140 7978 25 OTIS DMY RA 0 OTIS XA SLIDING SLV, ID = 3.813" PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: 86 @ 10080' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10080 - 10300 O 05/22/04 2" 6 10350 - 10520 O 05/22/04 2" 6 1064p - 10770 O 05/22/04 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ( $390` 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID=2.992" $401` 9-5i8" CSG, 47#, L-80, ID = 8.681" $591' TOP OF WHIPSTOCK 9069` 7" LNR, 28#, L-80, .0383 bpf, ID = 6.276" ~--) 9430` 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.80" $26$` --jTIW TBG SEAL ASSY $2$3' 9-5/8" TNV HHBP PKR, ID = 4.750" $2$8` MILL OUT EXTENSION, ID = 6.004" $321' 7" BROWN SHORTY HYp. LNR HNGR 8325' 4-1/2" OTIS X NIP, ID = 3.813" $~$' 4-112" PX PLUG (11!18709), $ o`ff' ~ ~ $349' 3.7" BKR DEPLOYMENT SLV, ID = 3.0" 8357 4-1/2" OTIS XN NIP, M ILLED ID - 3.80" (BEHIND CT LNR) 8369` 3-1/2" HES X NIP, ID = 2.813" $390' 4-112" WLEG (BEHIND CT LNR) $409' 3-112" X 3-3/16" XO, ID = 2.786" $$45' ESTIMATED CEMENT TOP TOP OF WINDOW 9073' 967$` 3-3/16" X 2-718" XO, ID = 2.380" I 967$' I 0782` i'~ PBTD 718" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" ~ 10$19' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/12/86 ORIGINAL COMPLETION 05/221t?4 KAK CTD SIDETRACK (F-28A) 06!01/04 RMFVKA GLV C!O 12/08/09 ?/ PJC SET PX PLUG (11!18/09) PRUDHOE BAY UNIT WELL: F-28A PERMf( No: 2040690 API No: 50-029-21649-01 SEC 2, T11 N, R13E, 2359' FSL & 2194' FEL BP Exploration (Alaska) ~ • -r9: ~- - MICROFILMED 03101 !2008 DO NOT PLACE ~~ . ter. ANY NEW MATERIAL UNDER THIS PAGE F: ~L.aserFiche\CvrPgs_Inserts~Microfilm_Marker. doc ;1 J.. ;) V'N\. Â ~ ~ DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040690 Well Name/No. PRUDHOE BAY UNIT F-28A Operator BP EXPLORATION (ALASKA) INC MD 10818" Completion Status 1-01L TVD 9049 r Completion Date 5/22/2004 , Current Status 1-01L UIC N lfl--¿ 17 ~ ~(. API No. 50-029-21649-01-00 REQUIRED INFORMATION Mud Log No Samples No Directional~ DATA INFORMATION Types Electric or Other Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint Received Comments 2/22/2006 ROP DGR EWR plus Graphics 6/9/2004 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 4/29/2004. Electr Digital Dataset Med/Frmt Number Name Lis 13643 Induction/Resistivity ~ASC Log/ Data Type Run No Interval OH / Start Stop CH 9070 10819 Open Log Log Scale Media Directional Survey ~ Directional Survey Gamma Ray ~ D Tap 12686 Gamma Ray ~ LIS Verification ß') C Pds 12860 Neutron Log Pds 12860 Neutron 9000 o 8600 10819 6/9/2004 o 1 0769 Open 9/28/2004 8600 10769 Open 9/28/2004 8157 10708 11/20/2004 Blu 8157 10708 11/20/2004 . GR, EWR4, ROP, DSN 12686 GR, EWR4, ROP, DSN 12686 COMPENSATED NEUTRON/MEMORY GRlCCUCNL COMPENSATED NEUTRON/MEMORY GRlCCLlCNL . Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received DATA SUBMITTAL COMPLIANCE REPORT 5/25/2006 Permit to Drill 2040690 API No. 50-029-21649-01-00 Well Name/No. PRUDHOE BAY UNIT F-28A Operator BP EXPLORATION (ALASKA) INC MD 10818 Completion Status 1-01L Current Status 1-01L UIC N TVD 9049 Completion Date 5/22/2004 ADDITIONAL INFORMATION Well Cored? v0 Chips Received? 'y ¡:¡;¡- Daily History Received? ~N &N Formation Tops Analysis Received? ~ Comments: Fk Date: ~ Ö j___~~ ~-- Compliance Reviewed By: . . . . WELL LOG TRANSMITTAL c!) ()4 - 0 (Pq To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 191P 4-:3 RE: MWD Formation Evaluation Logs F-28A, 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 F-28A: LAS Data & Digital Log Images: 50-029-21649-01 1 CD Rom ~ If! (f(f! Ob 11/16/04 Schlumberger NO. 3256 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . D r Color P Well Job # Log escnptlon Date Blue me rints CD ~O " E-39A 10715430 MEMORY IPROF & WARMBACK 09/13/04 1 Rt:ftf..o2 ¡,. D.S. 15-25A 10715428 MEMORY PPROF & IPROF 09/11/04 1 ¡,5"q¡, C-25A 10928596 MEMORY LDL 09/27/04 1 C-25A 10928598 MEMORY LOlli PROF 10/04/08 1 7 J ..AI L2-14B 10670029 PRODUCTION PROFILE 08/20/04 1 ~-. F-11 B 10928600 MCNL 10/20/04 1 1 ~ð'f-" ~~ L2-07 A 10861911 MCNL 05/31/04 1 1 -E-07 A 10715409 MCNL 06/07/04 1 1 F-28A 10670015 MCNL OS/22/04 1 1 ~~ L3-05 10724368 RST-SIGMA 04/02/04 1 1 L3-05 10662981 RST-SIGMA 01/08/04 1 1 ~'4 L3-05 10866588 RST-SIGMA 09/03/04 1 1 " t L3-05 10672320 RST-SIGMA 09/28/03 1 1 ¡?t. ~ ISif L3-02 10560313 RST -SIGMA 10/16/03 1 1 (e{)' < OWDW-NW 10563037 RST-SIGMA & BORAX 03/29/03 1 1 OWDW-NW 10672361 RST -BORAX 03/28/04 1 1 11 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, 99503-2838 ATTN: Bet Date Delivered: 1(-;2 t( - Ot-( ,-..,/ . · ~;1 ~~;~I~~D WELL LOG TRANSMITTAL ,',ìi:'íska Oil & Gas Cons. Commission Ar~ To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Robin Deason 333 West 7tlt Avenue, Suite 100 Anchorage, Alaska 99501 September 20,2004 RE: MWD Fonnation Evaluation Logs F-28A, AK-MW-3079250 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21649-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Speny-Sun 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 DmeØ · STATE OF ALASKA . ALASKA~L AND GAS CONSERVATION COMMmSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ::,,,::,U ", 1a. Well Status: IBI Oil o Gas o Plugged o Abandoned o Suspended o WAG 1 b. wen'crass: . :, ,: ::.F 20AAC 25.105 20AAC 25.110 IBI Development tJËi<þ!oratory DGINJ DWINJ o WDSPL No. of Completions One Other o Stratigraphic o Service 2. Operator Name: 5. Date Comp., Susp., or Aband. 12. Permit to Drill Number BP Exploration (Alaska) Inc. 5/22/2004 204-069 3. Address: 6. Date Spudded 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 5/17/2004 50- 029-21649-01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached 14. Well Name and Number: Surface: 5/20/2004 PBU F-28A 2359' NSL, 2193'WEL, SEC. 02, T11N, R13E, UM 8. KB Elevation (ft): 15. Field / Pool(s): Top of Productive Horizon: 2896' NSL, 1293' WEL, SEC. 02, T11N, R13E, UM 66.70' Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 9. Plug Back Depth (MD+ TVD) 3671' NSL, 554' WEL, SEC. 02, T11 N, R13E, UM 10782 + 9051 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: Surface: x- 652650 y- 5973893 Zone- ASP4 10819 + 9049 Ft ADL 028280 TPI: x- 653538 y- 5974448 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 654260 y- 5975239 Zone- ASP4 (Nipple) 2085' MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost IBI Yes DNo N/A MSL 1900' (Approx.) 21. Logs Run: SGRC Combined GR & EWR, MGR / CCL / CNL 22. CASING, LINER AND CEMENTING RECORD ii R~fi~ " ,,; ii::':":: ~I:'fTIIIIGDEfO"I'HMP ~ETTINGWI:'r 'n IV", ~?igi 'i ~~U~3:: iYV'T,Pr;R 'Fr.:: GAADÊ ::~":",::: TOP ~TTOM ToP, BOTTOM I.: : 20" Conductor Surface 110' Surface 110' 8 cu yds Concrete 13-3/8" 72# L-80 Surface 2675' Surface 2675' 17-1/2" 3274 cu ft AS 1/1, 465 cu ft AS 1/ 9-5/8" 47# L-80 Surface 8593' Surface 8457' 12-1/4" 575 cu ft Class 'G' 7" 26# L-80 8321' 9075' 8209' 8898' 8-1/2" 374 cu ft Class 'G' 3-112" x 3-3116" x 2-718" 9.2# 1 6.2# 1 6.5# L-80 8349' 10819' 8235' 9049' 4-114" x 3-314" 146 cu ft Class 'G' 23. Perforations open to Production (MD + TVD of To,e and 124.::: :: iTiô""(,,,, iii 'I::;: ii ,i:, Bottom Interval, Size and Number; if none, state' none"): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 spf 4-1/2", 12.6#, L-80 8390' 8283' MD TVD MD TVD 10080' - 10300' 9051' - 9052' 125. ACII:lJ;'Ø"t''''løc",,'7~'7'~' ~'!'~ê 10350' - 10520' 9053' - 9052' 10640' - 10770' 9052' - 9052' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): June 15, 2004 Flowing Date of Test Hours Tested PRODUCTION FOR Oll-BBl GAs-McF W A TER-BBl CHOKE SIZE GAS-Oil RATIO 6/26/2004 4 TEST PERIOD ... 162 357 22 93.3° 2,206 Flow Tubing Casing Pressure CALCULATED ~ Oll-BBl GAs-McF WATER-BBl Oil GRAVITY-API (CORR) Press. 186 500 24-HoUR RATE 971 2,143 132 25.6 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None vvm:"·;:':'XJ OR I GI NAL"SfL jUl () t) ~~ ./ ~Jf.,ÉJ) Form 10-407 Revised 12/200~ CONTINUED ON REVERSE SIDE - c,F(, 28. GEOLOGIC MARKERS 29. FORMATION 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". 22N 9117' 8935' None 21N 9174' 8980' Zone 18 /14N 9296' 9042' 14P 9302' 9043' 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 DCa (3D /0 PBU F-28A Well Number Prepared By Name/Number: Drilling Engineer: Terrie Hubb/e, 564-4628 Mary Endacott, 564-4388 204-069 Permit No. / 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 10-407 Revised 12/2003 Submit Original Only Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-28 F-28 REENTER+cOMPLETE NORDIC CALISTA NORDIC 1 Start: 5/12/2004 Rig Release: 5/22/2004 Rig Number: N1 Spud Date: 9/19/1986 End: 5/22/2004 5/15/2004 22:00 - 23: 15 1.25 MOB P PRE Rig released from 02-24A @ 22:00Hrs on 5/15/2004. Prep to move rig off well. Load out trailers. RID Gen-3. 23:15 - 23:30 0.25 MOB P PRE PJSM for moving rig off well. 23:30 - 00:00 0.50 MOB P PRE Jack-up & pull rig off well. P/U mats & clean up location. 5/16/2004 00:00 - 01 :00 1.00 MOB P PRE Move rig from 02-24A to pad entrance. Meanwhile conduct post operations pad inspection. 01 :00 - 01 :30 0.50 MOB P PRE Held pre-move safety meeting with Tool Services, Security & all personnel. 01 :30 - 06:00 4.50 MOB P PRE Moving rig from 02-24A to F-28. 06:00 - 13:30 7.50 MOB P PRE Moving rig from 02-24A to F-28A Rig arrived on location at 1330 hrs 13:30 - 14:00 0.50 MOB P PRE PJSM on moving over well 14:00 - 16:00 2.00 MOB P PRE Move rig over well and set down. RIG ACCEPTED AT 14:00 HRS 5-16-2004 16:00 - 18:30 2.50 P PRE NU BOP's Notified AOGCC 2230 hrs 10-14-2004 left message, no call back. Left messages in AOGCC Ancorage office 5-15-04, no callback 1-907-793-1250 & 1231 18:30 - 19:00 0.50 BOPSU P PRE PJSM with night crew for testing BOPE. 19:00 - 19:45 0.75 BOPSU P PRE RU to test BOPE. Rethread test joint. 19:45 - 23:45 4.00 BOPSU P PRE Test BOPE as per BP policy and AOGCC regulations. Talked with AOGCC rep John Crisp at beginning of test, witness of test waived. 23:45 - 00:00 0.25 BOPSU P PRE RD test equipment. 5/17/2004 00:00 - 00:30 0.50 STWHIP P WEXIT MU window milling BHA. 00:30-01:15 0.75 STWHIP N WEXIT Isolate SCR. Work on mud pump traction motor. 01 :15 - 02:15 1.00 STWHIP P WEXIT MU dart catcher. Load and lanch dart. Pump dart and fill CT with 2% KCI w/1 ppb biozan. Dart hit at 57.7 bbls. 02:15 - 02:45 0.50 STWHIP P WEXIT Install Baker 2 318" Reg CTC. Pull test to 30,000 Ibs and PT to 3,500 psi. 02:45 - 04:30 1.75 STWHIP P WEXIT RIH taking MeOH returns to outside tank. 04:30 - 06:00 1.50 STWHIP P WEXIT PU=34K. Tag whipstock at 9,076.2' dry. PU and start pumping. RIH slowly. Tag wI motor work. PU and overpulled to 38K. Correct depth to pinch point, 9,074.6'. Start milling. 06:00 - 11 :39 5.65 STWHIP P WEXIT Milling window as per SOP's, Qp 2.45/2.56 bpm, 1450/2600 psi WOB =1500 to 3000lb Milled from 9070 fto 9082 ft Stalled, PU and restarted 11 :39 - 12:33 0.90 STWHIP P WEXIT Milling, Op 2.50/2.60 bpm, 1450/1970 psi WOB = 1850lb 9082.6 ft EOW 12:33 - 12:53 0.33 STWHIP P WEXIT Drilling rathole from 9083 ft to 9085 ft Op 2.47/2.57 bpm, 1450/1650 psi WOB = 2520lb IA=9 psi; OA = 55 psi Gas behind casing (once we cut through, in the microannulus), set alarms off. SD pump, PUH and checked flow, No pit gain, No flow. 12:53 - 12:57 0.07 STWHIP P WEXIT Start drilling rathole again, Op 2.47/2.57 bpm, 1450/1650 psi WOB = 2520lb 12:57 -13:41 0.73 STWHIP P WEXIT Drilling rathole, Op 2.50/2.57 bpm, 1450/1798 psi WOB = 4250lb Started cleaning pits at 1215 hrs 13:41 -14:16 0.58 STWHIP P WEXIT Ream window and starting Flp-Pro down the CT 0=2.52 / 2.62 bpm at 2190 psi IA = 10 psi & OA = 54 psi 14:16-14:22 0.10 STWHIP P WEXIT Reaming hole with Flo-Pro around motor Printed: 5/24/2004 10:24:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-28 F-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/12/2004 Rig Release: 5/22/2004 Rig Number: N1 Spud Date: 9/19/1986 End: 5/22/2004 5/17/2004 14:16-14:22 0.10 STWHIP P WEXIT Dry tagged at 9093.5 ft back ream window. Paint flag 8950 ft EOP (yellow) 14:22 - 15:49 1.45 STWHIP P WEXIT POOH chasing FloPro to surface 15:49-16:15 0.43 STWHIP P WEXIT OOH, LD Milling BHA, check mill condition. Window mill = 3.79" and String Mill = 3.80" Cored (well worn) point on concave of mill. Good looking mill 16:15 - 16:30 0.25 DRILL P PROD1 Pre Spud meeting, on Project 16:30 - 18:40 2.17 DRILL P PROD1 Installed CTC and pull test 40k and PT 3800 psi. PU BHI Directional BHA. Mark orienter. MU injector. Orient two clicks and test MWD. Break off injector and check orienter, OK. Note: well is < 5 deg. inc. until 6,600'. 18:40 - 20:05 1.42 DRILL P PROD1 RIH. 20:05-21:15 1.17 DRILL P PROD1 Tie in to Sag River marker. -0.5' correction. Orient to 35R. RIH and tag bottom. Went through window clean. 21:15 - 21:25 0.17 DRILL P PROD1 Orient to 31 R. 21 :25 - 00:00 2.58 DRILL P PROD1 Drill at 2.3/2.3 bpm 3,030/3,350 psi to 9137' MD. 5/18/2004 00:00 - 05:15 5.25 DRILL P PROD1 Drill ahead at 2.5 1 2.5 bpm; 3,100/3,500 psi at 9,284' MD. Currently drilling at ROP between 40 and 80 fpm. Last survey at 9,266' MD, 66 deg INC, and 105 AZM. 05: 15 - 06:29 1.23 DRILL P PROD1 Continue driling ahead to end of build with drilling assembly #2. Currently on plan. 06:29 - 06:32 0.05 DRILL P PROD1 Survey to confirm BHL 06:32 - 08:00 1.47 DRILL P PROD1 POOH to make Motor bend change 08:00 - 08:15 0.25 DRILL P PROD1 OOH, PJSM on BHA Handling 08:15 - 09:00 0.75 DRILL P PROD1 LD BHA 09:00 - 10:51 1.85 DRILL P PROD1 Cut 1 ,102 ft CT off for Coil Management 10:51 - 12:00 1.15 DRILL P PROD1 RD CT cutter and Install CTC, PT to 3800 psi and pull test 40k 12:00 - 14:00 2.00 DRILL P PROD1 MU BHA # 3 Lateral Section 14:00 - 16:00 2.00 DRILL P PROD1 RIH. Tag bottom at 9,372' and correct depth to 9,370'. 16:00 - 16:50 0.83 DRILL P PROD1 MAD pass with RES tool. Tie in to RA marker, -1' correction. 16:50 - 17:00 0.17 DRILL P PROD1 Orient to 60L. 17:00 - 21 :20 4.33 DRILL P PROD1 Drill from 9,370' MD to 9,550' MD. - Orient as required by DO and Geologist. - Hit shale at 9,350' MD. A shale in similar position was identified on the F-11 log. o HOT has been penetrated at 9,650' MD. 21 :20021 :50 0.50 DRILL P PROD1 Short trip to window. - Hole in good condition. - No overpulllstackup. 21 :50 - 00:00 2.17 DRILL P PROD1 Orient tool face as required. Drill from 9,550' MD to 9,667' MD. 5/19/2004 00:00 - 00:45 0.75 DRILL P PROD1 Drill from 9,667' MD to 9,700' MD. 00:45 - 01 :45 1.00 DRILL P PROD1 Short trip from 9,700' MD to whipstock. - Hole in good condition. - No overpull/stackup. 01 :45 - 05:00 3.25 DRILL P PROD1 Drill from 9,700' MD to 9,850' MD - Orient as required. - Displace mud system to clean Flo-Pro while drilling ahead. 05:00 - 06:00 1.00 DRILL P PROD1 Short trip from 9,850' MD to window. - Tie-in at RA tag -- Add 3'. - Continue with mud displacement. - Hole in good condition. Printed: 5/24/2004 10:24:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-28 F-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/12/2004 Rig Release: 5/22/2004 Rig Number: N1 Spud Date: 9/19/1986 End: 5/22/2004 5/19/2004 06:00 - 08:30 2.50 DRILL P PROD1 Drill to 10,000'. Continue taking on mud. IA=18,OA=62. 08:30 - 09:15 0.75 DRILL P PROD1 Wiper trip to window. Hole in good condition. 09:15 - 09:30 0.25 DRILL P PROD1 Drill to 10,023' at 85L. 09:30 - 10:00 0.50 DRILL P PROD1 Orient to 95L. Only getting 10 degree clicks from orienter. 10:00 - 11 :30 1.50 DRILL P PROD1 Drill at 95L, 2.7/2.7 bpm, 2,950/3,300 psi. Drill to 10,150'. Increase Klagard content from 10 ppb to 12 ppb. 11 :30 - 12:30 1.00 DRILL P PROD1 Wiper trip to window. RIH. Slight bobble in shale at 9,350'. 12:30 - 13:00 0.50 DRILL P PROD1 Orient to 120L getting 10 degree clicks. 13:00 - 14:50 1.83 DRILL P PROD1 Drill at 2.8/2.8 bpm 3,050/ 3,380 psi. TF walking up. Orient all the way around. Continue drilling at 140L to 120L. Average ROP 150+ fph in good sand. Drill to 10,315'. 14:50-16:15 1.42 DRILL P PROD1 Wiper trip to window. Hole in good condition. Tie in to RA marker logging up, +3.5' correction. 16:15-18:00 1.75 DRILL P PROD1 Tag bottom. Orient to 60R, 5 clicks. Drill to 10,475' at 2.8/2.8 gpm, 3,050/3,400 psi TF 60R - 11 OR. 18:00 -19:10 1.17 DRILL P PROD1 Wiper trip to window. - Hole in good condition. 19:10 -19:30 0.33 DRILL P PROD1 Orient tool face to 80R. 19:30 - 22:30 3.00 DRILL P PROD1 Drill ahead from 10,475' MD to 10,558' MD - Slowly making hole. Motor continuing to stall and seeing erratic tool face. - Seeing occasional evidence of sticking (65k PU @ -10,500'). - Pressure decreased from 2700 psi at 2.5 bpm to 2600 psi at 2.5 bpm. Pressure should be reading approximately 3200 psi. Suspect wash out in BHA. 22:30 - 00:00 1.50 DRILL N DFAL PROD1 POOH to check BHA. - Slight overpull (6k) at 10,070' MD, 14N shale. - No issues going through window. 5/20/2004 00:00 - 00:40 0.67 DRILL N DFAL PROD1 Continue to POOH to check BHA. 00:40 - 04:45 4.08 DRILL N DFAL PROD1 LD BHA. - Hunt for leak while POOH. - No leak in BHA. - Found leak at coil connector (failed O-ring). Swap tools. - Change out motor, orienter (modified with spring) , MWD probe, equalizer sub, and check valve on MHA. - Bit in good condition (1-1-WT), will re-run. - Change coil connector (pressure test to 3500 psi, pull test to 30k Ibs). MU BHA #4. - Shallow hole test MWD. 04:45 - 06:45 2.00 DRILL N DFAL PROD1 RIH with BHA #4, lateral drilling BHA. - Tie in to RA - Adjust depth -3'. 06:45 - 07:00 0.25 DRILL P PROD1 Tag at 10,566'. Drill to 10,585' at 2.7/2.7 3,050 psi off bottom. ROP 300+ FPH. 200 psi differential pressure. No apparent bottom. 07:00 - 09:20 2.33 DRILL P PROD1 Orient and drill to 10,710'. 09:20 - 11: 1 0 1.83 DRILL P PROD1 Wiper trip to window. RIH. Set down at 10,030'. Work through tight hole to 10,050'. Back ream from 10,060' to 10,020' until running past interval without problem. 11 :10 - 13:00 1.83 DRILL P PROD1 Drill at 2.7/2.7 bpm 3,100/3,400 psi. PU = 34K, SO=17K at 10,820'. TD well at 10,820'. Printed: 5/24/2004 10:24:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-28 F-28 REENTER+cOMPLETE NORDIC CALISTA NORDIC 1 Start: 5/12/2004 Rig Release: 5/22/2004 Rig Number: N1 Spud Date: 9/19/1986 End: 5/22/2004 5/20/2004 13:00 - 14:45 1.75 DRILL P PROD1 Wiper trip to window. Tie in to RA marker logging up, -2' correction. RIH and tag corrected TO at 10,819'. Hole in good condition. Slight bobble at 10,030'. 14:45 - 17:00 2.25 DRILL P PROD1 POOH and lay in 41 bbls liner running pill w/12 ppb KlaGard and 4% lubtex. POOH. 17:00 - 17:15 0.25 DRILL P PROD1 PJSM for LD BHA. 17:15-19:00 1.75 DRILL P PROD1 LD BHA. LD MHA, orienter, motor, and bit. Bit 1-1-WT-A-X-NA-NO-TD. Down load RES tool. 19:00 -19:10 0.17 DRILL P PROD1 OOH with BHA tools. END DRILLING BHA @ 19:00. 19:10 - 19:30 0.33 CASE P COMP Install Baker coil connector. - Perform pull test to 30,000 Ib and pressure test to 3500 psi. - Noticing approximately 1 bph static losses. 19:30 - 20:30 1.00 CASE P COMP Pump dart. - Coil volume at 53.5 bbls. 20:30 - 22:00 1.50 CASE P COMP PJSM. Rig up liner running tools. Run 35 joints of 2-7/8" L-80 STL liner and one 9.75' pup. - Confirm 30 joints left in shed. - 1 joint shoe track. 22:00 - 22:30 0.50 CASE P COMP Fill pipe. Unload shed. Change out liner running tools. 22:30 - 00:00 1.50 CASE P COMP RIH with LSL sub and 3-3/16 L-80 TCllliner. - 17 with tubolators - 24 without turbolators - X nipple + pup - Deployment sleeve + pup 5/21/2004 00:00 - 00:30 0.50 CASE P COMP MU liner to baker coil connector. - String weight 9k Ibs. 00:30 - 01 :30 1.00 CASE P COMP RIH with liner on coil tubing to window. - Total length of liner is 2478.6' MD. - EOP flags at 6510' MD and 8275' MD - Fill pipe while RIH. - Rig down liner running tools. - 0.44 bpm; 1200 psi. 01 :30 - 01 :40 0.17 CASE P COMP Tie in to 6510' MD EOP flag. -4' correction. - PU at 26,500 Ibs - SO at 24,000 Ibs 01 :40 - 02:20 0.67 CASE P COMP Run into openhole with liner to TO. - No issues going through the window. - Running speed at 65 fpm - 0.42 bpm; 1140 psi. - 3k Ib bobble at 10,650' MD. - 10k Ib bobble at 10,810' MD. - Land liner on bottom at 10,816' MD uncorrected. - 41 k Ib pick up weight at TO. 02:20 - 02:45 0.42 CASE P COMP Drop 5/8" ball to release from liner. Confirm release. - Pump down at 2 bpm for 40 bbls. - Reduce rate to 0.5 bpm until ball on seat. - Ball on seat at 41.8 bbls. - Pressure up to 3900 psi to shear ball seat (1100 psi circulating pressure, 2800 psi to shear). - Free at 27,000 Ibs. Printed: 5/24/2004 10:24:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-28 F-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/12/2004 Rig Release: 5/22/2004 Rig Number: N1 Spud Date: 9/19/1986 End: 5/22/2004 5/21/2004 02:45 - 03:45 1.00 CASE P COMP Off load 228 bbls of Flo Pro Mud to MI for reconditioning. 03:45 - 04:50 1.08 CASE N WAIT COMP Wait on Truck for 2% KCI water. 04:50 - 07:00 2.17 CASE P COMP Circulate the well over to 2% KCI water (490 bbls at 110 deg F). 07:00 - 07:15 0.25 CEMT P COMP PJSM for cement job. 07:15 - 07:30 0.25 CEMT P COMP Batch mix 15.8 ppg, Gas block cement. Cement up to weight at 07:30. 07:30 - 08:40 1.17 CEMT P COMP Pump 2 bbls of water. Pressure test cement lines to 4,000 psi. Pump 26 bbls 15.8 ppg gas block cement. Shut down pump and close inner reel valve. Flush lines back to cement truck. Drop CT wiper dart. Launch dart and displace cement with 30 bbls of 2% KCI wI biozan, continue displacing with 2% KC/. CT wiper dart latched liner wiper plug at 54.1 bbls and sheared at 3,300 psi. Continue displacement at 1.4 bpm, 800 psi. Slow pump to 1 bpm with 67 bbls away and bump plug at calculated volume, 70 bbls. Pressure up to 2,100 psi. Bleed off pressure and check floats, OK. CIP at 08:40. Full returns during cement job. Estimated cement top=8,850'. 08:40 - 09:50 1.17 CEMT P COMP Pressure up to 200 psi and unsting from liner. POOH replacing pipe voidage. 09:50 - 11 :30 1.67 CEMT P COMP LD liner running tools. 11 :30 - 13:15 1.75 CLEAN P COMP PJSM for PU RA source and PU CSH. PU mill, motor, MCNUCCUGR w/ flow through carrier. Load RA source. PU 14 joints of CSH. RIH wI 32 stands CSH from derrick. 13:15 - 13:30 0.25 CLEAN P COMP MU injector. 13:30 - 14:30 1.00 CLEAN P COMP RIH wi logging tools on CT to 8,300'. Cement at 600 psi at 14:30. 14:30 - 16:00 1.50 CLEAN P COMP Log down from 8,300' at 30 fpm. Tag uncorrected PBTD at 10,795'. No obstructions RIH. 16:00 - 18:30 2.50 CLEAN N WAIT COMP Wait on perf pil/. 18:30 - 19:15 0.75 EVAL P COMP Start pumping perf pil/. 19:15 - 20:35 1.33 EVAL P COMP POOH laying 30 bbls of Flo Pro perf pill, logging at 60 fpm. - Logged to 8,300' MD. 20:35 - 20:50 0.25 EVAL P COMP POOH and stand back injector. 20:50 - 21 :00 0.17 EVAL P COMP PJSM for racking back CSH drillpipe. - Drop 5/8" ball for circ sub. 21 :00 - 22:15 1.25 EVAL P COMP POOH, racking back 1-1/4" CS Hydril DP. 22:15 - 22:30 0.25 EVAL P COMP PJSM for rigging down SLB CNL too/. 22:30 - 23:00 0.50 EVAL P COMP Lay down CNL and rest of BHA. 23:00 - 23:30 0.50 CASE P COMP Pressure test liner lap to 2000 psi for 30 minutes. - Took 1.4 bbls to pressure up. Lost 50 psi in 30 minutes. NOTES: Loading pipe shed with perf guns (33 each). Obtained good logging data from CNUCCL. - PBTD called at 10,782' CTM - Deployment sub at 8,350' CTM 23:30 - 00:00 0.50 PERF P COMP Prepare floor for perforating. 5/22/2004 00:00 - 00:45 0.75 PERF P COMP Prepare floor for perforating. 00:45 - 02:00 1.25 PERF P COMP PJSM. RIH with perforating guns and firing head. - 33 each 2" 6 spf perforating guns Printed: 5/24/2004 10:24:36 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: F-28 F-28 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 5/12/2004 Rig Release: 5/22/2004 Rig Number: N1 Spud Date: 9/19/1986 End: 5/22/2004 5/22/2004 00:45 - 02:00 1.25 PERF P COMP - Loaded for the following intervals: 10,080' - 10,300' 10,350' - 10,520' 10,640' - 10,770' 02:00 - 03:00 1.00 PERF P COMP RIH with 30 stands of 1-1/4" CS Hydril DP. 03:00 - 03:15 0.25 PERF P COMP Rig up injector. 03: 15 - 04:45 1.50 PERF P COMP RIH with perf guns on CT. -100fpm. - 0.44 bpm in rate /1.0 bpm out rate - Tag TO -- correct depth to 10,782' MD. - PU wt. 34k. - PU to 10,773' MD. 04:45 - 05:15 0.50 PERF P COMP Insert ball into coil reel. Pump to seat. - Pump 10 bbl Flo Pro perf pill before ball. - Pump 20 bbl Flo Pro perf pill after ball. - At 38 bbls away, decrease rate to 1 bpm and 750 psi. - 43.7 bbls away, ball on seat. Start moving pipe at 3 fpm. Pressure up to 3100 psi - initial idications that guns fired. Perforate from: 10,080' - 10,300' 10,350' - 10,520' 10,640' - 10,770' with 2" guns, 6 spf, 2006PJ. - Initial loss of 3 bbls. fluid, steadily healing. - POOH at 10 fpm, increasing to 50 fpm. Replacing bbl per bbl. 05:15 - 06:50 1.58 PERF P COMP POOH. Start filling well across the top holding 100 psi on the choke at 8,300'. At surface. Observe well, no flow. 06:50 - 08:00 1.17 PERF P COMP Stand back CSH. 08:00 - 11 :00 3.00 PERF P COMP PJSM. LD and off load perf guns. All shots fired. 11:00-12:15 1.25 WHSUR P COMP MU nozzle. RIH to 2,000' and start pumping MeOH. Lay in MeOH at 60/40 to freeze protect well. Off load pits. 12:15 - 13:00 0.75 RIGD P POST PJSM. Blow down reel w/ Nitrogen. 13:00 - 15:00 2.00 RIGD P POST ND BOP. NU tree cap and test. Release rig at 15:00 on 5/22/04. Printed: 5/24/2004 10:24:36 AM . . 04-Jun-04 AOGCC Howard Okland 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well F...28A Dear Dear Sir/Madam: Enclosed are two survey hard copies and one disk with the *.PTT and *.PDF files. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 9,000.00' MD 9,069.00' MD 10,819.00' 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 AUn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date 9. ~ ~ ¡.,a ''\ Signed 1~ð~ Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager ;Z ()vf - Ó It 1 Attachment(s) Halliburton Sperry-Sun North Slope Alaska BPXA PBU_WOA F Pad F-28A Job No. AKMW3079250, Surveyed: 20 May, 2004 Survey Report 3 June, 2004 Your Ref: API 500292164901 Surface Coordinates: 5973893.00 N, 652650.00 E (70· 20' 08.3769w N, 148· 45' 41.3382w W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Surface Coordinates relative to Project H Reference: 973893.00 N, 152650.00 E (Grid) Surface Coordinates relative to Structure Reference: 1329.93 N, 1717.56 E (True) Kelly Bushing Elevation: 66. 70ft above Mean Sea Level Kelly Bushing Elevation: 66. 70ft above Project V Reference Kelly Bushing Elevation: 66.70ft above Structure Reference 5p,e........y-5UI! CRLLLLNG seRVices A Halliburton Company DEFINITIVE e e Survey Ref: svy4270 Halliburton Sperry-Sun Survey Report for PBU_WOA F Pad - F-28A Your Ref: API 500292164901 Job No. AKMW3079250, Surveyed: 20 May, 2004 BPXA North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastin9s Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) ("/100ft) 9000.00 24.070 58.800 8762.54 8829.24 524.01 N 718.97 E 5974431.54 N 653358.16 E 867.16 Tie On Point MWD Magnetic 9069.00 24.010 58.720 8825.56 8892.26 538.59 N 743.01 E 5974446.60 N 653381.89 E 0.099 893.93 Window Point 9099.15 27.330 67.900 8852.74 8919.44 544.38 N 754.67 E 5974452.63 N 653393.43 E 17 .153 905.96 9130.84 33.490 77.500 8880.07 8946.77 549.02 N 769.97 E 5974457.58 N 653408.63 E 24.706 919.49 e 9163.70 41.930 87.360 8906.07 8972.77 551.49 N 789.84 E 5974460.46 N 653428.45 E 31.502 934.40 9195.20 50.710 88.880 8927.81 8994.51 552.22 N 812.59 E 5974461.64 N 653451.18 E 28.089 949.87 9226.77 58.620 94.150 8946.06 9012.76 551.48 N 838.29 E 5974461.43 N 653476.90 E 28.503 966.18 9259.14 64.600 102.590 8961.46 9028.16 547.28 N 866.41 E 5974457.80 N 653505.09 E 29.433 981.46 9292.28 72.070 110.850 8973.71 9040.41 538.38 N 895.84 E 5974449.51 N 653534.69 E 32.302 994.04 9322.15 77.780 119.290 8981.49 9048.19 526.15 N 921.91 E 5974437.81 N 653561.01 E 33.301 1001.92 9354.58 83.080 130.440 8986.89 9053.59 507.89 N 948.08 E 5974420.08 N 653587.55 E 37.624 1005.31 9386.50 85.370 127.980 8990.10 9056.80 487.82 N 972.69 E 5974400.52 N 653612.56 E 10.500 1006.30 9416.98 87.840 126.390 8991.91 9058.61 469.43 N 996.93 E 5974382.63 N 653637.16 E 9.632 1008.33 9454.28 90.930 122.870 8992.31 9059.01 448.24 N 1027.61 E 5974362.07 N 653668.27 E 12.556 1012.46 9483.99 92.510 117.400 8991.42 9058.12 433.34 N 1053.28 E 5974347.69 N 653694.24 E 19.155 1018.06 9514.92 93.920 111.240 8989.68 9056.38 420.63 N 1081.41 E 5974335.55 N 653722.62 E 20.400 1026.92 9545.39 92.510 106.130 8987.97 9054.67 410.88 N 1110.21 E 5974326.40 N 653751.62 E 17.371 1038.46 9581.83 87.670 103.130 8987.91 9054.61 401.68 N 1145.46 E 5974317.92 N 653787.05 E 15.625 1054.64 9612.71 88.110 100.660 8989.05 9055.75 395.32 N 1175.65 E 5974312.17 N 653817.36 E 8.119 1069.65 9645.42 87.490 92.910 8990.31 9057.01 391.46 N 1208.08 E 5974308.97 N 653849.87 E 23.751 1088.02 9694.42 89.870 85.690 8991.44 9058.14 392.06 N 1257.03 E 5974310.57 N 653898.79 E 15.510 1120.58 e 9731.13 93.740 79.700 8990.28 9056.98 396.72 N 1293.40 E 5974315.97 N 653935.06 E 19.417 1147.96 9765.35 94.180 75.640 8987.92 9054.62 404.01 N 1326.75 E 5974323.93 N 653968.25 E 11.906 1175.34 9796.88 97.710 68.950 8984.65 9051.35 413.54 N 1356.60 E 5974334.06 N 653997.90 E 23.886 1202.11 9836.19 95.330 65.420 8980.18 9046.88 428.68 N 1392.59 E 5974349.94 N 654033.58 E 10.782 1237.15 9866.21 92.160 61.020 8978.22 9044.92 442.17 N 1419.32 E 5974363.97 N 654060.03 E 18.038 1264.87 9899.52 88.460 58.730 8978.04 9044.74 458.89 N 1448.13E 5974381.27 N 654088.49 E 13.062 1296.38 9932.76 88.460 52.560 8978.94 9045.64 477.63 N 1475.55 E 5974400.57 N 654115.52 E 18.555 1328.52 9973.07 87.750 44.980 8980.27 9046.97 504.16 N 1505.82 E 5974427.71 N 654145.25 E 18.876 1368.41 10001.33 88.990 40.930 8981.08 9047.78 524.83 N 1525.07 E 5974448.77 N 654164.07 E 14.982 1396.63 3 June, 2004· 14:50 Page 2 of 4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA F Pad - F-28A Your Ref: AP/500292164901 Job No. AKMW3079250, Surveyed: 20 May, 2004 BPXA North Slope Alaska 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) (°/1 DOft) 10035.21 88.550 34.760 8981.80 9048.50 551.57 N 1545.84 E 5974475.92 N 654184.29 E 18.253 1430.44 10072.12 85.640 28.590 8983.68 9050.38 582.92 N 1565.19 E 5974507.66 N 654203.00 E 18.461 1466.79 10108.23 88.550 22.960 8985.51 9052.21 615.38 N 1580.86 E 5974540.43 N 654218.01 E 17.531 1501.57 10141.82 92.160 16.960 8985.30 9052.00 646.93 N 1592.32 E 5974572.21 N 654228.82 E 20.844 1532.90 10171.13 91.190 12.380 8984.44 9051.14 675.27 N 1599.73 E 5974600.69 N 654235.66 E 15.966 1559.15 e 10209.78 90.040 7.980 8984.03 9050.73 713.30 N 1606.56 E 5974638.85 N 654241.71 E 11.766 1592.33 10256.15 89.520 2.690 8984.20 9050.90 759.45 N 1610.87 E 5974685.08 N 654245.08 E 11.463 1629.99 10287.38 88.720 357.050 8984.68 9051.38 790.66 N 1610.80 E 5974716.29 N 654244.38 E 18.238 1653.50 1 0332.48 87.580 351.590 8986.14 9052.84 835.50 N 1606.34 E 5974761.02 N 654239.01 E 12.361 1684.42 10366.81 90.480 348.070 8986.72 9053.42 869.28 N 1600.28 E 5974794.67 N 654232.26 E 13.283 1705.93 10402.91 92.860 355.470 8985.67 9052.37 904.96 N 1595.12 E 5974830.24 N 654226.37 E 21.523 1729.48 10432.04 92.250 0.750 8984.37 9051.07 934.04 N 1594.16E 5974859.29 N 654224.82 E 18.228 1750.79 10471.58 88.810 8.860 8984.00 9050.70 973.40 N 1597.47E 5974898.71 N 654227.33 E 22.276 1782.67 10501.63 87.400 15.030 8985.00 9051.70 1002.77 N 1603.68 E 5974928.20 N 654232.94 E 21.050 1808.91 10533.44 87.780 21.110 8986.34 9053.04 1032.97 N 1613.54 E 5974958.59 N 654242.18 E 19.134 1838.16 10576.11 90.570 19.780 8986.95 9053.65 1072.94 N 1628.44 E 5974998.86 N 654256.26 E 7.243 1878.11 10606.18 92.330 14.670 8986.19 9052.89 1101.64 N 1637.34 E 5975027.74 N 654264.58 E 17.968 1905.61 10639.42 91.370 7.620 8985.12 9051.82 1134.21 N 1643.76 E 5975060.44 N 654270.33 E 21.394 1934.40 10684.80 89.430 4.630 8984.80 9051.50 1179.33 N 1648.60 E 5975105.64 N 654274.25 E 7.854 1971.63 10722.43 88.630 353.180 8985.44 9052.14 1216.88 N 1647.88 E 5975143.17 N 654272.77 E 30.497 1999.50 10755.59 91.010 349.300 8985.54 9052.24 1249.65 N 1642.83 E 5975175.83 N 654267.05 E 13.726 2020.91 10786.49 93.220 356.520 8984.40 9051.10 1280.27 N 1639.02 E 5975206.36 N 654262.62 E 24.419 2041.52 e 10819.00 93.220 356.520 8982.57 9049.27 1312.67 N 1637.05 E 5975238.72 N 654259.99 E 0.000 2064.68 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 41.000° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 10819.00ft., The Bottom Hole Displacement is 2098.34ft., in the Direction of 51.276° (True). 3 June, 2004 - 14:50 Page 3 of4 DrillQuest 3.03.06.002 Halliburton Sperry-Sun Survey Report for PBU_WOA F Pad - F-28A Your Ref: AP/500292164901 Job No. AKMW3079250, Surveyed: 20 May, 2004 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 9000.00 9069.00 10819.00 8829.24 8892.26 9049.27 524.01 N 538.59 N 1312.67 N 718.97 E 743.01 E 1637.05 E Tie On Point Window Point Projected Survey e Survey too/prOf/ram for F-28A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 9000.00 0.00 9000.00 8829.24 10819.00 8829.24 BP High Accuracy Gyro (F-28) 9049.27 MWD Magnetic (F-28A) e 3 June, 2004 - 14:50 Page 4 of4 Dril/Quest 3.03.06.002 TREE = W8...LHEAD = A crUll. TOR = KB. ELEV = BF. ELEV - KOP- Max Angle = Datum MD = DatumTVD = 4"CIW fvk;EVOY AXELSON 66.7' 38' 6700' 94 9515' 9041' 8800' SS 13-318" CSG, 72#, L-80, ID = 12.347" Minimum ID = 2.380" @ 9678' 3-3/16" X 2-7/8" XO F-28A 2085' 4-1/2" OTIS SSSV NIP, ID = 3.813" . PERFORATION SUWMARY REF LOG: ANGLEATTOPÆRF: 86 @ 10080' Note: Refer to Production DB for historcal perf data SIZE SPF INTER\! AL OpnlSqz DA 1E 2" 6 10080 - 10300 0 OS/22/04 2" 6 10350 - 10520 0 05122/04 2" 6 10640 - 10770 0 05122/04 14-112" 1BG, 12.6#, L-80, .0152 bpf, ID =3.958" 3-1/2" LNR, 8.81#, L-80, .0087 bpf, ID = 2.992" 9-5/8" CSG, 47#, L-80, ID = 8.681" DA 1E REV BY 10/12/86 05122/04 KAK 06/01/04 RMH/KA TOP OF WHIPSTOCK 17" LNR, 26#, L-80, .0383 bpf, ID - 6.276" 8390' 8401' 8591' I I GAS LIFT Jv1ANffi8...S ST MD TVD DEV TYPE VLV LA TCH SIZE DA1E 7 2978 2911 1 011S OOrvE RM 16 06/01/04 6 4774 4708 0 011S SO RM 20 06/01/04 5 5903 5836 1 011S DIv1Y RA 0 4 6639 6572 6 011S DIv1Y RA 0 3 7180 7094 17 011S DIv1Y RA 0 2 7758 7631 24 011S DIv1Y RA 0 1 8140 7978 25 011S DIv1Y RA 0 8208' -1011S XA SLlONG SLV, ID = 3.813" 8268' -1TIW TBG SEAL ASSY I 9069' 8283' 8288' 8321' 9-518" TIW Hf-BP PKR, ID = 4.750" HMILL OUTEX1ENSION, ID= 6.004" I 7" BROWN SI-ORTY HY D. LNR HNGR 4-1/2" OTIS X NIP, ID = 3.813" 3.7" BKR DEPLOY MENT SLV, ID = 3.0" 8369' 8390' 8401' 8845' 4-1/2"OTISXN NIP, MILLEDID= 3.80" (BB-IIND cr LNR) 3-1/2" I-ES XNP, ID-2.813" 4-1/2" WLEG (BB-IIND cr LNR) 3-1/2" X 3-3/16" XO, ID = 2.786" ES11MATED CEMENT TOP TOP OF WINDOW ~~ I qO'Z -13-3116" X2-7/8"XO, ID =2.380" I 9430' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, D = 2.80" COMrvENTS ORIGINAL COMPLETION CTD SIDETRACK (F-28A) GLV ao 12-718" LNR, 6.4#, L-80, .0058 bpf, ID = 2.441" H 10819' DATE PRUDHOE BAY UNIT W8...L: F-28A ÆRMT N:.J: 2040690 API N:.J: 50-029-21649-01 SEe 2, T11 N, R13E, 2359' FSL & 2194' F8... REV BY OOWMENTS BP Exploration (Alaska) . . FRANK H. MURKOWSKI, GOVERNOR A ItASIiA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott CT Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe F-28A BP Exploration (Alaska) Inc. Permit No: 204-069 Surface Location: 2359' NSL, 2193' WEL, SEC. 02, TIIN, R13E, UM Bottomhole Location: 4123' NSL, 372' WEL, SEC. 02, TIIN, R13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exempt you ITom obtaining additional permits or approvals required by law ITom 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 pennit 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 pennit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field' r -3607 (pager). Since / BY ORDER OF THE COMMISSION DA TED thi~ day of April, 2004 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. i.u 4A- 4 ( L ~ /·z.."o4 . STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 MC 25.005 / 1 a. Type of work o Drill II Redrill rb. Current Well Class o Exploratory II Development Oil o Multiple Zone ORe-Entry o Stratigraphic Test o Service o Development Gas o Single Zone 2. Operator Name: 5. Bond: 181 Blanket o Single Well 11. Well Name and Numbe/, BP Exploration (Alaska) Inc. Bond No. 2S 100302630-277 PBU F-28A 3. Address: 6. Proposed Depth: 12. Field 1 Pool(s): P.O. Box 196612, Anchorage, Alaska 99519-6612 MD 11250 TVD 8985 Prudhoe Bay Field 1 Prudhoe Bay 4a. Location of Well (Governmental Section): 7. Property Designation: Pool ./ Surface: ADL 028280 2359' NSL, 2193' WEL, SEC. 02, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: Top of Productive Horizon: 2831' NSL, 1559' WEL, SEC. 02, T11N, R13E, UM 05/03/04 Total Depth: 9. Acres in Property: 14. Distance to Nearest Property: 4123' NSL, 372' WEL, SEC. 02, T11 N, R13E, UM 2560 9973' 4b. Location of Well (State Base Plane Coordinates): 10. KB Elevation KBE= 15. Distance to Nearest Well Within Pool Surface: x- 652650 y- 5973893 Zone- ASP4 (Height above GL): 66.70' feet 395' away from F-11 at 11044' 16. Deviated Wells: 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.~) Kickoff Depth 9110 ft Maximum Hole Angle 0 94 Downhole: 3204 psig Surface: 2200 psig 18. C~sing Program Specificatipns Setting Depth q!J(?ntityBl Size TOD Bottom c.f. or Hole Casino WeiClht Grade CouDlino Lenath MD TVD MD TVD (includino staoe data) 3-3/4" 3-3/16' x 2-7/8' 6.2# 1 6.5# L-80 TCII/ST 2915' 8335' 8155' 11250' 8985' 135 cu ft Class 'G' ./ 19. PRESENT W::LL ÇONDITIONSUMMA~Y (To be completed for Redrill AND Re-entry Qperations) .................... .. Total Depth MD (ft): Total Depth TVD (ft): I Plugs (measured): I Effective Depth MD (ft): I Effective Depth TVD (ft):1 Junk (measured): 9430 9221 NIA 9384 9179 NIA Ca$il'lQ ·.i l.:ênâtl"! ·······Sjzø .... .. ... · ·.....iMDi / ··.··.·...···rvOi I ConrtlJr.tor 110' 20" 8 cu yds Concrete 110' 110' 2675' 13-3/8" 3274 cu It Arctic Set III, 465 cu It Arctic Set II 2675' 2675' i;:¡tF! Production 8593' 9-5/8" 575 cu ft Class 'G' 8593' . 8457' Liner 1109' 7" 374 cu ft Class 'G' 8321' - 9430' 8209' - 9221' Perforation Depth MD (ft): 9222' - 9258' perfOration Depth TVD (ft): 9032' - 9065' 20. Attachments 181 Filing Fee, $100 181 BOP Sketch 181 Drilling Program o Time vs Depth Plot o Shallow Hazard Analysis o Property Plat o Diverter Sketch o Seabed Report 181 Drilling Fluid Program 181 20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer -I?7{]) j L 871díJ (~~tf- 5G4 -43~R Prepared By Name/Number: Signature Phone Date 4/22/04-. Sondra Stewman, 564-4750 .> . .i~i. (1'......... . ~. """,:. .i i>..T .....: iii..····?·.·...· .. Permit To Drill ~I API Number: permit'.J;0va/,¡, I See cover letter for 1./ Number:2oc;,; -,.-j¿' q 50-029-21649-01-00 Date: . ';)1- '/16 other requirements Conditions of Approval: Sámples Required DYes ~o Mud Log Requfred ( uBJ:~eI~eD Hydro h ulfide Measures '!5tY es D No Directional Survey Req r .. Other:\est ""ßa - . c.., O. c; L ¿, . c:, ù 0 . A P R 2 2 2004 0 00 f~t. ) p~v Alaska Oil & Gas Cons. C ission BY ORDER OF Anchor ~~ ~0" ADDroved Bv: ""......-..... . THE COMMISSION Date'l ð Form 10-401 Re<åsed ~03 ~. I) :\ ! LJ I I\! A L , ubmjÝln Du~licate . BP F-28A CTD Sidetrack . Phase 1 Operations: Prep Work: · Integrity pressure test OA, IA &tbg, wellhead seals & Xmas tree valves. · Set whipstock /' · Mill XN nipple · Downsqueeze cement Phase 2 Operations: Mill window, Drill and Complete sidetrack. Mud Program: · Phase 1: Seawater/1 % KCI ¿J · Phase 2: Mill with seawater / Y2lb biozan, drill with Solids Free Flo-Pro (8.6 ~pg) Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: I . 33/16 TCII X 2Ys" STL from 1125<;/;,~~.. '~~r85'ss) to 8,335'MD (-8, 155'ss). / . The liner will be cemented with~blS with a planned TOC at 8900' . Parent Well CasinQs Hole Size Burst (psi) Collapse (psi) 13 3/8" 72# L -80 5380 2670 9%" 47#, L-80 6870 4750 ( 7" 26#, L-80 7240 5410 Sidetrack Casings 3-3/16" 6.2#, L-80, TCII- Prod LNR 3.75 8520 7660 2)1'" 6.5#, L-80, STL - Prod LNR 3.75 10570 11170 Well Control: · BOP diagram is attached. · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. / · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 93°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. · F-28A will be approximately 395' ctr-ctr away from well F-11 at 11044' md · F-28A will be approximately 9973' from the unit boundary, (Prudhoe Bay Unit) Logging · MWD Gamma Ray and Resistivity will be run in the open hole section. · Memory cNL will be run inside the liner. Hazards . · H2S last measured on F-28 was 10ppm in 2000. 100ppm is the maximum measured on the pad/ · The risk of a lost circulation event is considered low, one small faults will be crossed. · Stuck pipe in 14N shale. Reservoir Pressure · Res. press. is estimated to be 3204 psi at 8800'ss (7.1 ppg emw). .. · Max. surface pressure with gas (0.12 psi/ft) to surface is 2200 psi. / TREE = WRLHEAO = ACTUATOR = KB. ElEV = 4" CIW M:EVOY AXB.SON 66.7' F-28 SAFETY NOTES: BF. ElEV = 38' KOP= 6700' 4-1/2" OTIS SSSV NIP, 10 = 3.813" I Max Anqe = 25 @ 8300' I 2085' Datum MD = 9041' . Datum TVD = 8800' SS 113-318" CSG, 72#, L-BO, ID = 12.347" 2675' µ ~ GAS LIFT Mo\/>VRElS ST MD TVD DEV TYPE VLV LATCH SIZE DATE 7 2978 2911 1 OllS RA L 6 4774 4708 0 011S RA Minimum ID = 3.725" @ 8357' 5 5903 5836 1 OllS RA 4-1/2" OTIS XN NIPPLE 4 6639 6572 6 OllS RA 3 71BO 7094 17 OllS RA 2 7758 7631 24 011S RA 1 8140 7978 25 OllS RA I I I 8208' OllS XA SlI(]NG SLV, 10 = 3.813" I i .... r 8268' TIW TOO SEAL ASSY I :g I 8283' 9-518" TIW HH3P PKR, ID = 4.750" I .2S TOPOF7" LNR 8321' I I . 8325' 4-1/2" OTE> X NIP, 10 = 3.813" I I 8357 4-1/2" OTB XN NP, 10 = 3.725" I 14-1f2" TBG, 12.6#, L-BO, .0152 bpf, 10 = 3.958" 8390' I 8390' 4-1/2" BKRWlEG 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 8591' 1-4 ~ I 8388' H RM:> IT LOGGED 06KJ1/87 I PERFORATION SUrvtAARY REF LOG: SWS BI-CS 10/08/86 I A NGLE AT TOP ÆRF: 24 @ 9195' - flbte: Refer to Production DB for historical perf data SIZE SPF INTERv' AL OpnlSqz [)ð. TE I 9220' MARKER JOINT 3-3/8" 4 9195 - 9232 S 10/31197 I 3-3/8" 6 9222 - 9232 0 11/11197 3-3/8" 6 9238 - 9258 0 11/11197 3-3/8" 4 9242 - 9258 0 08125190 ffiID 9382' I I 7" LNR, 26#, L-BO IJ4S, .0383 bpf, ID = 6.276" 9430' I DATE 10/12/86 03/03/01 03/05/01 05/19/01 07/13/03 REV BY COMM:NTS ORIGINAL COMPLETION SIS-MH CONVERfEDTOCANVAS SIS-MD ANAL RN/KAK CORRECTIONS a.1O'TLP KB REVA 1lON. MAX ANGlE [)ð.TE RBI BY COM-AENTS FRUŒiOE SA Y UNT WRL: F-28 ÆRMITNo: 1861590 Apt No: 50-029-21649-00 sa; 2, T11 N. R13E, 2359' FSL & 2194' FR BP Exploration (Alaska) TREE = . SAfETY NOTES: 4" CrN F-28 A Proposed CTD Sidetrack WB.LHEAD = McEVOY ACTUATOR = AXB.SON KB. B.EV = 66.7' BF. B.EV = 38' KOP= 6700' Max Angle = 25 @ 8300' Datum MD = 9041' DatumìVD= 8800' SS . 2085' -14-1/2" OTIS SSSV NIP, Ð = 3.813" I GAS LIFT MANDRELS S MD ìVD DEV TYPE VLV LATCH SIZE DATE 7 2978 2911 1 OTIS RA 6 4774 4708 0 OTIS RA 5 5903 5836 1 OTIS RA 4 6639 6572 6 OTIS RA 3 7180 7094 17 OTIS RA 2 7758 7631 24 OTIS RA 1 8140 7978 25 OTIS RA I I 8208' OTIS XA SLÐtNG SL V, ID = 3.813" 8268' -TIN TaG SEAL ASSY I 13-3/8" CSG, 72#, L-80, Ð = 12.347" Minimum 10 = 3"725" @ 8357' 4-112" OTIS XN NIPPLE (milled out to 3.8") TOPOF 7" LNR I 8321' 4-1/2" TaG, 12.6#, L-80, .0152 bpf, Ð = 3.958" 8325' 8335' 8345' 835T 8390' 8388' 8900' 8390' 19-5/8" CSG, 47#, L-80, ID = 8.681" I ANGLE AT TOP PERF: 24 @ 9195' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DA TE 3-3/8" 4 9195 - 9232 isolated proposed 3-3/8" 6 9222 - 9232 isolated proposed 3-3/8" 6 9238 - 9258 isolated proposed 3-3/8" 4 9242 - 9258 isolated proposed 17" LNR, 26#, L-80 U4S, .0383 bpf, Ð = 6.276" I 9430' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/12/86 ORIGINAL COM PLETION 03103101 SIS-MH CONVERTED TO CANVAS 03105101 SIS-MD FINAL 05119101 RNIKAK CORRECTIONS 07/13103 CMOITLP KB B.EV A TION, MAX ANGlE 9-5/8" TIN HHBP PKR. ID = 4.750" -4-1/2" BKR WLEG I H B.MD TT LOGGED 06/01/87 I Cement Top /' 3-3/16 x 2-7/8 X-over / PRUDHOE BAY UNIT WB.L: F-28 PERMfTNo: 1861590 API No: 50-029-21649-00 SEC2. T11N, R13E. 2359' FSL & 2194' FEL BP exploration (Alaska) Nordic 1 big hole All Measurements are from top of Riser 4/20/2004 :L.... () (J) a: top of bag BAG 7 1/16" 5000psi bttm of bag middle of slips Blind/Shears .......................... middle of pipes TOTs ....................·····71/16" 5000psi middle of flow cross Mud Cross Mud Cross 7 1/16" 5000psi middle of blind/shears .......................... middle of pipe/slips TOTs ........·······71/16" 5000psi ................... Flow Tee . BP-GDB Baker Hughes INTEQ Planning Report . ... ......... Obp Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre bggm2003 Site: PB F Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5972527.29 ft 650960.70 ft Latitude: 70 19 Longitude: 148 46 North Reference: Grid Convergence: 55.283 N 31.468 W True 1.15 deg Well: F-28 Slot Name: 28 F-28 Well Position: +N/-S 1331.53 ft Northing: 5973893.00 ft Latitude: 70 20 8.377 N +E/-W 1716.57 ft Easting : 652650.00 ft Longitude: 148 45 41.338 W Position Uncertainty: 0.00 ft Wellpath: Plan#1 F-28A 500292164901 Current Datum: 29 : 28 9/19/1986 00:00 Magnetic Data: 4/21/2004 Field Strength: 57588 nT Vertical Section: Depth From (TVD) ft 31.20 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 F-28 9100.00 ft Mean Sea Level 25.27 deg 80.87 deg Direction deg 41.00 Height 66.70 ft Targets F-28A Polygon1.1 0.00 1035.46 1514.50 5974959.00 654143.00 70 20 18.559 N 148 4457.103 W -Polygon 1 0.00 1035.46 1514.50 5974959.00 654143.00 70 20 18.559 N 148 4457.103 W ·Polygon 2 0.00 558.98 1482.80 5974482.00 654121.00 70 20 13.873 N 148 44 58.032 W -Polygon 3 0.00 526.79 1295.09 5974446.00 653934.00 70 20 13.557 N 148 45 3.514 W -Polygon 4 0.00 349.10 1277.47 5974268.00 653920.00 70 20 11.809 N 148 45 4.030 W -Polygon 5 0.00 396.73 1787.58 5974326.00 654429.00 70 20 12.277 N 148 4449.132 W ·Polygon 6 0.00 987.30 1669.57 5974914.00 654299.00 70 20 18.085 N 148 44 52.574 W -Polygon 7 0.00 1722.90 1944.61 5975655.00 654559.00 70 20 25.319 N 148 44 44.535 W -Polygon 8 0.00 1779.72 1708.70 5975707.00 654322.00 70 20 25.878 N 148 44 51.426 W F-28A Fault 1 0.00 885.19 1329.39 5974805.00 653961.00 70 20 17 .082 N 148 45 2.511 W -Polygon 1 0.00 885.19 1329.39 5974805.00 653961.00 70 20 17.082 N 148 45 2.511 W -Polygon 2 0.00 230.32 1412.09 5974152.00 654057.00 70 20 10.641 N 148 45 0.099 W -Polygon 3 0.00 65.24 1364.71 5973986.00 654013.00 70 20 9.017 N 148 45 1.483 W -Polygon 4 0.00 230.32 1412.09 5974152.00 654057.00 70 20 10.641 N 148 45 0.099 W F-28A Fault 3 0.00 1351.39 2014.07 5975285.00 654636.00 70 20 21.665 N 148 44 42.509 W -Polygon 1 0.00 1351.39 2014.07 5975285.00 654636.00 70 20 21.665 N 148 44 42.509 W -Polygon 2 0.00 1465.71 1459.24 5975388.00 654079.00 70 20 22.791 N 148 44 58.715 W F-28A Fault 2 0.00 1137.39 1470.56 5975060.00 654097.00 70 20 19.562 N 148 44 58.386 W -Polygon 1 0.00 1137.39 1470.56 5975060.00 654097.00 70 20 19.562 N 148 44 58.386 W -Polygon 2 0.00 946.92 1736.76 5974875.00 654367.00 70 20 17.688 N 148 44 50.612 W F-28A T1.2 8985.00 514.76 1590.93 5974440.00 654230.00 70 20 13.438 N 148 44 54.874 W F-28A T1.3 8985.00 1024.69 1601.31 5974950.00 654230.00 70 20 18.453 N 148 44 54.568 W F-28A T1.4 8985.00 1764.46 1819.43 5975694.00 654433.00 70 20 25.728 N 148 4448.192 W F-28A T1.1 8990.00 522.70 1200.98 5974440.00 653840.00 70 20 13.517 N 148 45 6.263 W . . ~ Obp BP-GDB Baker Hughes INTEQ Planning Report 9100.00 8853.88 TIP 9110.00 8863.02 KOP 9130.00 8881.18 3 9341.74 8990.59 4 9421.74 8988.01 5 9501.74 8985.33 6 10251.74 8984.81 7 10551.74 8985.26 8 10776.74 8985.55 9 11051.74 8985.86 10 11250.00 8986.05 TO Plan: Plan #1 Date Composed: 4/20/2004 Identical to Lamar's Plan #1 Version: 5 Principal: Yes Tied-to: From: Definitive Path Plan Section Information 9100.00 23.98 58.69 8853.88 545.14 753.78 0.00 0.00 0.00 0.00 9110.00 23.99 58.63 8863.02 547.25 757.25 0.26 0.10 -0.60 292.27 9130.00 25.56 60.72 8881.18 551.48 764.48 9.00 7.87 10.43 30.00 9341.74 90.00 97.84 8990.59 560.54 930.29 33.00 30.43 17.53 40.00 9421.74 93.69 111.77 8988.01 540.17 1007.39 18.00 4.61 17.41 75.00 9501.74 90.13 125.73 8985.33 501.80 1077.30 18.00 -4.45 17.45 104.00 10251.74 89.91 350.73 8984.81 811.46 1577.35 18.00 -0.03 -18.00 270.00 10551.74 89.92 26.73 8985.26 1103.12 1622.15 12.00 0.01 12.00 90.00 10776.74 89.93 359.73 8985.55 1320.13 1673.18 12.00 0.00 -12.00 270.00 11051.74 89.94 32.73 8985.86 1580.53 1748.99 12.00 0.00 12.00 90.00 11250.00 89.95 8.94 8986.05 1764.49 1819.01 12.00 0.00 -12.00 270.00 Survey 9100.00 23.98 58.69 8853.88 545.14 753.78 5974453.33 653392.47 905.94 0.00 0.00 TIP 9110.00 23.99 58.63 8863.02 547.25 757.25 5974455.51 653395.90 909.81 0.26 292.27 KOP 9125.00 25.17 60.22 8876.66 550.42 762.62 5974458.79 653401.20 915.73 9.00 30.00 MWD 9130.00 25.56 60.72 8881.18 551.48 764.48 5974459.88 653403.04 917.75 9.00 28.56 3 9150.00 30.89 68.99 8898.80 555.43 773.05 5974464.01 653411.53 926.36 33.00 40.00 MWD 9175.00 38.07 76.21 8919.40 559.58 786.55 5974468.43 653424.94 938.34 33.00 32.70 MWD 9200.00 45.57 81.40 8938.03 562.76 802.89 5974471.94 653441.21 951.46 33.00 26.73 MWD 9225.00 53.24 85.39 8954.29 564.90 821.73 5974474.47 653460.00 965.44 33.00 22.86 MWD 9250.00 61.03 88.64 8967.84 565.97 842.68 5974475.96 653480.92 979.99 33.00 20.26 MWD 9275.00 68.88 91.44 8978.42 565.93 865.31 5974476.39 653503.55 994.81 33.00 18.48 MWD 9296.65 75.72 93.62 8985.00 565.02 885.90 5974475.89 653524.15 1007.63 33.00 17.30 F-28A T1 9300.00 76.77 93.95 8985.80 564.80 889.15 5974475.74 653527.40 1009.59 33.00 16.63 MWD 9325.00 84.69 96.30 8989.82 562.59 913.70 5974474.03 653551.99 1024.04 33.00 16.55 MWD 9341.74 90.00 97.84 8990.59 560.54 930.29 5974472.31 653568.62 1033.37 33.00 16.17 4 9350.00 90.38 99.28 8990.57 559.31 938.46 5974471.25 653576.81 1037.80 18.00 75.00 MWD 9375.00 91.55 103.62 8990.15 554.35 962.95 5974466.79 653601.39 1050.12 18.00 75.00 MWD 9400.00 92.70 107.98 8989.22 547.55 986.98 5974460.48 653625.56 1060.76 18.00 75.08 MWD 9421.74 93.69 111.77 8988.01 540.17 1007.39 5974453.52 653646.12 1068.58 18.00 75.24 5 9425.00 93.55 112.34 8987.80 538.95 1010.41 5974452.36 653649.15 1069.64 18.00 104.00 MWD 9450.00 92.45 116.71 8986.49 528.59 1033.11 5974442.47 653672.07 1076.71 18.00 104.04 MWD 9475.00 91.33 121.07 8985.67 516.52 1054.99 5974430.85 653694.18 1081.95 18.00 104.26 MWD 9500.00 90.21 125.43 8985.33 502.82 1075.89 5974417.57 653715.35 1085.33 18.00 104.41 MWD 9501.74 90.13 125.73 8985.33 501.80 1077.30 5974416.59 653716.79 1085.49 18.00 104.47 6 9525.00 90.13 121.55 8985.27 488.92 1096.66 5974404.11 653736.40 1088.47 18.00 270.00 MWD Obp . BP-GDB Baker Hughes INTEQ Planning Report . -.I: INTRQ 9550.00 90.13 117.05 8985.21 476.69 1118.46 5974392.32 653758.44 1093.54 18.00 269.99 MWD 9575.00 90.13 112.55 8985.16 466.21 1141.15 5974382.31 653781.34 1100.51 18.00 269.98 MWD 9600.00 90.13 108.05 8985.10 457.54 1164.59 5974374.12 653804.95 1109.35 18.00 269.97 MWD 9625.00 90.12 103.55 8985.05 450.74 1188.64 5974367.80 653829.13 1119.99 18.00 269.96 MWD 9650.00 90.12 99.05 8985.00 445.84 1213.15 5974363.41 653853.73 1132.38 18.00 269.95 MWD 9675.00 90.11 94.55 8984.95 442.88 1237.97 5974360.96 653878.60 1146.43 18.00 269.94 MWD 9700.00 90.11 90.05 8984.90 441.88 1262.94 5974360.46 653903.59 1162.06 18.00 269.93 MWD 9725.00 90.10 85.55 8984.85 442.84 1287.91 5974361.93 653928.54 1179.17 18.00 269.92 MWD 9750.00 90.09 81.05 8984.81 445.76 1312.74 5974365.36 653953.30 1197.65 18.00 269.91 MWD 9775.00 90.09 76.55 8984.77 450.62 1337.25 5974370.71 653977.71 1217.40 18.00 269.91 MWD 9800.00 90.08 72.05 8984.73 457.38 1361.31 5974377.96 654001.62 1238.29 18.00 269.90 MWD 9825.00 90.07 67.55 8984.70 466.01 1384.77 5974387.07 654024.90 1260.20 18.00 269.89 MWD 9850.00 90.06 63.05 8984.67 476.46 1407.48 5974397.97 654047.38 1282.98 18.00 269.89 MWD 9875.00 90.05 58.55 8984.65 488.66 1429.29 5974410.61 654068.95 1306.49 18.00 269.88 MWD 9900.00 90.04 54.05 8984.63 502.52 1450.09 5974424.90 654089.45 1330.60 18.00 269.88 MWD 9925.00 90.03 49.55 8984.61 517.98 1469.73 5974440.75 654108.77 1355.15 18.00 269.87 MWD 9950.00 90.02 45.05 8984.60 534.93 1488.09 5974458.07 654126.79 1380.00 18.00 269.87 MWD 9975.00 90.01 40.55 8984.59 553.27 1505.07 5974476.75 654143.39 1404.98 18.00 269.87 MWD 10000.00 90.00 36.05 8984.59 572.89 1520.56 5974496.68 654158.48 1429.94 18.00 269.87 MWD 10025.00 89.99 31.55 8984.59 593.66 1534.47 5974517.72 654171.95 1454.74 18.00 269.87 MWD 10050.00 89.98 27.05 8984.60 615.45 1546.70 5974539.76 654183.73 1479.21 18.00 269.87 MWD 10075.00 89.97 22.55 8984.61 638.14 1557.18 5974562.66 654193.75 1503.21 18.00 269.87 MWD 10100.00 89.96 18.05 8984.63 661.59 1565.85 5974586.27 654201.94 1526.59 18.00 269.87 MWD 10125.00 89.95 13.55 8984.65 685.64 1572.65 5974610.45 654208.25 1549.21 18.00 269.87 MWD 10150.00 89.94 9.05 8984.67 710.14 1577.55 5974635.05 654212.65 1570.92 18.00 269.88 MWD 10175.00 89.93 4.55 8984.70 734.96 1580.50 5974659.93 654215.10 1591.59 18.00 269.88 MWD 10200.00 89.92 0.05 8984.73 759.94 1581.51 5974684.91 654215.59 1611.09 18.00 269.89 MWD 10225.00 89.91 355.55 8984.77 784.91 1580.54 5974709.86 654214.12 1629.31 18.00 269.89 MWD 10250.00 89.91 351.05 8984.80 809.73 1577.63 5974734.62 654210.70 1646.13 18.00 269.90 MWD 10251.74 89.91 350.73 8984.81 811.46 1577.35 5974736.33 654210.39 1647.25 18.00 269.91 7 10275.00 89.91 353.52 8984.84 834.49 1574.17 5974759.30 654206.74 1662.54 12.00 90.00 MWD 10300.00 89.91 356.52 8984.89 859.39 1572.00 5974784.15 654204.06 1679.92 12.00 90.00 MWD 10325.00 89.91 359.52 8984.93 884.38 1571.13 5974809.11 654202.69 1698.20 12.00 89.99 MWD 10350.00 89.91 2.52 8984.97 909.37 1571.58 5974834.10 654202.63 1717.36 12.00 89.99 MWD 10375.00 89.91 5.52 8985.01 934.30 1573.33 5974859.07 654203.88 1737.33 12.00 89.98 MWD 10400.00 89.91 8.52 8985.04 959.11 1576.39 5974883.93 654206.43 1758.06 12.00 89.98 MWD 10425.00 89.91 11.52 8985.08 983.73 1580.74 5974908.63 654210.27 1779.49 12.00 89.97 MWD 10450.00 89.91 14.52 8985.12 1008.08 1586.37 5974933.09 654215.41 1801.57 12.00 89.97 MWD 10475.00 89.92 17.52 8985.16 1032.11 1593.27 5974957.25 654221.82 1824.22 12.00 89.96 MWD 10500.00 89.92 20.52 8985.19 1055.74 1601.42 5974981.04 654229.48 1847.41 12.00 89.96 MWD 10525.00 89.92 23.52 8985.23 1078.91 1610.79 5975004.40 654238.38 1871.04 12.00 89.95 MWD 10550.00 89.92 26.52 8985.26 1101.57 1621.37 5975027.26 654248.49 1895.08 12.00 89.95 MWD 10551.74 89.92 26.73 8985.26 1103.12 1622.15 5975028.83 654249.24 1896.77 12.00 89.95 8 10575.00 89.92 23.94 8985.29 1124.14 1632.10 5975050.05 654258.76 1919.15 12.00 270.00 MWD 10600.00 89.92 20.94 8985.33 1147.25 1641.64 5975073.34 654267.83 1942.85 12.00 270.00 MWD 10625.00 89.93 17.94 8985.36 1170.82 1649.96 5975097.07 654275.67 1966.10 12.00 270.01 MWD 10650.00 89.93 14.94 8985.39 1194.79 1657.04 5975121.18 654282.25 1988.84 12.00 270.01 MWD 10675.00 89.93 11.94 8985.42 1219.10 1662.85 5975145.61 654287.57 2011.00 12.00 270.02 MWD 10700.00 89.93 8.94 8985.46 1243.69 1667.38 5975170.28 654291.60 2032.52 12.00 270.02 MWD 10725.00 89.93 5.94 8985.49 1268.47 1670.62 5975195.12 654294.33 2053.35 12.00 270.02 MWD 10750.00 89.93 2.94 8985.52 1293.40 1672.55 5975220.08 654295.76 2073.43 12.00 270.03 MWD 10775.00 89.93 359.94 8985.55 1318.39 1673.18 5975245.07 654295.88 2092.70 12.00 270.03 MWD . BP-GDB Baker Hughes INTEQ Planning Report . ... ~ Obp 10776.74 89.93 359.73 8985.55 1320.13 1673.18 5975246.81 654295.84 2094.02 12.00 270.03 9 10800.00 89.93 2.52 8985.58 1343.38 1673.63 5975270.07 654295.82 2111.86 12.00 90.00 MWD 10825.00 89.93 5.52 8985.61 1368.31 1675.39 5975295.03 654297.07 2131.83 12.00 90.00 MWD 10850.00 89.93 8.52 8985.64 1393.12 1678.44 5975319.90 654299.62 2152.56 12.00 89.99 MWD 10875.00 89.93 11.52 8985.66 1417.74 1682.80 5975344.59 654303.47 2173.99 12.00 89.99 MWD 10900.00 89.93 14.52 8985.69 1442.09 1688.43 5975369.05 654308.60 2196.07 12.00 89.99 MWD 10925.00 89.94 17.52 8985.72 1466.12 1695.33 5975393.21 654315.01 2218.73 12.00 89.98 MWD 10950.00 89.94 20.52 8985.75 1489.75 1703.48 5975417.01 654322.68 2241.91 12.00 89.98 MWD 10975.00 89.94 23.52 8985.78 1512.93 1712.85 5975440.36 654331.57 2265.55 12.00 89.98 MWD 11000.00 89.94 26.52 8985.80 1535.58 1723.42 5975463.22 654341.68 2289.58 12.00 89.97 MWD 11025.00 89.94 29.52 8985.83 1557.64 1735.17 5975485.52 654352.98 2313.94 12.00 89.97 MWD 11050.00 89.94 32.52 8985.85 1579.06 1748.05 5975507.20 654365.42 2338.56 12.00 89.97 MWD 11051.74 89.94 32.73 8985.86 1580.53 1748.99 5975508.69 654366.33 2340.28 12.00 89.96 10 11075.00 89.94 29.94 8985.88 1600.39 1761.08 5975528.79 654378.02 2363.21 12.00 270.00 MWD 11100.00 89.94 26.94 8985.90 1622.37 1772.99 5975551.01 654389.47 2387.61 12.00 270.00 MWD 11125.00 89.94 23.94 8985.93 1644.95 1783.73 5975573.79 654399.75 2411.69 12.00 270.01 MWD 11150.00 89.94 20.94 8985.95 1668.05 1793.27 5975597.08 654408.82 2435.39 12.00 270.01 MWD 11175.00 89.95 17.94 8985.98 1691.62 1801.59 5975620.82 654416.65 2458.63 12.00 270.01 MWD 11200.00 89.95 14.94 8986.00 1715.60 1808.66 5975644.93 654423.24 2481.37 12.00 270.01 MWD 11225.00 /89.95 11.94 8986.02 1739.91 1814.48 5975669.35 654428.55 2503.53 12.00 270.02 MWD 11250.00 89.95 8.94 8986.05 1764.49 1819.01 5975694.02 654432.58 2525.06 12.00 270.02 TO SP Amoco WEll.PATH DETAILS Ptan#'! F-2&A 500292'1$491>1 ParenfWellp1llth: F·23 Tie Oft MÞ: 9100,0& Rig; 29' 28 9/1$119&6 00:00 Ref. Datum: II ..section ~~~ ~~~l; :=~ ..... 41.00' O.CO 0.00 31.20 REFERENCE !NFORMATION Inc. MIll .... ,... ,... I.\S9 ).13 ..., M!% U!3 .... '" ANNOTATIONS ..... fltD . . MftOtatwll Plan: Plan #1 (F-28/PJan#1 F-28A) Created By: Digital Business Client UserDate: 4/21/2004 Azimuths to True North Magnetic North: 25.27' Magnetic Field Strength: 57588nT Dip Angle: 80.87' Date: 4/21/2004 Model: bggm2003 1750 1800 1850 1900 1950 2000 2050 2100 at 41.00· [50ft/in] '2'8. ~81 It) .....8 .r: ..... ~875cr' GI Q8. DATE 3/2/2004 CHECK NO. 055266 p055266 DATE VENDOR DISCOUNT NET INVOICE I CREDIT MEMO DESCRIPTION GROSS 3/2/2004 PR022604H e PERMIT TO DRILL PPLlCATIONS H POUCH TO TERRI UBBLE MB7-5 -')~) , + ,{...·....)/...A. .C·.·1 C'((,..4 - \.. \; f-.-,Z,.F RECE\V 0 APR 2 2 20 4 Commission Alaska Oil & Gas ons. Anchorage TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. NATIONAL CITY BANK Ashland, Ohio No. P 055266 BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 . PAY: TO THE ORDER OF: 56-389 4"i2 CONSOLIDATED COMMERCIAL ACCOUNT WEST 7TH AVENUE SUITE ANCHORAGE AK 99501 B'P r. ~l"· ;1111) . ........ . _ - _ -D--. ...'1...,1 .-e- . .... .It V 1110 5 5 2 b b III ~ ~ 0 L. ¡. 2 0 j a c:¡ 5 I: 0 ¡. 2 ? a c:¡ b liD . . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERIP ARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# Development Service Exploration Stratigraphic CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing weD , Permit No, API No. . (If API number Production.sbould continue to be reported as last two (2) digits a function 'of tbe original API number. stated are between 60-69) above. Pll..OT BOLE In accordance witb 20 AAC 25.005(0, all (PH) records, data and logs acquired for tbe pilot bole must be clearly differentiated In both name (name on permit plus PH) and API Dumber (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject ·to fuD EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of ~ conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing .exception that may occur. DRY DITCH AU dry ditch sample sets submitted to the SAMPLE Commission must be in no greater tban 30' sample intervals from below tbe permafrost or from where samples are first caugbt and 10' sample intervals through target zones. óJ!S Geologic Commissioner: 4(?J{~ 35 36 37 38 39 Date: .S~abedconditioo survey CQntact Engineering Commissioner: nam.elphOl1eJor Date Appr RPC Date 4/22/2004 (if Off-shß(e) .S~isOlicanalysjs Qf sbaJlow gaszooes. p~Ol}it .D.ata.preseoted 011 potential oveJpressur~ .zOl1es No. NA .NA Geology Appr WGA Date 4/23/2004 21 22 23 24 25 26 27 28 29 30 31 32 33 34 can be issued wlo hYdrogen. sulfide OleaS.U(es Js presence oJ H2S gas prob.able Mecba.nicaLcoodjtjon of weUs within ,ll.OR yerified (For service w~ onJyJ incomOlents) C.hoke.llJanifold cQmpJies w/APl RF'-53 (May 84) WQrk will occur witholltoperation .shutdown .BOPEs,.d.o .they meet reguJation .BOPE.press raiing appropriate; .test to (puJ psig DJilliog fluid program schematic.&. e~uip Jfdiverter Jeq.uired. dQes be~n apPJoved for Adequ<itetal1kage.or re.serve pit .C.asing de.signs adeClIa.te C,T, B.&.permafr.ost 18 19 20 .CMT vßI adeQ uate. to .CMTwill coyer.all .Cßndu.ctßr stril1gpJovided .S.urface .casingpJQtects all knowl1 USDWs .CMT vol adequate. to circ.u late. o.n .conductor Jtare-drill~ hasa. to,.403 fQr abandol1ment Adequ<ite well bore separatio.n .proposed iLme~t istadequat~ reguJations. known -p(o.ductiYe hQri¡!:ons tie-in JQng .string to surf csg. & surfcs9 NA NA NA .NA Y~s Yes Y~s Yes .Y~s NA Yes Y~s y~s Yes .Y~s y~s NA Wppm. Test to .3500 psi. .MSF' 22.00 psi. Sidetraçk. Max MW8~ 7. ppg.. CTDU. 4/22/20.04. Engineering . Appr RPC Date 4/22/2004 .U.nique welln.am~.and oumb.er IQcat~d Administration 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 .AII wel)s. within .1 14. l1Jile.area.of reyiew id~otjfied (For servjce well only) Pre-produced injector; duratiQn.of pre-productioo I~ss thal13 montbs. (For.service well only) .ACMP. F.il1djngof COl1sisteocyhas bee.n issued. for. this prolect We.!1 JQcated wiihil1 area al1d.strata authorized by.lnjectioo Ord~r # (put 10# in COOlm~lJts). (For Can permit be approved before 15-day wait .Operator P~rmit can be issued witbQut P~rmit c.an be issued withQut ad.ministratille. apprßval has.appropriate. bond inJQrce co.nserva.tion order Operator .distance distaoce tbeJ .S.ufficienLacreage.ayailable ,,, u, "."'.1 Jfd~viated, incJu.ded wells :n ..Ir''''ng unjt WeU Wedl Well JQcat~d proper IQcated proper from driJIiog unitb.ound.arv. P~rmit fee attached .Leas~ .number .appropriate in.a. d.efined pool PRUDHOE BAY, PRUDHOE OIL N~ only affected party js we.!lbQre plat 640150 Initial ClassfType y~s Y~s .Y~s Yes y~s y~s Y~s y~s y~s No. Y~s Yes Yes .NA NA NA NA DEV WeU Name: PRUDHOE. BAY UNITF-28A /1-0IL GeoArea _89º Unit 11650 Program DEV On/Off Shore On Well bore seg D Annular Disposal D e e 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. e e C:<o cf-oft;<¡ R. ·E··C·E (2~~Ç, ,IVED Sperry-Sun Drilling Services LIS Scan Utility f"'.cn ,'ì ('¡ "iV' ' ;::';-~J- L. Cì {~~ t; V 4 $Revision: 3 $ LisLib $Revision: 4 $ Mon Sep 20 14:02:33 2004 Uil ¿~ Gas Cons, (;ormms..~¡(jf Reel Header Service name.... .........LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 04/09/20 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name................UNKNOWN Continuation Number......Ol Previous Reel Name.......UNKNOWN Comments.................STS LIS Writing Library. Scientific Technical Services Tape Header Service name.............LISTPE Date.....................04/09/20 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 F-28A 500292164901 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 20-SEP-04 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0003079250 S. LATZ HILDRETH/KOL MWD RUN 2 MW0003079250 B. JAHN KOLSTAD 1 HO MWD RUN 3 MW0003079250 B. JAHN KOLSTAD 1 HO # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 2 UN 13E 2359 2193 66.70 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.250 4.500 8390.0 # REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . e e 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 9069'MD AND THE BOTTOM WAS AT 9079'MD IN THE ORIGINAL F-28 WELLBORE. 4. MWD RUN 1 COMPRISED DIRECTIONAL WITH NATURAL GAMMA RAY (PCG) UTILIZING SCINTILLATION DETECTORS. TIE-IN SGRD DATA WERE ACQUIRED PRIOR MWD RUN 1. THESE MAD PASS DATA WERE MERGED WITH MWD DATA FROM RUN 1. 5. MWD RUNS 2 AND 3 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 IEWR4). A MAD PASS WAS RUN AFTER RUN 2 TO ACQUIRE RESISTIVITY DATA OVER THE RUN 1 INTERVAL. THESE MAD PASS DATA WERE MERGED WITH THE RUN 2 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY LOG RUN ON 22 MAY 2004. THESE DIGITAL DATA WERE PROVIDED BY K. COONEY ISIS/BP) VIA E-MAIL ON 17 SEPTEMBER 2004. LOG HEADER DATA RETAIN ORIGINAL DEPTH REFERENCES. 7. MWD RUNS 1 - 3 REPRESENT WELL F-28A WITH API#: 50-029-21649-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 10819'MD/8983'TVDSS. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SGRD SMOOTHED NATURAL GAMMA RAY. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) . SESP = SMOOTHED PHASE SPACING I . SEMP = SMOOTHED PHASE SPACING) . SEDP = SMOOTHED PHASE SPACING I . SFXE = SMOOTHED FORMATION EXPOSURE TIME. $ SHIFT-DERIVED RESISTIVITY ( SHALLOW SHIFT-DERIVED RESISTIVITY (MEDIUM SHIFT-DERIVED RESISTIVITY (DEEP File Header Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/20 Maximum Physical Record..65535 Fil e 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 FET RPD RPM RPS RPX ROP '" 1 and clipped curves; all bit runs merged. .5000 START DEPTH 8600.5 9080.5 9080.5 9080.5 9080.5 9080.5 9095.0 STOP DEPTH 10769.5 10783.0 10783.0 10783.0 10783.0 10783.0 10815.5 e e # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 8600.5 8602.0 8611.0 8613.5 8614.5 8617 .5 8619.0 8624.0 8626.0 8630.0 8632.5 9066.0 9072.0 9076.5 9078.0 9080.5 9083.0 9087.0 9099.5 9102.0 9104.0 9110.0 9113.5 911 7.0 9122.0 9130.0 9137.5 914 8.0 9151. 5 9156.0 9162.5 9169.5 9172.5 9176.5 9200.0 9201.5 9210.0 9212.0 9220.5 9223.0 9226.5 9236.0 9239.5 9241. 5 9251.0 9259.5 9268.5 9270.5 927 5.5 9284.5 9296.5 9300.5 9303.5 9309.5 9315.5 9320.5 9329.0 9332.5 9336.5 9348.0 9354.5 9361.0 9369.5 9375.0 9391. 5 9397.5 9402.0 9410.5 9418.5 9446.0 GR 8599.5 8601. 0 8610.0 8612.0 8613.0 8616.5 8618.0 8624.0 8625.0 8629.5 8633.0 9063.5 9069.5 9076.0 9077.5 9079.0 9080.5 9086.0 9097.5 9099.5 9102.5 9109.5 9111.5 9115.5 9121.0 9130.5 9137.5 9146.5 9149.5 9152.5 9157.0 9166.0 9169.0 9174.0 9198.5 9200.0 9207. 0 9211.0 9219.0 9221.5 9224.5 9234.5 9238.0 9239.5 9249.0 9258.0 9267.0 9269.5 9274.5 9283.0 9295.5 9299.0 9302.5 9309.0 9315.0 9319.5 9328.0 9331.0 9334.0 9344.5 9352.0 9359.0 9366.5 9371.5 9390.0 9395.5 9400.0 9408.0 9414.0 9443.5 e e 9455.0 9450.0 9460.5 9455.0 9462.5 9457.5 9466.5 9461.5 9477 . 0 9471. 0 9483.0 9480.5 9501.5 9499.5 9517.0 9515.5 9526.5 9526.0 9565.0 9564.5 9591. 5 9592.5 9596.0 9596.5 9604.0 9604.0 9607.5 9606.5 9621. 5 9621.0 9628.5 9626.0 9646.0 9644.0 9673.5 9672.5 9679.5 9679.0 9687.5 9686.5 9700.5 9698.5 9712.0 9713.0 9720.0 9720.5 9737.5 9736.0 9756.5 9754.5 9766.0 9764.5 9772.5 9770.0 9774.0 9772.0 9776.0 9775.5 9788.0 9786.0 9803.5 9806.0 9806.5 9809.5 9828.0 9826.5 9841.5 9843.5 9844.0 9845.5 9850.0 9849.5 9855.5 9854.0 9864.0 9863.5 9873.5 9874.5 9889.5 9891. 0 9898.5 9899.5 9920.5 9920.0 9951. 5 9952.0 9958.5 9961.5 9961. 5 9963.5 9978.5 9979.5 9987.5 9993.5 9999.5 10003.0 10004.5 10009.0 10011.5 10013.5 10016.0 10019.5 10026.5 10030.0 10034.0 10036.0 10036.5 10041.0 10043.0 10048.5 10058.5 10064.5 10066.0 10070.0 10074.5 10078.5 10090.0 10094.0 10101. 0 10104.5 10111.0 10115.0 10125.5 10132.5 10133.0 10139.0 10140.0 10147.0 10144.5 10149.5 10159.0 10163.5 10163.0 10166.0 10170.0 10172.5 10176.0 10178.0 10189.5 10191.5 10211. 5 10216.0 10227.5 10236.0 10235.5 10241.5 10239.5 10246.5 10250.5 10256.5 e e 10256.0 10267.0 10279.0 10284.5 10292.0 10300.0 10307.0 10310.0 10314.0 10339.5 10350.5 10362.5 10371.5 10377.5 10385.0 10393.0 10398.5 10400.5 10414.5 10422.5 10426.5 10430.0 10442.5 10466.0 10482.0 10506.0 10518.0 10527.0 10530.0 10535.0 10546.5 10550.5 10560.5 10569.0 10582.5 10591.5 10601. 5 10605.5 10609.5 10612.5 10623.0 10628.5 10634.5 10639.0 10649.5 10655.5 10672.5 10676.0 10680.0 10683.5 10685.5 10690.5 10694.0 10698.5 10815.5 $ 10262.0 10272.0 10284.0 10291.0 10300.0 10308.5 10314.5 10316.5 10319.0 10341.5 10353.0 10365.5 10373.5 10382.5 10388.5 10398.0 10400.5 10403.0 10415.0 10426.5 10429.5 10434.5 10447.5 10470.5 10489.5 10512.5 10521.5 10528.5 10533.0 10537.0 10550.0 10553.0 10565.0 10572.0 10584.0 10593.0 10603.0 10606.5 10612.0 10614.5 10625.0 10631. 5 10637.0 10643.0 10651. 5 10658.0 10672.5 10676.5 10679.5 10685.0 10688.0 10692.5 10697.0 10702.0 10819.0 # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ BIT RUN NO 1 2 3 MERGE TOP 8599.5 9370.5 10566.0 MERGE BASE 9370.5 10566.0 10819.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing.....................60 .1IN Max frames per record.............Undefined e e Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. . .0 Name service order Units Size Nsam Rep code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 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 8600.5 10815.5 9708 4431 8600.5 10815.5 ROP MWD FT/H 0.32 2406.18 113.583 3442 9095 10815.5 GR MWD API 14.01 995.06 46.6256 3485 8600.5 10769.5 RPX MWD OHMM 1.11 777.03 10.0653 3406 9080.5 10783 RPS MWD OHMM 1. 62 1274.43 11.0893 3406 9080.5 10783 RPM MWD OHMM 1.16 1768.36 11.9802 3406 9080.5 10783 RPD MWD OHMM 1. 34 2000 14.1349 3406 9080.5 10783 FET MWD HOUR 0.16 19.19 3.07257 3406 9080.5 10783 First Reading For Entire File..........8600.5 Last Reading For Entire File...........10815.5 File Trailer Service name.............STSLIB.OOl Service Sub Level Name... Version Number...........1.0.0 Date of Generation.......04/09/20 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...........l.0.0 Date of Generation.......04/09/20 Maximum Physical Record..65535 Fi 1 e Type................ LO Previous File Name.......STSLIB.OOl 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. 1 .5000 START DEPTH 8599.5 9093.5 STOP DEPTH 9340.0 9370.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): 18-MAY-04 Insite 7.75 Memory 9370.0 e 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 PCG $ BOTTOM) TOOL TYPE Natural 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.................. 0 Data Specification Block Type.....O Logging Direction.................Down Optical log depth units...........Feet Data Reference Point..............Undefined Frame Spacing..................... 60 .1IN Max frames per record.............Undefined Absent value...................... -999 Depth Uni ts. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order DEPT ROP MWDOI0 GR MWDOI0 Units FT FT/H API Size 4 4 4 Nsam Rep 1 68 1 68 1 68 Code 9093.0 9370.0 24.0 77.8 TOOL NUMBER TLG011 4.250 8390.0 KCL Brine 8.70 65.0 9.5 25000 6.4 .000 .000 .000 .000 Offset o 4 8 Channel 1 2 3 e .0 141. 7 .0 .0 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8599.5 9370.5 8985 1543 8599.5 9370.5 ROP MWDOlO FT/H 0.42 1578.24 67.1197 555 9093.5 9370.5 GR MWDOI0 API 14 995.06 38.494 634 8599.5 9340 First Read~ng For Entire File..........8599.5 Last Reading For Entire File...........9370.5 File Trailer Service name.............STSLIB.002 Service Sub Level Name... Version Number........ ...1.0.0 Date of Generation.......04/09/20 e 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...........l.O.O Date of Generation.......04/09/20 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 e header data for each bit run in separate files. 2 .5000 START DEPTH 9079.0 9079.0 9079.0 9079.0 9079.0 9340.5 9371. 0 STOP DEPTH 10533.5 10533.5 10533.5 10533.5 10533.5 10520.0 10566.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # 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: 19-MAY-04 Insite 4.3 Memory 10566.0 9370.0 10566.0 83.1 97.7 TOOL NUMBER 78012 171170 4.250 8390.0 Flo Pro 8.70 65.0 9.0 23000 5.2 .220 .100 .200 .230 70.0 162.7 70.0 70.0 e e 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 MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9079 10566 9822.5 2975 9079 10566 ROP MWD020 FT/H 0.32 2406.18 118.794 2391 9371 10566 GR MWD020 API 23.95 171. 01 49.6793 2360 9340.5 10520 RPX MWD020 OHMM 1.11 777 .03 10.0461 2910 9079 10533.5 RPS MWD020 OHMM 1. 62 1274.43 10.9836 2910 9079 10533.5 RPM MWD020 OHMM 1.16 1768.36 11. 7 091 2910 9079 10533.5 RPD MWD020 OHMM 1. 34 2000 13.8261 2910 9079 10533.5 FET MWD020 HOUR 0.16 19.19 3.29451 2910 9079 10533.5 First Reading For Entire File..........9079 Last Reading For Entire File...........l0566 File Trailer Service name... ..........STSLIB.003 Service Sub Level Name... Version Number...........l.0.0 Date of Generation.......04/09/20 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...........l.0.0 Date of Generation.......04/09/20 Maximum Physical Record..65535 File Type................ LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD e e header data for each bit run in separate files. 3 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ START DEPTH 10520.5 10534.0 10534.0 10534.0 10534.0 10534.0 10566.5 STOP DEPTH 10773.0 10786.5 10786.5 10786.5 10786.5 10786.5 10819.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TO DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE GM EWR4 $ BOTTOM) TOOL TYPE Dual GR ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH 1FT): # 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 20-MAY-04 Insite 4.3 Memory 10819.0 10566.0 10819.0 88.6 93.2 TOOL NUMBER 78012 171170 4.250 8390.0 Flo Pro 8.70 60.0 9.1 23600 5.8 .180 .080 .190 .160 69.0 165.8 69.0 69.0 e e 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 10520.5 10819 10669.8 598 10520.5 10819 ROP MWD030 FT/H 9.33 948. 91 144.415 506 10566.5 10819 GR MWD030 API 22.81 134.63 41. 7262 506 10520.5 10773 RPX MWD030 OHMM 3.8 12.06 8.46856 506 10534 10786.5 RPS MWD030 OHMM 5.28 11. 58 8.76854 506 10534 10786.5 RPM MWD030 OHMM 5.66 11.46 8.90842 506 10534 10786.5 RPD MWD030 OHMM 6.95 13.05 9.45039 506 10534 10786.5 FET MWD030 HOUR 0.26 9.37 1. 69624 506 10534 10786.5 First Reading For Entire Fi1e..........10520.5 Last Reading For Entire File...........10819 File Trailer Service name.............STSLIB.004 Service Sub Level Name... Version Number...........l.O.O Date of Generation.......04/09/20 Maximum Physical Record..65535 File Type................ LO Next File Name...........STSLIB.005 Physical EOF Tape Trailer Service name.............LISTPE Date.....................04/09/20 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.. ...................04/09/20 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