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205-158
i • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. t~~~ - ~ ~ g Well History File Identifier Organizing (done) ^ Two-sided III Ilillllllli ~~III ^ Rescan Needed III II~III II II III III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: ~skettes, No. ~ ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ D /s/ Project Proofing II I II II II V III I I III BY: Maria Date: ~., /~ ~ 8 /s/ / Scanning Preparation ~_ x 30 = ~ + ~ =TOTAL PAGES h (Count does not include cover sheet) BY: ~ Maria Date: ~''`j I l ~ lsl ~, Production Scanning Stage 1 Page Count from Scanned File: __~~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria Date: ~, t ~ O $ /s/ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III (I'I II III II I I III ReScanned II I II II II I I III V III BY: Maria Date: /s/ Comments about this file: Quality Checked III I~IIII III II'I III 10/6/2005 Well History File Cover Page.doc • • RECEIVED STATE OF ALASKA SEP 1 1 2012 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT ANIi1Q CC 1 a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1 b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 8/17/2012 205 - 158 312 - 169 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 11/5/2005 50 029 - 20124 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 11/11/2005 PBU C -03B 1316 FNL, 879' FEL, SEC. 19, T11N, R14E, UM 8. KB (ft above MSL): 63.66' 15. Field / Pool(s): Top of Productive Horizon: 651' FSL, 1770' FWL, SEC. 17, T11N, R14E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 395' FSL, 257' FWL, SEC. 17, T11N, R14E, UM 9610' 8552' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 664500 y- 5959906 Zone- ASP4 11635' 8996' ADL 028305 TPI: x- 667098 y- 5961931 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 665591 y - 5961641 Zone- ASP4 None 18. Directional Surve : 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): y ❑ Yes ®No A (Submit electronic and printed information per 20 AAC 25.050) N/ ft MSL 1900' (Approx.) ) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/ VD: MWD DIR / GR / RES, DIR / GR / RES / DEN / NEU 8202' 7342' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE ToP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" Insulated Conductor Surface 80' Surface 80' 36" 484 sx Cement 18 -5/8" 139#/109#/96.5# K -55 Surface 2524' Surface 2524' 24" 4700 sx Permafrost 11 13 -3/8" 72# / 68# L - 80 / N -80 Surface 4331' Surface 4180' 17" 1210 sx Class 'G', 950 sx PF II 9 - 5/8" 40# / 47# L -80 / N - 80 Surface 8202' Surface 7342' 12 -1/4" 4670 sx Class 'G', 619 sx Class 'G' 7" 26# L -80 8054' 9410' 7216' 8365' 8 -1/2" 275 sx Class 'G' 4-1/2" 12.6# L -80 9250' 11630' _ 8229' 8997' _ 6-1/8" 290 sx 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) 4 -1/2 ", 12.6 #, L -80 9261' 9205' / 8191' MD TVD MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED $ r: ;?_iii?: 9610' 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 ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None �^ ORIGINAL !� ReDAAS SEP 1 3 Z �'0k1 Form 10 -407 Revised 12/2009 R <8 CONTINUED ON REVERSE q � /� Submit Original Only/' 129. GEOLOGIC MARKERS (List all formations a arkers encountered): 30. FORMATION TESTS NAME D TVD Well Tested . Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top HRZ 8405' 7516' None Base HRZ 8647' 7722' Sag River 9415' 8369' Shublik 9459' 8407' Sadlerochit 9540' 8483' Top CGL 9691' 8632' Base CGL 9785' 8722' 23SB / Zone 2B 9832 8766' 22TS 9905' 8833' 21 TS / Zone 2A 9979' 8895' Zone 1B 10090' 8967' TDF / Zone 1A 10238' 9009' Formation at Total Depth (Name): 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the -•oing is rue P orrect to the best of my knowledge. Signed: Joe Lastufka , �-� Title: Drilling Technologist Date: PBU C - 03B 205 - 158 312 - 169 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Zach Sayers, 564 -5790 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • • C -03B, Well History (Pre Rig Sidetrack) Date Summary 05/19/12 TAGGED 4 -1/2" BAKER ROCKSCREEN AT 9,224' SLM / 9,249' MD (No issues). JARRED FOR 2 HRS AT 1800 -2000# ON 4 -1/2" BKR ROCKSCREEN AT 9,224' MD (No movement). RAN EQUALIZING PRONG TO 4 -1/2" EQ DEVICE IN XN LOCK AT 9,249' MD (No pressure change). JAR FOR 3 HRS (5 hrs total) AT 1800 - 2000 #'S ON 4 -1/2" BKR ROCK SCREEN AT 9,216' SLM (Moved uphole —8'). 05/20/12 JAR FOR 2 HRS (7 hrs total) @ 1800 - 2000 #'S ON 4 -1/2" BAKER ROCK SCREEN @ 9,216' SLM (No movement). RIG DOWN SLICKLINE AND RIG UP BRAIDED LINE. PULLED 4 -1/2" x 25' BAKER ROCK SCREEN FROM 9,188' BLM (Missing 8" of the outer layer of the screen). UNABLE TO PASS 9,166' BLM W/ 3.70" x 20' DUMMY WHIPSTOCK (3" scratch on bottom of whipstock). CURRENTLY RIGGING DOWN BRAIDED LINE & BACK UP SLICKLINE. 05/21/12 MADE SEVERAL ATTEMPTS TO FISH 8" SCREEN SECTION OF ROCKSCREEN. DRIFT TO 9,800' SLM W/ 3.70" x 20' DUMMY WHIPSTOCK, 3.675" JUNK BASKET (No recovery / Target 9,800'). 06/03/12 INITIAL T /I /O = 250/0/50. ATTEMPT TO MILL NIPPLE AT 9249'. MILLING TOOL BECAME STUCK IN NIPPLE AT 9249'. DECISION MADE TO BREAK WP AFTER SEVERAL ATTEMPTS TO WORK TOOL FREE WITH MILLING PISTON / MOTOR UNSUCCESSFUL. WP BREAK AT 4400LBS. POOH. 06/04/12 FISHED WELLTEC MILL ASSEMBLY FROM XN NIP @ 9200' SLM (wire from rock screen stuck in tool). RAN 4 -1/2" BRUSH & 3.70" GAUGE RING TO 9850' SLM (recovered one 5" piece of wire from rock screen). RAN 3.70" x 20' DUMMY WHIPSTOCK TO 9850' SLM (no restrictions). RAN 3.805" DRIFT TO XN NIP @ 9225' SLM/9249' MD (had to tap through both x- nipples). 06/05/12 T /IA /OA= 0/40/460. SSV,SWAB= CLOSED, IA/OA =OTG. RIH W/ ELINE TOOLS & WELLTEC MILLING TOOL - MILLED XN (5 9249' MD TO 3.805" O.D. SWAB,SSV= CLOSED, IA/OA =OTG. FINAL T /IA/OA = 80/50/400. LAYED EQUIPMENT DOWN FOR NIGHT & WILL RETURN IN AM TO SET 1 WHIPSTOCK. 06/06/12 (ELINE WHIPSTOCK) INITIAL T / IA/OA= 0/0/700. RIH W/ SLB ELINE TOOLS W/ BAKER 45KB WHIPSTOCK PKR (WIHPSTOCKS CONTAINS 2 RA PIP TAGS). SET TOP OF WHIPSTOCK @ 9610' - TOOL ORIENTATION 14 DEG LEFT OF HIGH SIDE. SWAB CLOSED, SSV CLOSED. FINAL T /IA/OA= 0/ 680/ OPSI. 06/11/12 T /I /O /00A= 0/0/500/0 Temp =SI MIT -T to 2400 psi (PASSED) (CTD prep) Pumped 11 bbls 40* diesel down tbg to reach test pressure. 1st 15 min lost 89 psi. 2nd 15 min lost 33 psi for a total loss of 122 psi in 30 min. Bled TP ( -2 bbls) Tags hung, DSO notified. Valve positions upon departure: SV WV SSV= closed. MV IA OA 00A= open FWHP= 0/0/500/0. 06/16/12 T /I /O = 45/0/0. Conduct PJSM. PT'd tree cap to 500 psi. (passed) against Swab valve prior to removal of tree cap. Rigged up lubricator with 1 -1' ext. and CIW TWC # 279. PT'd lubricator to 250 psi. low for 5 min. (passed) and 3500 psi. high for 5 min.(passed), using Swab valve and SSV as barriers. Set TWC tagging at 114 ". Bled off TWC. Closed SSV and SV. Rigged down lubricator and attached CIW pulling tool. Rigged up lubricator and torqued all tree flanges to API specs, (see log). PT'd lubricator (using same barriers and procedure, passed). Opened all valves and ran polish rod to approx. 6 " above TWC. PT'd tree to 250 psi. low for 5 min. (passed) and 4750 psi. (max. amount per PT. equipment) high for 5 min. (passed). Pulled TWC tagging at 114 ". Rigged down lubricator. PT'd tree cap to 500 psi. (passed). Swab valve tests and Shell tests charted and documented. Page 1 of 2 • • C -03B, Well History (Pre Rig Sidetrack) Date Summary 08/13/12 T /1 /0= 0 +/0/300/0. Temp= SI. Hold open bleed on OA (Pre -CTD). OA cemented to surface. OAP increased 170 psi in last 7 hours. Bled OAP from 300 psi to 0+ psi in 5 minutes (all gas). Maintained open bleed on OA for 6 hours. Shut -in bleed and monitor for 30 minutes, OAP increased 40 psi. Final WHPs= 0 +/40/0. 08/13/12 T /I /O /OO = 16NAC/450/0. Temp = SI. Bleed WHPs to 0 psi (Pre CTD). Flowline and AL lines disconnected. OOA reading taken from Ops gauge, OOA jewelry below cellar floor and cellar is 60" deep. TBG FL near surface, OA cemented to surface. Bled OAP from 450 psi to 0 psi in 2 min (all gas) and held open bleed for 1 hr. Bled TP from 16 psi to 0 psi in 5 min and held open bleed for 30 min. During TP bleed OAP increased 200 psi, bled OAP from 200 psi to 0 psi in 1 min (gas) and held open bleed for 2 hrs. Monitored for 30 min, OAP increased 130 psi. Job incomplete. Final WHPs = ONAC /130/0. SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. NOVP. 13:00 hrs. 08/14/12 T /I /O /OO =SSV /0/200/0. Temp = SI. Hold open bleed on OA. (CTD Prep). OA FL = Cement to surface. Well house & flowline removed. Bled OAP from 200 psi to 0 psi in 2 minutes (all gas), maintain open bleed till end of shift. Held open bleed for 3 hours, rig down for end of shift, Valve crew installing double OA casing valves. Final WHP's = SSV /0/0/0, no monitor done. Night shift to continue open bleed. SV, WV, SSV = C. MV = 0. IA, OA & OOA = OTG. 08/15/12 T /I /0 =0/0/0 Conducted PJSM. Performed LTT on both OA valves. Pass. Removed blinds, piggy backed both side OA valves, torqued all flanges to specs. Shell tested both sides against inner valves. (see charts in TRP folder) 250 /Iow..3500 /high..5 min each, pass. Pre Nordic 1. 08/15/12 T /I /0 /00 = SSV /0/160/0. Temp = SI. Hold open bleed on OA (Pre CTD). OA cemented to surface. Wellhouse and flowline removed. Bled OAP from 160 psi to 0 psi in 2 minutes. (All gas). Maintained open bleed on OA for 4 hours. Shut in bleed and monitored for 30 minutes. OAP increased 50 psi in 30 minutes. Final WHP's = SSV /0/50/0. SV, WV, SSV = C. MV = 0. IA, OA, OOA = OTG. NOVP. 04:45 hrs. Page 2 of 2 ■,. ' 0 • , / ;V‘, 4/00,-;,-- i,: ; ,‘..4,04.: ,,/..//,4 ,..„.,e 0),,,W,) 7.0C/01W 7p ::i:< ,, 44: ..,:; , . -.4 , %.4t ',,,,,,x,„ / 0,4-72 ; ‘,-,,,,tz< i , :/ , : y.: 4 ./ ,,,-,, ',..-/MLUS,--.//...:';' ,,,:'2,%///dY•,W4 / , , // ,/ ///,,f , " /2•,,, d„ ',.,/,' ///,,, ', // , i/ // ,;,-, ,,/ / / ,/, , , / , Common Well Name: C-03 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 8/16/2012 End Date: X3-0124X-C: (3,127,117.95) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 2/13/1973 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070°17'48.375"5 Long: 0148°40'04.275"W Active Datum: ORIG KELLY BUSHING @54.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 8/16/2012 04:00 - 05:00 1.00 MOB P PRE MOVE RIG TO C-03. DOUBLE CHECK OA PRESSURE (20PSI) - BLEED DOWN. 05:00 - 06:30 1.50 MOB P PRE MOVE RIG OVER WELL C-03. RIG ACCEPTED AT 05:30AM. 06:30 - 08:30 2.00 BOPSUR P PRE PJSM. RIG UP TO TEST FOR REMOVING TREE CAP. CLOSE MASTER, SSV AND SWAB VALVE. TEST SWAB THROUGH WING VALVE TO 250 PSI LOW AND 3500 PSI HIGH FOR A LEAK TIGHT TEST. BLEED OFF PRESSURE AND OBSERVE NO LEAKS PAST SSV - PASS. 08:30 - 09:00 0.50 BOPSUR P PRE PJSM. RIG UP IA AND OA CRASH CAGES. 09:00 - 12:00 3.00 BOPSUR P PRE PJSM. NIPPLE UP BOP. 12:00 - 14:00 2.00 BOPSUR P PRE PJSM. RIG UP GREASE CREW AND GREASE CHOKE MANIFOLD AND STACK FOR BOP TESTING. 14:00 - 00:00 10.00 BOPSUR P PRE PJSM. TEST BOP TO 250 PSI LOW, 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. TEST 2-3/8-IN COMB1S WITH 2-3/8-1N TEST JOINT. TEST 2-3/8" X 3-1/2" VARIABLES WITH 2-3/8" 1 0? AND 3-1/4" TEST JOINTS. TEST ANNULAR TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 ,/ y CHARTED MINUTES EACH WITH 2-3/8" TEST /V JOINT. PERFORM ACCUMULATOR DRAWDOWN TEST. NOTE STARTING ACCUMULATOR PRESSURE AS 3,100 PSI AND THE FINAL PRESSURE AFTER FUNCTIONING ALL PREVENTERS AND HCR = 2,200 PSI. SYSTEM TOOK 20SEC TO BUILD 200 PSI AND 91 SEC TO FULL PRESSURE. CHECKED THAT NITROGEN BACKUP BOTTLES HOLD 2,000 PSI. TEST WITNESS WAS WAIVED BY JEFF JONES WITH AOGCC. TEST WITNESSED BY , WSL'S MITCH SKINNER AND MATTHIAS KOENIG AND TOOLPUSHERS TOMMY KILFOYLE AND DAVE HILER. AT 18:00hrs - IA = OPSI / OA = 168PS1/ 00A = OPSI AT 00:00hrs - IA = OPSI / OA = 173PSI / 00A = OPSI 8/17/2012 00:00 - 01:30 1.50 BOPSUR P PRE CONTINUE BOP-TEST. 01:30 - 03:30 2.00 BOPSUR P PRE TAKE OFF NIGHT CAP AND PICK UP INJECTOR. TEST METHANE AND H2S ALARMS. MU SLB CTC, PULLTEST TO 35K LBS AND PRESSURE-TEST TO 300 / 5MINS AND 3,500PSI 5/MINS. CTC IS LEAKING, TAKE OFF AND MU NEW CTC. ACHIEVE GOOD TEST AND BLEED DOWN. Printed 9/4/2012 11:08:29AM • `` j °, , .�� j�/� "� / j © ,��� i / ,s ,f�, �o � , ,.,gar/.^. ./ ,/, ,�� �, �, ,_� .. T ,�, �, � 0" /Tx '���j, /,,/ ) / /,,o t �i .; l, � j v , , .v,,, i /� / /. /" 'i�v4 3 a�r .e '�,n / �. ar •,. Tifm e.�:j .,Af ` „ y ", ,q ,, �.,`.'�y x. ///,m /4 � / %' ',: '1'4 9 4(4 : � : / /� "- 4 ,% / �/^: i `fV/ /4 ‘,./i Common Common Well Name: C -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/16/2012 End Date: X3- 0124X -C: (3,127,117.95 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/13/1973 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'48.375 "5 Long: 0148°40'04.275'W Active Datum: ORIG KELLY BUSHING @54.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:30 - 04:30 1.00 BOPSUR P PRE STAB ON INJECTOR AND FLUID PACK REEL & LUBRICATOR. AT 04:00hrs - IA = OPSI / OA = 172PSI / OOA = OPSI 04:30 - 05:00 0.50 BOPSUR P PRE PERFORM PRESSURE -TEST ON INNER REEL VALVE, QTS AND PACK - OFF'S. 05:00 - 05:20 0.33 BOPSUR P PRE HOLD RIG EVACUATION ALARM. 05:20 - 06:30 1.17 BOPSUR P PRE PUMP SLACK FORWARD WITH 55BBLS. POP OFF LUBRICATOR AND EXPOSE 12' E -LINE CABLE. RIG DOWN AND PREP FOR BOP RAM LOCK TEST. 06:30 - 08:00 1.50 BOPSUR P PRE INSTALL NOZZLE ASSEMBLY. STAB ON WELL AND BREAK CIRCULATION. 08:00 - 10:30 2.50 BOPSUR P PRE HOLD PJSM. TEST MANUAL LOCK DOWNS ON BOP RAMS. FOR EACH RAM, CLOSE RAM, RUN IN LOCKS, CLOSE ACCUMULATOR, BLEED OFF HYDRAULIC PRESSURE THEN PRESSURE TEST FROM BELOW. BLEED OFF PRESSURE, BACK OUT LOCKS THEN OPEN RAMS. TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MINUTES EACH. TEST IN ORDER, LOWER 2 -3/8" COMBI, LOWER 2 -3/8" X 3 -1/2" VARIABLES AND UPPER 2 -3/8" COMBI WITH 2 -3/8" COIL. PULL COIL AND TEST BLIND SHEAR RAMS. ALL TESTS PASSED. 10:30 - 11:00 0.50 BOPSUR P WEXIT INSTALL TREE CAP AND PRESSURE TEST. 11:00 - 11:30 0.50 BOPSUR P WEXIT HOLD EVAC DRILL AND AAR. HOLD PRE -SPUD MEETING AFTER AAR. 11:30 - 13:00 1.50 STWHIP P WEXIT PJSM. RIG UP THEN HEAD UP COIL. TEST -PASS. 13:00 - 13:30 0.50 STWHIP P WEXIT PJSM. TEST CHECKS ON COIL HEAD - PASS. 13:30 - 14:30 1.00 STWHIP P WEXIT PJSM. PICK UP BHA TOOLS. MAKE UP DIAMOND WHIPSTOCK MILL AND DIAMOND STRING MILL TO STRAIGHT MOTOR, PH-6 AND COILTRAK TO 120'. 14:30 - 15:00 0.50 STWHIP P WEXIT MAKE UP INJECTOR AND TEST QUICK TEST SUB TO 250 PSI LOW, 3500 PSI HIGH - PASS. 15:00 - 17:30 2.50 STWHIP P WEXIT RIH AT 93 FEET PER MINUTE PUMPING AT 1.5 BARRELS PER MINUTE WITH 1018 PSI TO 9,460' MD. DISPLACE DIESEL FREEZE PROTECT FROM THE WELL ON THE FLY. 17:30 - 18:30 1.00 STWHIP P WEXIT DISPLACE KCL WITH 8.5 PPG MILLING FLUID WHILE LOGGING TIE -IN TO TOP OF WHIPSTOCK SLIDE AT 9,610' MD. TAG UP ON TOP OF WHIPSTOCK SLIDE AT 9,617' MD. CORRECTION OF MINUS 2 FEET. 18:30 - 20:00 1.50 STWHIP P WEXIT START MILLING THE WINDOW ONWARDS FROM 9,616.4'. TIME MILL WINDOW FOR C. COG FIRST FOOT AT 2.58 BPM WITH - 2,800PSI CIRC PRESSURE AND -0.5K LBS WOB. 20:00 - 20:20 0.33 STWHIP P WEXIT GRADUALLY INCREASE TO -2.5K LBS WOB. SEE STALL AT 9617.9' AT 2.85K LBS WOB / 2,816PSI CIRC PRESSURE. PICK UP AND TAKE SPR'S. j Printed 9/4/2012 11:08:29AM ,e g,i �/ /, �, f� // / / , / / //%y. °%% (,., r / gyp / / / /7/ , :f; b �L $Y /, /���/ %y.;; �„ �j� / �', />/ � % / /f� / „Y '�. �, , q 9` `. / "� N , //f`' � 6� � �,:� r / j / /f /, „ � . 7 ' / � . / , / c �� ® e / .../ x2, � '"!/f°� %% ��" , "*,.= , fir / / % %� / /,�F °; /% .r,�o- + '"` / / i / .r.. :Y'. , . 9 ; `�/ 5 ° � %.Y .ca..././- V , / s� • ,;,G/ a� iG.r./�r lf�� U � >� . /�,. ciE/ /� „r i�� / >:,rz•. °v:�j�i / �iii :�� r / iff',. 41/ l� � � ff � . ���' lf ' 1"� � / /// „,%.7,d''' . /�� /�:+r,5�,'�': /�' Common Well Name: C -03 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 8/16/2012 End Date: X3- 0124X -C: (3,127,117.95 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 2/13/1973 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'48.375 "5 Long: 0148 °40'04.275'W Active Datum: ORIG KELLY BUSHING @54.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:20 - 21:45 1.42 STWHIP P WEXIT PICK UP AND REVERT BACK TO TIME - MILLING TO ESTABISH MILLING PATTERN AGAIN AT PUMP RATE OF 2.56BPM AND 2.8K LBS WOB / 2,770 - 2,820PSI CIRC PRESSURE. 21:45 - 00:00 2.25 STWHIP P WEXIT CONTINUE TIME MILLING WINDOW. OBSERVE STEADY INCREASE IN WOB UP TO 2.96K LBS (CIRC PRESSURE = 2,850PS1) FOLLOWED BY A STEADY DECLINE IN WOB, THUS INDICATING THE WINDOW MILL "MID POINT'. 8/18/2012 00:00 - 00:40 0.67 STWHIP P WEXIT WOB DECREASES AND LEVELS OUT AROUND 1.56K LBS / 2,740PSI CIRC PRESSURE, WHICH INDICATES WINDOW MILL "EXIT POINT'. 00:40 - 01:20 0.67 STWHIP P WEXIT CONTINUE MILLING AHEAD AT SIMILAR WOB. 01:20 - 02:55 1.58 STWHIP P WEXIT OBSERVE AN INCREASE IN WOB ONWARDS FROM 9,620.5' INDICATING THE STRING REAMER ENTERING THE WINDOW. CONTINUE TIME MILLING WITH INCREASING WOB UP TO 2.32K LBS / 2,830PSI CIRC PRESSURE, FOLLOWED BY A DECLINE DOWN TO 1.8K LBS WOB / 2,800PSI CIRC PRESSURE AGAIN (EXIT OF STRING REAMER). 02:55 - 08:30 5.58 STWHIP P WEXIT START DRILLING 10' RATHOLE. CONTINUE DRILLING AHEAD WITH ROP = —1 -5 FPH, WOB = 3 -4K LBS AND CIRC PRESSURE = —3,000 PSI AT 2.62 BPM. PVT = 300 BBLS. MW IN = 8.62 PPG / MW OUT = 8.59 PPG / ECD = 10.15 PPG IAP = 740 PSI / OAP = 355 PSI / OOA = 65 PSI BACKREAM WINDOW 3 TIMES WITH SLIGHT MOTOR WORK ON FIRST RUN THEN DECREASING. DRY DRIFT WINDOW AFTER THIRD TIME WITH NO WEIGHT ON INDICATOR GOING THROUGH OR OVER PULL COMING UP. WINDOW APPEARS TO BE IN GOOD CONDITION. 08:30 - 09:00 0.50 STWHIP P WEXIT FLOW CHECK WELL FOR 10 MINUTES - STATIC. PULL UP INTO WINDOW. UP WEIGHT 36K, DOWN WEIGHT 17K. OPEN EDC. 09:00 - 10:30 1.50 STWHIP P WEXIT POOH AT 98 FPM TO BHA AT 192' MD. PUMP AT 2.6 BPM WITH 2200 PSI. MUD WEIGHT IN AND OUT 8.6 PPG. UP WEIGHT 29K. 10:30 - 11:30 1.00 STWHIP P WEXIT PJSM. FLOW CHECK WELL FOR 10 MINUTES - STATIC. LAY DOWN MILLING BHA FROM 192' MD. WINDOW MILL 3.78" NO -GO. STRING MILL 3.75” NO -GO. 11:30 - 12:30 1.00 STWHIP P WEXIT MAKE UP DRILLING BHA WITH 4 -1/4" SRH3211 M -C3 BI- CENTER BIT, 3 -1/8" LOW SPEED MOTOR WITH MWD TOOLS AND RIH TO 86' MD. Printed 9/4/2012 11:08:29AM TREE =' " 4-1/16" CM/ WELLHEAD = CIW SAF ROTES: WELL ANGLE > 70° a 10140'. 'fir/ ACTUATOR = BAKER C Initial WELLBORE(C -03) NOT SHOWN ON KB. ELEV = 54.46' DIAGRAM. BF. ELEV = 35.16' ' KOP 3000' $ Max Angle 94" @ 11603' i ° - 9941' itil i 4 ) i+ I 'Da tum MD = 2039' - a CEMENTER I Datum TVD = 8800' SS 2033 CSG I 80' ► �� t 2054' —19-5/8" SEAL ASSY I 11 -1/2" TBG IH 1814' i ii +4 it 2059' H13 -3 /8" X 9 -518" BOT PKR/ LNR HGR I ' . I TOP OF 9 -5 /8 ' . LNR I 2043' I4 41 11# '' I 2074' I— 9 -518" FOC 19 -5/8" CSG, 40#, L -80 BTC, ID = 8.835" H 2068' s, I I 2138' H13-318" FOC 1 ! 1 2206' -41/2" HESX NIP, ID =3.813" I 2332' H13-3/8" FOC I GAS LIFT MANDRELS 18-5/8" CSG, 96.5 #, K -55, ID = 17.655 " H 2524' ST MD TV O DEV TYPE VLV - LATCH 1 PORT DATE 4 3308 3295 18 MU DMY RK I 0 03(30/12 3 6120 5599 36 MMGM DMY RK 0 03130/12 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 4331' 2 8014 7182 31 MMGM DMY RK 0 11/13/05 Minimum ID = 3.725" @ 9249` 1 9114 8114 33 KGB2 DM' BK 0 11113/05 � 4-1/2" /2" HES XN N NIPPLE 4303' 1 9 5/8° FOG I 8054' I—I9 -5 /8" X 7" BKR C2 ZXP LW w /TIEBK SLV, ID = 6.30" 1 8071' H9 -5 /8" X 7" BKR HMC LNR HNGR, ID = 6.23" MILLOUT' WINDOW (C -03B) 8202' -8215' 9184' H4-1/2" HESX NIP, ID = 3.813" 'WHIPSTOCK (11/04/05) I 8142' 9205' —17" X 4-1/2" BKR PKR, ID = 3.875" I 9228' _I 14 -1/2" HESX NIP, ID= 3,813" 19 -5/8 " LNR, 47 #, N-80, ID = 8.681" I — 8202 9249' — 4 -1/2" HES XN NIP, MILLED TO 3.80" ( EZSV PLUG (10/31/05) I 8225' (06/05/12) _.... � — �iii 7 . v 9250' — x 5" BKR HRDZXP LTP "so. ■ �ii�i _ w /TIEBK SLV, ID= 4A1" 1: PTA 9261' 1 V11LEG I ii v • 9270' H RS PO NIP, ID = 4.25" I ' 9272' — 7" X 5" BKR HMC LNR HNGR, ID = 4.42" 1 N , 9279' — 5" X 4-1/2' XO, ID =3.960" PERFORATION SUMMARY 4-1/2' TBG, 12.6#, L -80 IBT- M/TCII, H 9261' I 1111 REF LOG: ? ? ? ?? ON ? ? / ? ? / ?? PBTD 11544' ANGLE ATTOPPERF: 86 °@ 10185' bpf, ID = 3.958 "!� ' 1 1 Nate: Refer to Production DB for historical perf data 7" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 9410', SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 10185 - 10210 0 07/18 /09 'BKR 45 KB PKR WHIPSTOCK (06106112) I 9610' 3 -3/8" 6 10210 - 10235 0 05/06/09 - 3 -3/8" 6 10255 - 10285 0 07/18109 2 -7 /8" 4 10320 - 11230 C 11/14/05 14-1/2" BKR CIBP (05/06/09) I 10297 1.;140) i 2 -7/8'" 4 11440 11530 C 11/13/05 ;,A. 13.50 BKR CIBP (04/13/08) 11360' ELM ‘11 1, 11 ,` 14 -112" LNR 12.6 #, L-80 IBT -M, .0152 bpf, ID = 3.958" IH 11630' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03126173 ORIGINAL COMPLETION 12/18/11 LEG PJC PULL PLUG/ ROCK SCREEN WELL: C-038 10105187 RWO 04/011 LEG PJC GLV G0 (03/30/12) PERMIT No: 10/14198 CTD SIDETRACK (C -03A) 04/10/12 NSIJMD AR CORRECTION (04 /05/12) API No: 50- 029- 20124 -02 11115/06 N4ES SIDETRACK (C-0313) 05123/12 CJN/JMD RILL ROCK SCREEN (05/20/12) SEC 19, T11 N, R14E, 1316' FNL & 879' FEL 10/31/11 CCU /JMD PX PLUG SET (10/28111) 06/11/12 JLS /JMD MILLED XN & SET WS (06/05- 06/12) 10/31/11 , RM/JMD ! TREE CIO (10130/11) I I BP Exploration (Alaska) I r „ t SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader yv BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C -03B Sundry Number: 312 -169 O MAY 1 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Cathy. Foerster ,� Chair DATED this F' day of May, 2012. Encl. -7s /S' `�- V E D • STATE OF ALASKA � ECEI ADSPA OIL AND GAS CONSERVATION COM SION MAY 012012 APPLICATION FOR SUNDRY APPROVAL ' 20 AAC 25.280 AOGCC _ 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 205458 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029 - 20124 -02 -00 • 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C-03B ' Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028305 - 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): 11635' 8996' - 11544' 9003' 10297', 11360' None Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2524' 18 -5/8" 2524' 2524' 930 870 Intermediate 4331' 13 -3/8" 4331' 4180' 4930 2270 Production 8202' 9 -5/8" 8202' 7342' 3580 2090 Liner 1356' 7" 8054' - 9410' 7216' - 8365' 7240 5410 Liner 2380' 4 -1/2" 9250' - 11630' 8229' - 8997' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10185' - 11530' 9002' - 9004' 4 - 1/2 ", 12.6# L - 80 9261' Packers and SSSV Type: 7" x 4 Baker Packer Packers and SSSV 9205' / 8191' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development - ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 15, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Zach Sayers, 564 -5790 Printed Name John McMullen Title Engineering Team Leader Prepared By Name/Number: • Signature � ( ��, jv i'" jtiL, Phone 564 - 4711 Date Joe Lastufka, 564 -4091 Commission Use Only (� Conditions of approval: tify Commission so that a representative may witness Sundry Number ?, I - 1 ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance v 3 5 0 6 r ©a S ,,,e) V----- �/ s - NO C Other: / L /G _ i d ) ` � A Z' -• A r r rt --k j � i j f 146 -Z-v 4C-P' Subsequent Form Required: /B *- "f L APPROVED BY Approved By: (44 COMMISSIONER THE COMMISSION Date 5— Form 10-403 Revi Ms MAY 0 9 qe....-01--er•—■ � � l z � S'��-f L \ Submit In Duplicate �v . , RIGIN 7. 6 . _ GIN AL • • To: Alaska Oil & Gas Conservation Commission bp From: Zach Sa Y ers CTD Engineer Date: April 27, 2012 Re: C -03B Sundry Approval Sundry approval is requested to plug the C -03B perforations as part of drilling the C -03 coiled tubing sidetrack. History of C -03. C -03B is a rotary sidetrack drilled in Nov 2005 and completed with 1,000' of perforations in Zone 1A/1 B. It produced fulltime until March 2007 when it began cycling - for high GOR. In April 2008, a CIBP was set at 11,360' MD to isolate the Z1 B toe perfs (11,440 - 11,530') for a gas shut -off, but the gas rate did not change. In May 2009, a CIBP was set at 10,297' MD to shut -off all Z1A lateral production, and 25' of Z1 B was shot near the heel. Based on the RST -sigma log also run during that job, the GOC had moved down to near the top of Z1 B and there were no oil lenses. In July 2009 an additional 55' of Z1 B were shot in the heel. C -03B produced fulltime for -4 months before cycling. After an RST log was run in Aug 2011, the well was brought back online and solids were found in the choke, so a rock screen was installed. C -03B is currently cycling with degrading - production and on -time. Reason for sidetrack. C -03B is no longer a competitive producer due to a high GOR, - and there are no remaining wellwork options. The proposed sidetrack will access reserves in a -42 acre Zone 1A target in eastern C -pad. Proposed plan for C -03C is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around August 15 2012. The existing perforations will be isolated by the primary cement job for the liner. The sidetrack, C -03C, will exit the existing 4 -W liner, kick off in Z4, and land in Z1A. This sidetrack will be completed with a 3 -1/4" x 2 -7/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. 1 o r & ® R I Con cif T� e sitiWecr l � f irdliCe5 ti ©� .3- --60 i�i Pu�i/ e ����� 6e , rid ells 0A f p rocike q C c /rc 'T/ ' Su; �'ncf /I 4ui' O � p 7 - 1 �r aye �J o" r4 p 611/ n� 7t �i'(� 1/ ®� rye JQwesr 04,7 ©�'� r �r� 6r /`gyp / {tee e i kem / 7 �® ®�- � f f Pre-Rig Work: • (scheduled to be inl 1a 15 2012 9 ( 9 Y 2012) 1: F MIT- IA to 3,000 psi, MIT -OA to 2,000 psi 2. W Cycle LDS; PPPOT- T to 5,000 psi 3. S Pull BKR Rock Screen from XN nipple at 9,249' MD 4. S Dummy WS Drift to 9,800'MD (17° Inc) 5. E Mill XN nipple at 9,228' to 3.80'✓ 6. F Load and Kill well with 1% KCI 7. E Set 4 -1/2" KB Whipstock at —9,610' MD using C9,1_ to locate mid joint 8. F Test KB whipstock to 2,400 psi for 30 min MITE p'� - � 9. V PTMV,SV,WV 10. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange 11. 0 Remove wellhouse, level pad Rig Work: (scheduled to begin August 15 2012) R. 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2 Mill 3 80" w indow at 9 610' and 10' of rathole Swap the well to PowerVis 3. Drill Lateral: 4.125" OH, 2,880' (12 deg /100 planned) with resistivity 4. Run 3 -1/4" x 2 -7/8" L -80 liner leaving TOL at 9,500' MD. 5. Pump primary cement leaving TOC at 9,500' MD (TOL), 15 bbls of 15.8 ppg liner cmt planned 6. Cleanout liner and run MCNUGR /CCL log. 7. Test liner lap to 2,400 psi. 8. Perforate liner per asset instructions (-1,000') 9. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set 4 -W liner top packer, and test to 2,400 psi (If liner lap test fails) 3. Generic GLV's 4. Test separator Zach Sayers CTD Engineer 564 -5790 CC: Well File Sondra Stewman/Terrie Hubble 'TREE= 4- 1/16" CM/ WELLHEAD = CM/ • OTES: ORIGINAL WELLBORE (C -03) IS ACTUATOR = BAKER C C _0 3 B NOT SHOWN ON DIAGRAM. KB. ELEV = 54.46' BF. ELEV = 35.16' KOP = 3000' �� . Max Angle = 94 @ 11603' 44 11' Datum MD = 9941' ,�'� I* 4 2039' —19-5/8" a CEMENTER I 120" CSG 1H 80 �j t I 2054' -19-5/8" SEAL ASSY Datum TVD = 8800' SS 0 1 � ' � '1 1 11 /2" TBG I 1814' 0* • 6,,• 2059' - -113 -3/8" X 9 -5/8" BOT PKR / LNR HGR 1 1 TOP OF 9 -5/8" LNR H 2043' 4 I ��� 2074' -19-5/8" FOC 19 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" 1 2068' 0 2138' - 113 -3/8" FOC 1! 2206' —14-1/2" HES X NIP, ID = 3.813" 1 ' 1 2332' 1-113-3/8" FOC GAS LIFT MANDRELS 118 -5/8" CSG, 96.5 #, K -55, ID = 17.655" H 2524' FAI 1111 ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3308 3295 18 MMG DOME RK 16 11/28/05 3 6120 5599 36 MMGM SO RK 20 11/28/05 1 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 4331' 1 2 8014 7182 31 MMGM DMY RK 0 11/13/05 1 9114 8114 33 KGB2 DMY BK 0 11/13/05 Minimum ID = 3.725" @ 9249' 4303' H9 -5/8" FOCI 4-1/2" HES XN NIPPLE 1 8054' 1-19-5/8" x 7" BKR C2 ZXP LTP w /TIEBK SLV, ID = 6.30" MILLOUT WINDOW (C -03B) 8202' -8215' I 8071' H 9-5/8" X 7" BKR HMC LNR HNGR, ID = 6.23" 1 9184' 1 -14 -1/2" HES X NIP, ID = 3.813" 1 'WHIPSTOCK (11/04/05) 1-1 8142' 9205' HT X 4-1/2" BKR PKR, ID = 3.875" 1 9228' H4-1/2" HES X NIP, ID = 3.813" 1 1 9 -5/8" LNR, 47 #, N-80, ID = 8.681" 1 - 8202 � �r� � _ _ 9249' -14-1/2" HES XN NIP, ID = 3.725" (EZSV PLUG (10/31/05) 1-1 8225' ��.�.� -�.��, CC 9250' - 7 "x5 " BKR HRDZXPLTP ������-' ` w/TIEBKSLV, ID= 4.41" 104 4T4 9261' - 14 -1/2" WLEG 1 � , o- � 9270' 1-1 RS PO NIP, ID = 4.25" 1 Lt ° •• 9272' - 7" X 5" BKR HMC LNR 14 -112" BKR ROCK SCREEN w / SOLID BULL NOSE (12/18/11 H 9249' HNGR, ID = 4.42" ` 1 9279' 1- 5" X 4 -1/2" X0, ID = 3.960" PERFORATION SUMMARY ` PBTD 1-i 11544' 1 REF LOG: ? ? ? ?? ON ? ? / ? ? / ?? 4 -1/2" TBG, 12.6#, L -80 IBT - M/TCII, 9261' ANGLE AT TOP PERF: 86° @ 10185' .0152 bpf, ID = 3.958" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1-1 9410' I / ` 3 -3/8" 6 10185 - 10210 0 07/18/09 / • 3 -3/8" 6 10210 - 10235 0 05/06/09 14-1/2" BKR CIBP (05/06/09) 1 10297' 114, 3 -3/8" 6 10255 - 10285 0 07/18/09 . 141111, 2 -7/8" 4 10320 - 11230 C 11/14/05 13.50 BKR CIBP (04/13/08) 1 11360' ELM ' � \�, 2 -7/8" 4 11440 - 11530 C 11/13/05 14 -1/2" LNR 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" H 11630' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/26/73 ORIGINAL COM PLETION 12/18/11 LEC/ PJC PULL PLUG/ ROCK SCREEN WELL: C-03B 10/05/87 RWO PERMIT No: 2051580 10/14/98 CTD SIDETRACK (C -03A) AR No: 50- 029- 20124 -01 11/15/05 N4ES SIDETRACK (C -03B) SEC 19, T11 N, R14E, 1316' SNL & 879' WEL 10/31/11 CDJ /JMD PX PLUG SET (10 /28/11) 10/31/11 RM/JMD TREE C/O (10/30/11) BP Exploration (Alaska) • TREE= 4-1/16" CNV III WELLHEAD = CM/ SA OTES: ORIGINAL W ELLBORE (C -03) IS ACTUATOR = BAKER C C -0 3 C NOT SHOWN ON DIAGRAM. KB. ELEV = 54.46' planned CTD sidetrack 'BF. ELEV = 35.16' KOP = 3000' ,� *� • • � Max Angle = 94 @ 11603' 04 r � �Datum MD = 9941' � 2039' —19 -5/8" EZ CEMENTER Datum TVD = 8800' SS • • 20" CSG - 80' ,� �� 2054' - 19 -5/8" SEAL ASSY — •' I 1 1* 2059' 13 - 3/8" X 9 -5/8" BOT PKR /LNR HGR H 1814' O 1 - 1/2" TBG A 1 �' TOP OF 9 - 5/8" LNR - 2043' I '41 161 2074' H9 FOC 9 -5/8" CSG, 40 #, L -80 BTC, ID = 8.835" I- 2068' E I I 2138' H 13 - 3/8" FOC 1! 2206' H4-1/2" HES X NIP, ID = 3.813" I I 2332' H1 f$'i IFFiSl14NDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 18 -5/8" CSG, 96.5#, K -55, ID = 17.655" 2524' • • 3308 3295 18 MMG DOME RK 16 11/28/05 3 6120 5599 36 MMGM SO RK 20 11/28/05 2 8014 7182 31 MMGM DMY RK 0 11/13/05 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 4331' 1 9114 8114 33 KGB2 DMY BK 0 11/13/05 Minimum ID = 2.377" @ — 10500' 3 -1/4" x 2 -7/8" XO 4303' I—I9 -518" FOC 8054' - 9 -5/8" X 7" BKR C2 ZXP LW • w /TIEBK SLV, ID = 6.30" 8071' H9 X 7" BKR HMC LNR HNGR, ID = 6.23" MILLOUT WINDOW (C -038) 8202' -8215' 9184' H4-1/2" HES X NIP, ID= 3.813" WHIPSTOCK (11/04/05) -] 8142' I 9205' — 17" X 4 -1/2" BKR FKR, O = 3.875" 9 -5/8" LNR, 47 #, N-80, ID = 8.681" H - 8202 9228' H4-1/2" HES X NIP, ID = 3.813" I milled out I. 9249' — 14 - 1/2" HES XN NIP, ID = 3.80" I EZSV PLUG (10/31!05) 8225' ' 9250' I 7" x 5" BKR HRD ZXP LTP 1i w /l1EBK SLV, ID = 4.41" TSGR = 9,415' MD ` �` 9261' h4 -1/2" WLEG 4-1/2" TBG, 12.6 #, L -80 IBT- MUTCII, —I 9261' _ 9270' H RS PO NIP, ID = 4.25" .0152 bpf. ID = 3.958" 9272' 1 7" X 5" BKR HMC LNR IT LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" I— 9410' HNGR, ID = 4.42" 20 9279' j 5" X 4 -1/2" XO, Top of 3 -1/2" liner and cement @ -9,500 —s ID = 3.960" 3 -1/4" x 2 -7/8" XO @ - 10,500' \ 9� 1a 4 A- 2-7/8" liner with TD at 12,510' 4 - 1/2" whipstock @ 9,610' C -- l 4 1* I PBTD —I 11544' PERFORATION SUMMARY 4 -1/2" CIBP @ - 9,750' `` REF LOG: ' ON 7?/? ?/92 ANGLE AT TOP PERF: 86° @ 10185' fj ` Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE �// ` 3 -3/8" 6 10185 - 10210 0 07/18/09 4-1/2" BKR CIBP (05/06/09) 10297' //�►\ 3 -3/8" 6 10210 - 10235 0 05/06/09 ��� 3 -3/8" 6 10255 - 10285 0 07/18/09 3.50 BKR CIBP (04/13/08) 11360' ELM �‘ 2 -7/8" 4 10320 - 11230 C 11/14/05 2 -7/8" 4 11440- 11530 C 11/13/05 4 -1/2" LNR 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" —I 11630' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/26/73 ORIGINAL COMPLETION 12/18/11 LEG PJC PULL PLUG/ ROCK SCREEN WELL: C-03C 10/05/87 RWO !4/23/12 WJH planned CTD sidetrack WELL:' 051580 10/14/98 CTD SIDETRACK (C -03A) WELL: 50- 029 - 20124 -01 11/15/05 N2ES SIDETRACK (C -03B) SEC 19, T11 N, R14E, 1316' SNL & 879' WEL 10/31 /11 CDJ /JMD PX PLUG SET (10/28/11) 10/31/11 RM'JMD TREE C/O (10 /30/11) BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM . V12 V14 • I 7.1118" 6000 psi BOP's ID = 7.06" V15 V11 . 17 1/16" 6000 Psi, R% Transducers 0 111 11 :.ORB. li V2 1 V1 V 16 ...op MII— Note BOP arrangement for 23R" coiled ruling drilling 1I I 7 NW 6000 psi, ax � . u1 V17 �. To Poor Boy bas Buster HCR � IC �� 1K OK ��� A WI. I Tr ' 2 1118 " 6000 psl, RXRt I • 1111.11 1111 9.00 "6000 psi NCR I ■ l illil .......,,w,..,..,.., -In on- 2- 1116 "6000 VPL VE PSi CHECK I Manual Choke 6060 / .� ■ N _ 1OU " ;; ; 7 1/16 Cameron FOV Gate ¢;. Valve a 5600 psi 1`f lir MEOH /Diesel • , , r h 4— - FP Line CoFlex Hose . =. 1/4 Tum Halco . h. . , 1OWOG To Production Tree or Cross Over • 4 • T e transducers CoFlex Hose 0/11 11 „ , CV12 To Coiled Tubing Bleed OR Inner Reel Valve _ Alt -_.7. _ _ - I I CV13 Cement Line In - ! Ground Level Tie -in 7. CV10 -1 CVO CV2 T Stand Pipe A n, ..........-=-._ r MOP _ _ _ Manual Choke MI - no - - �•/ Pressure Transducers N9 Motion // -t I CV77 " 411111/ CV1 I NS VMIlif Tiger Tank F•• Mud P UMP (I In From ANL O - - _ Baker MP 1 8 MP 2, ■ IOW Choke • • CV14 to Pits t Rig Floor i Mud Pump #1 40CV16 Reverse CI _ . . . Cir CT w1—fie—OOH . 0 To Manifold CV15 1- Jun -2010 4 R..v.ome Cir.•rdmlon lino I CT while nom CoFlex Hose • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code " IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: / /F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE - DRI... 6/2/2011 2o5 -t5 24 -FEB -2012 214 Schhneherger 5895 Alaska Data & Consulting Services 3v M Y 2 2 201'4 Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD Z -21A BWML -00003 RESERVOIR SATURATION LOG 13- Oct -11 1 1 N -04A BINC -00068 RESERVOIR SATURATION LOG 28- Sep -11 1 1 iiii C -03B BINC -00059 RESERVOIR SATURATION LOG 19- Aug -11 1 1 D -06A BL65 -00041 MEMORY COMPENSATED NEUTRON W/ BORAX 25- Jun -11 1 1 llir H -19B BLPO -00109 MEMORY COMPENSATED NEUTRON W/ BORAX 13-Jun-11 1 1 01 -02 BG4H -00083 RESERVOIR SATURATION LOG 5- Sep -11 1 1 B -16A BD88 -00128 MEMORY COMPENSATED NEUTRON LOG 30-Jun-11 1 1 le PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 r August 22, 2011 RECENED AUG 3 1 2f Mr. Tom Maunder �� Alaska Oil and Gas Conservation Commission aft & %at C 333 West 7 Avenue Anchorage Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB C -Pad s 53 s Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C -01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 I C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C -20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 ' NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI~N REPORT OF SUNDRY WELL OPERATIONS ~~~~11/~ 8~ ~u~ ~ ~ zo~ ~F 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate~ Othh~r ~ ~ ~~ as , ;, Performed: ;,~5~.3 ; ~ Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver~ Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well "~~~~~~~ 2. Operator BP Exploration (Alaska), inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~lopment r Exploratory I~~ 205-1580 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage,AK 99519-6612 50-029-20124-02-00 7. KB Elevation (ft): 9. Well Name and Number: 63.66 KB PBU C-03B 8. Property Designation: 10. Field/Pool(s): ADLO-028305 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11635 feet Plugs (measured) 10297' 11360' true vertical 9003 feet Junk (measured) None Effective Depth measured 11544 feet true vertical 0 feet Casing Length Size MD NO Burst Collapse Conductor 80 20" Surface - 80 Surface - 80 Surface 2524 18-5/8" 96.5# K-55 Surface - 2524 Surface - 2524 930 870 Intermediate 4331 13-3/8" 72# L-80 Surface - 4331 Surface - 4180 4930 260 Production 2068 9-5/8" 40# L-80 Surface - 2068 Surface - 2068 5120 2370 Liner 1356 7"26# L-80 8054 - 9410 7216 - 8365 7240 5410 Liner 2380 4-1/2" 12.6# L-80 9279 - 11630 8229 - 8997 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# ~-80 SURFACE - 9261' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR PKR 9205' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: Intervalstreated(measured): _.~ ~~~~~_,~ ~\;'~ s:3 ~t~r~~ 1~ .~ ~ ~ i Y 4v 4.4W ui. ..'.' Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oii-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 161 9613 14 625 Subsequentto operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Su~eys Run Exploratory ~~ De~elopment ~ Service ~~~ Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas ~`~ WAG ~ GINJ ~ WINJ ~ WDSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Titie Data Management Engineer Signature ~~ Phone 564-4944 Date 7/20/2009 Form 10-404 Re sed 04/2006 ~' ~~`~~ ~~~~ ~F; " ";' ~, Submit Ori i ~ ~ F, ~,~~1~ g nal Only `~ -.~ ~~ ~/?~C~~ C-03B 205-158 PF_RF OTTO[:HMENT • Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-03B 11/13/05 PER 11,440. 11,530. 9,007.78 9,003.53 C-03B 11/14/05 PER 10,320. 11,230. 9,017.18 9,007.94 C-03B 5/6/09 APF 10,210. 10,235. 9,005.85 9,008.73 C-03B 5/6/09 BPS 10,297. 10,299. 9,015. 9,015.19 C-03B 7/18/09 APF 10,185. 10,210. 9,001.55 9,005.85 C-03B 7/18/09 APF 10,255. 10,285. 9,010.8 9,013.82 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 SQUEE2E MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~ • ~ C-03A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY - . ~ ~ ~` '~ ~ ~` ~1~-~'~ r n , <. ~ ~- ~ ~~«,~c~ . ` ~' , .~ ~ . ? 7/17/2009~CTU #5: Job Scope: Memory GR/CCL/Perforate; «Interact Not Publishing» ~ ~ j MIRU coil unit. MU and RIH with 3 3/8" dummy gun and PDS GR/CCL for coil jflag. Log from 10287' to 9000' ctmd for coil flag. Flag coil at 10200' & 10256' ~ ; ctmd. POOH and download logging data. Depth correction (-6'), log correlated to }SLB RST SIGMA/GR/CCL log dated 5-5-09. MU and RIH with 30' 3 3/8" HSD ; ~ ;2006 PJ, 6 spf gun.""'Continued on 18 July WSR"** ~ 7/18/2009:CTU #5: Job Scope: Memory GR/CCL/Perforate; «Interact Not Publishing» ?Continue running in well with 3 3/8" perforating gun. Run #1. Correct top shot at ~flag to 10190.9' PU to perforation depth @ 10255'. Pump 1/2" steel ball on seat, 3 pressure up to 2200 psig and fire guns. Perforated from 10255' to 10285'. ; POOH with run #1. Verified all shots fired. MU and RIH with gun #2. 25' - 3 3/8" ~ HSD loaded with 2006 PJs at 6 spf. Correct top shot depth at flag to 10190.9'. ?Pull into shooting depth at 10185' corr. Pump 1/2" steel ball on seat. Pressure iup to 2250 psi and fire gun #2. Perforate from 10185 to 10210'. POOH with run i#2. Verified all shots fired. Attempt to FP down tubing, well not taking fluid. RIH iwith 3.0" noule and lay in 40 Bbl diesel freeze protect from 2500' to surface. ~RDMO. ""*Job Complete""* FLUIDS PUMPED BBLS 65 DIESEL 152 1 % XS KCL 217 Total • • Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, June 04, 2009 9:09 AM To: 'Preble, Gary B (SAIC)' Subject: C-03B (205-158} Gary, I am reviewing the 404 recently submitted for setting a 8P and pertorating on this well. Accaording to the 404, there was a BP previously set in the well at 11360. On the operations report, it is stated that the BP was tagged at 10360 which would appear to be a typo. I look at our file and I do not find any information regarding the setting of the BP at 11360. Can you check your records and send the appropriate operations reports? No need to send a 404. Call or message with any questions. Tom Maunder, PE AOGCC ~~3'~r~ ~~.lT.~ ~ _ 20~J Maunder, Thomas E (DOA From: Preble, Gary B (SAIC) [Gary.Preble@bp.com] Sent: Thursday, June 04, 2009 9:43 AM To: Maunder, Thomas E (DOA) Subject; Emailing: C-03A-SERVICE-RPT.pdf Attachments: C-03A-SERVICE-RPT.pdf C-03A-SERVICE-RP Tom, It is a typo and here is the well service report for the BPS 4/~,3,Lgq The message is ready to be sent with the following file or link attachments: C-03A-SERVICE-RPT.pdf Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «C-03A-SERVICE-RPT.pdf» STATE OF ALASKA ALAS OIL AND GAS CONSERVATION COMMI~N S--/l ~ MAY ~. 5 2009 REPORT OF SUNDRY WELL OPERATION9laska Qi! ~ Gas Co~~a Cnrrltn;cc;,,.E 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~O~Or9~t+ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate 0 - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ~ Exploratory 205-1580 - 3. Address: P.O. Box 196612 Stratigraphic ~ Service ( 6. API Number: Anchorage, AK 99519-6612 50-029-20124-02-00' 7. KB Elevation (ft): 9. Well Name and Number: 63.66 KB PBU C-03B - 8. Property Designation: 10. Field/Pool(s): - ADLO-028305 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 11635 - feet Plugs (measured) 10297' 11360' true vertical 9003 ~ feet Junk (measured) None Effective Depth measured 11544 - feet true vertical 0 feet Casing Length Size MD TVD Burst Collapse Conductor 80 20" Surface - 80 Surface - 80 Surface 2524 18-5/8" 96.5# K-55 Surface - 2524 Surface - 2524 930 870 Intermediate 4331 13-3/8" 72# L-80 Surface - 4331 Surface - 4180 4930 260 Production 2068 9-5/8" 40# L-80 Surface - 2068 Surface - 2068 5120 2370 ' Liner 1356 7" 26# L-80 8054 - 9410 7216 - 8365 7240 5410 Liner 2380 4-1/2" 12.6# L-80 9279 - 11630 8229 - 8997 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ - True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# L-80 SURFACE - 9261' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BKR PKR 9205' 0 0 0 0 0 0 12. Stimulation or cement squeeze summary: ~ Intervals treated (measured): ~ ~~~~°~ ~~ .~~ Treatment descriptions including volumes used and final pressure: `®~~~ ~~ 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~' - Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas WAG GINJ ~ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preble Title Data Management Engineer Signature Phone 564-4944 Date 5/13/2009 Form 10-404 Revise. 04/2006 ~ ~ ~ Sub iginal Only ~~%~~~ C-036 205-158 PERF ATTArI-IMFNT u Sw Name Operation Date Pert Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-03B 11/13/05 PER 11,440. 11,530. 9,007.78 9,003.53 C-03B 11/14/05 PER 10,320. 11,230. 9,017.18 9,007.94 C-03B 5/6/09 APF 10,210. 10,235. 9,005.85 9,008.73 C-03B 5/6/09 BPS 10,297. 10,299. 9,015. 9,015.19 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 • C~ • C-03B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 5/4/2049 ""'WELL SI ON ARRIVAL*** ~ SSV, SWAB = C, MASTER = O, INITIAL T/I/O = 2360/700/0 ILRS KILL WELL WITH 260 BBL 1%KCL. WELL IS ON VAC AFTER LOAD & KILL RIGGING UP TO RIH WITH MH-22, ECRD, TRACTOR, GR/CCL, WEIGHT i BARS, AND CENTRALIZER TO LOG JEWELRY /TIE-IN LOG. i ~"**JOB CONTINUED ON 5-MAY-2009"** 5/4/2009 T/I/O = 2600/750/380/0_Assist E-Line with Load to Secure for RST Log. Pumped 260bb1s 100*F 1 %KCL down Tbg to displace gas from Tbg liner. ""*Job in progress, job continued on 5-5-09"'** 5/5/2009 "** JOB CONTINUED FROM 5-MAY-2009 """ DRIFT VyITH WELLTEC TRACTOR AND 3-3/8" DUMMY GUN TO CIBP AT 1~3~~ 7ydt5U', MHX I VVL VU = 3.titi", LtNC~ I I-I = 5U' RU WELLTEC TRACTOR /RST, LOG 1 PASS AT 30 FPM, 2 PASSES AT 60 FPM, LOG 4TH PASS AT 30 FPM FROM 11650' TO 9650', PUMPING 0.5 TO 0.7 BPM WHILE LOGGING. TRACTORING FROM 10200' TO 11350' """ JOB IN PROGRESS AND CONTINUED ON 6-MAY-2009 WSR''*" 5/5/2009 ***Job in progress, continued from 5-4-09***T/I/O = 2600/750/380/0 Assist E-Line with Load to Secure for RST Log. Pumped 106 bbls. 1 %KCL and 1160 bbls. 80*F Crude while SLB logged. Continued on 05-06-09 WSR __ 5/6/2009Continued from 05-05-09 WSR, Assist E-Line w. RST Log. Pumped into. Tbg ~w/ 282 total bbls Crude, capped w/ 75 bbls diesel while E-Line ran RST. 1FWHP=200/800/520/0 Casing vlaves open to gauges, E-Line on location upon departure 5/6/2009''*" JOB CONTINUED FROM 5-MAY-2009 ""* ;PUMP 45 BBL DIESEL AT 3 BPM. RU ELINE, WELLTEC TRACTOR / CCL /CIBP, MAX OD = 3.66", LENGTH - 40 SET CIBP AT 10297'. POOH. RIH WITH 3-3/8" PJ HMX. PERFORATE s F .235' AT 6 JSPF. FIRED GUN AND GOOD INDICATION. *"*JOB IN PROGRESS AND CONTINUED ON 7-MAY-2009 WSR*** 7/2009 • "`""`JOB CONTINUED FROM 6-MAY-2009"'** FINAL T/I/O = 0/750/0 WELL SHUT IN ON DEPARTURE. ALL VALVE POSITIONS COMMUNICATED TO AND APPROVED BY PAD OPERATOR. """JOB COMPLETE"** FLUIDS PUMPED BBLS 366 1 % KCL 120 DIESEL 486 Total We1lServiceReport • • Page 1 of 2 WELL SERVICE REPORT WELL .IOB SCOPE UNIT `'..03g PACKERS1BRfDGE PLUGS (NRWO) CTU #9 DATE DAILY WORK DAY SUPV 4/13/2008 SET MECHANICAL PLUG BURNETT COST CODE PLUS KEY PERSON NIGHT SUPV PBCPDWL03-N DS-WILLIAMS MIELKE MiN ID DEPTH TTL SIZE 3.725 " 9249 FT 4.5 " CTU #9 w/ 1.5" OD CT. Set CIBP, continued from WSR 04/13/08. Log PDS memory GRICCL correlation log from 11450' - 10$00' ctmd, pain#ing coil flag at 11150' ctmd. POOH. MU and RIH with Baker CfBP. Set CIBP mid-'pint at 11360' MD (reference: Sperry-SunMalliburton MWD (DGR, EWR) 02-Nov-0S through 12-Nov-O reeze Protect Weil with 38 bbls 60/40 methanol. Perform Weekly BOP test. Notifv Pad Operator of well status. RDMO. ***Job Complete*** ~ nn Fnrrr~r~c !nit T , lA, OA 1759 808 450 TIME DEPTH TBG CTP BPM BBLS COMMENTS 00:01 11450 1759 50 Park at bottom of log interva{ at 11450.4' ctmd. Mechanical counter reads 11421'. PDS box reads 11450.48' . OOA ressure = 0 i. 04:01 1759 52 Continued from WSR 04113108. Continue RIH with logging tooistrin . 00:05 11450 1754 48 B in l u at 40 f m. 00:13 11150 1759 0 Flag coil at 11150.6' cfmd. Flag is white. Mechanical counter reads 11122'. PDS box reads 11150.65' 00:17 11150 1758 0 B in to at 40 f m. 00:26 10800 1764 0 Park at top of logging interval at 10800.1' ctmd. Mechanical reads 10772'. PDS reads at 10800.23' 00:30 10800 1762 0 B in POOH. 00:45 0 Walkaround of return tank. 02:07 0 1666 0 Tag up at surface. SIWHP = 1666 psi. Close swab and bleed down lubricator. 02:32 0 Break PDS toolstrin . 02:38 0 0 Online with 60140 meth/water down coil to PT BHA. 02:40 0 Correlate coil flag log with PDS. Correction of -11 feet to reference log Sperry Sun/Halliburbon MWD {DGR, EWR) 02-Nov-05 #hrough 12-Nov-05. 02:45 0 BHA assed PT to 3500 si. 02:55 0 MU Baker settin tool and CIB 03:30 0 Stab on. 03:49 0 11.5 LPPTIHPPT assed to 300 si/4000 si. 03:51 0 1651 1683 O en swab. SIWHP = 1649 si 03:55 0 Begin RIH with MHA #3: 2.13" OD CTC, 2.13" OD DBPV, 2.13" OD hydraulic disconnect {accepts 3I4" OD ball to disconnect), 2.65" OD xo, 2.75" OD J-10 hydraulic setting tool {with 112" baA seat), 3.50" OD CIBP. OAL:14.1T. 04:59 6000 1736 65 Wei ht check: 11300 ib. 05:54 11151 1748 13 Park at flag ~ 11151.2' dmd. Mechanical counter reads 11137'. Correct de th to corrected mid-element 11141.6` ELMD 05:55 11141 Continue RIH. 05:56 11414 1748 12 0.7 11.5 Stop at c~nvienient ball drop. Load ball. Launch bail with 1100 psi pressure. PU clean at 20300 lb to set dep#h. Hear baN roiling throu h reel. 06:12 11360 1753 2360 0.9 15.4 Park at set depth. Mid-element is at 11360.3' ELMD. This is mid- 'oint settin in clean i e, avaidi collars . 06:15 11360 1749 2359 0.9 17.9 No longer hear baU in reef. This is within 0.5 bbl of calculated volume over ooseneck. 06:22 11360 1742 1003 0.6 27 Reduce rate. 06:32 11360 1729 752 0.5 32 Reduce cafe. 06:34 11360 1728 750 0.5 33.1 Bait on seat 06:35 17360 1727 4000 0.5 33.4 Sudden decrease in circ pressure. Broke over at 4000 psi, broke to 670 si. Concurrent , wei ht tiro ed off 3000 lb #013000 ib. 06:36 11360 1726 634 0 34.6 PU clean at 19500 ib. Down on pump. At Baker's recommendation, opt not to tag (dont want setting rod #o bend, or to get pushed into lu http://apps2-alaska.bpweb.bp.corn/awgrs-wellservicereport/default.aspx?id=A36474117$484E76A... 6/4!2009 WellServiceReport ~ ~ Page 2 of 2 06:39 11141 1725 1 Park and repaint flag. Flag is white. Flag is at 11141' ctmd. Resume POOH. 08:18 0 1652 -11 48 Pum 60140 methane[ for freeze rotect of roduction tubi 08:32 0 1446 -5 76 Done freeze rotedi 08:39 0 1446 -5 76 Secure well and re to ri back 10:00 0 B in weekl BOP test 12:00 0 BOP test ood 12:01 0 B in Ri Down 13:00 Q Check chains and cha a ack-offs 15:00 0 Road unit to G77 Final T , iA OA 1446 811 425 76 bbls 60140 methanoi/water - Tank nc http://apps2-alaska.bpweb.bp.com/awgrs-wellservicereport/default.aspx?id=A36474I i 78484E7fiA... 6/412009 05/14/09 ~~~~~~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NO.5235 Company: State of Alaska :~ ~~ 3 Alaska Oil & Gas Cons Comm ~~'~~~~~ i/i ~~~•~ ~ { :6 Attn: Christine Mahnken ..~. m;. 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Jeh # Lea Descriotien Date BL Color CD Z-O6 AP3O-00035 STATIC PRESSlfEMP SURVEY 04/25/09 1 1 E-07A AYOO-00022 SCMT _ 04/24/09 1 1 V-04 AWJB-00031 MEM GLS -( 03/24/09 1 1 Y-16 AZ4D-00015 USIT (~ .-p 00~- 05/06/09 1 1 07-16A B2WY-00002 MEM CBL p 04/29/09 1 1 J-O6 ANHY-00009 PRODUCTION PROFILE C3(} 05/08/09 1 1 R-21 AVY5-00038 LDL / -l / J C~ 05/02/09 1 1 18-O1A 62WY-00003 MEM CBL /~j(o -~ 05/01/09 1 1 13-03 AYKP-00018 SCMT ~'~ ~_ p(o~ ( ~ (~ 05/01/09 1 1 4-04A/T-30 BOCV-00014 SCMT ~ 04/27/09 1 1 03-09 AXOY-00007 MCNL ~ p~ ~(~ 12/13/08 1 1 K-16AL2 AXIA-00009 MCNL - 01/10/09 1 1 02-13B AWL9-00028 RST 03/26/09 1 1 C-03B AVY5-00040 RST " 05/05/09 1 1 YLtA,t At:RIVV W LtU(at titt:tlY 1 CT JI(GIVIIVIi ANU Flt 1 UH1V11VCi VIVt t:UY1 tRl~t1 1 U: BP Exploration (Alaska) Inc. ~ y y~ ~~ .~ Petrotechnical Data Center LR2-1 , ~ 900 E. Benson Blvd. 3 Anchorage, Alaska 99508 2O~g Date Delivered: . ~S (~q}911~1iS51~ &d ~i@~~ I~ Alaska Data & Consulting Services 2525 Gambell Street, to 400 Anchorage, AK 950 - 838 ATTN: Beth Received by • • ~ ~ WELL LQG TRANSM/TTAL ~~- ProActive Diagnostic Services, Inc. To: AC~CC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907] 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT] The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Bbd. Anchorage, Alaska 99508 v~~ ~~ _~-~c,r~l~o~a9 and ProActive Diagnostic Services, Inc. Attn: Ro~rt A. Richey 130 West International Airport Road~~~ APR ~ ~ X008 Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ~/ 1 ] Coil Flag 13 Ap-L08 G036 / v' 2] Leak Detection - WLD 12-Aprv08 DS 17-0Si ~~ Signed Print Name: [ '~ ~~-,,~f. } c~- e-J v l n,(~ ; V p c- 1 EDE 50-029-2012402 1 Color / EDE 50-029-20602-00 Date : ~ - _. 1 PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (9071245-8951 FAX:. (9071245-88952 E-MAIL : ~dsarat:S~mrage(a~ra~es~aarv9acs.L~ar~ WEBSITE : °r~~rtwo~es~sc~r~~~® C:\Documents and Settings\OwnerlDesktop\Transmit_BP.doc ~ ~ -~.',~', WELL LOG TRANSMITT. ~ t •_~ ' To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~` Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: C-03B ~~~~9.~r _~ ~ , .deb , ,.. . ~. AK-MW-403088 1 LDWG formatted CD rom with verification listing. API#: 50-029-20124-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO TAE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. A~c}~orage, Alaska 99518 ~, ~~. Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: ~~~ MAR ~ ZDO~ ass-~s~ ~` ~ 59~~/ WELL LOG TRANSMITTAL To: State of Alaska February 13, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : C-03B AK-MW-4030881 C-03B: Digital Log Images: 50-029-20124-02 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 _ ~„ ,~ , :eG l Vii. ~ ~'.~ v 7 -;~-sca :~. Date: ~ . y~i?u BP Exploration (Alaska) Inc. Petrotechnical Data Center, MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 Signed: r ~~~ ~E~ MAR ~. ~ 200 d~s ~5 ~ ~~5~(O DATA SUBMITTAL COMPLIANCE REPORT 1 /29/2008 Permit to Drill 2051580 Well Name/No. PRUDHOE BAY UNIT C-036 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20124-02-00 MD 11635 TVD 8996 Completion Date 11/14/2005 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Su ey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / GR /RES, DIR / GR /RES /DEN / NEU Well Log Information: log/ Electr Data Digital Dataset Log Log Run Type Med/Frmt Number Name Scale Media No D D Asc Directional Survey sc Directional Survey C Las 15435 See Notes Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? / Chips Received? ~i~`y-td---, Analysis ~Y_! N~ Received? Comments: Compliance Reviewed By: (data taken from Logs Portion of Master Well Data Maint Interval OH / Start Stop CH Received Comments 8189 11635 Open 1/9/2006 8189 11635 Open 1/9/2006 MWD 8191 11635 Open 9/17/2007 Field Data, LAS - FNC, GR, NCN, NPHI, RHOB - _ . _ - _ _-- w/EMF Graphics ---_. - _ - _ _ _ _- -I Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops Date: • Date 09-14-2007 Transmittal Number.92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) [f you have any questions, please contact Douglas Dortch at the Yll(; at 564-4y"/:3 Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: u~C 06-066 i r5 Val 06-06BPB1 ~ aos-c~1~ ~ r~ elate 13-31 A - vT c ao5- I~oo ~ ~~2'~ 14-11 A `~ ao~ !86 ~S~a 14-11 APB1 14-21A uzcao5 -!v~ ~ +5 ~i3! 15-39A aom-o~~r ~ tgy3a 16-066 acx.-o ti t ~ i s~/33 16-14Bc3C(o•0~3 "~Sy3y c-osB aos ~~ ~ ~s~s C-10A aos ~~~ • +5~a~ J-17C o~ofS-O'~fa ~ i5`~3~' NGI-07A Uz.eaoc.-,ate ~ 1S~l3~ n ~,~ r' i~ ;1 Please ~'ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 ~~ ~ ~~~~ ~- Y~ ~~ ~ ~~~ ~,~, ~v~i t r;~s~,~ie=, ~,ilC i0i ~~~ Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99~ 19-6612 STATE OF ALASKA ALASKA LAND GAS CONSERVATION COMMON WELL COMPLETION OR RECOMPLETION REPORT AND LOG ECEI~ iAtV Y $ ~C'C=~a *iaska Clil & Gas COtI':s. C~.~tnts~ir~n 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC26.105 2oAACZfi.,~o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aban // ~ 12. Permit to Drill Number 205-158 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/5/2005 13. API Number 50-029-20124-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 11/11/2005 14. Well Name and Number: PBU C-03B 1316 FNL, 879 FEL, SEC. 19, T11 N, R14E, UM Top of Productive Horizon: 630' FSL, 1632' FWL, SEC. 17, T11N, R14E, UM 8. KB Elevation (ft): 63.66' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 395' FSL, 257' FWL, SEC. 17, T11N, R14E, UM 9. Plug Back Depth (MD+TVD) 11544 + 9003 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664500 y- 5959906 Zone- ASP4 10. Total Depth (MD+TVD) 11635 + 8996 Ft 16. Property Designation: ADL 028305 _ TPI: x- 666960 y- 5961907 Zone- ASP4 Total Depth: x- 665591 y- 5961641 Zone- ASP4 11. Depth where SSSV set N/A MD 17. Land Use Permit: ------~~~~-~---- ~~-~~~~-~~-- t Thi k f P f 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness o erma ros c 20. 1900' (Approx.) 21. Logs Run: MWD DIR / GR /RES, DIR / GR /RES /DEN / NEU 2. ASING, LINER AND EMENTING RECORD CASING ETTINti EPTH MD ETTINO EPTH TVp .HOLE MOUNT SIZE WT, PER FL GRADE OP TTOM OP TTOM .SIZE CEMENTING RECORD PULLED 20" Insulated Conductor Surface 80' Surtace 80' 36" 84 sx Cement 18-5/8" 139# / 109# /96.5# K-55 Surface 2524' Surtace 2524' 24" 700 sx Permafrost II 13-3/8" 72# / 68# L-80 / N-80 Surface 4331' Surface 4180' 17" 1210 sx Class 'G', 950 sx PF II 9-5/8" 40# / 47# L-80 / N-80 Surtace 8202' Surface 7342' 12-1/4" 670 sx Class 'G', 619 sx Class 'G' 7" 26# L-80 8054' 9410' 7216' 8365' 8-1/2" 75 sx Class 'G' 4-1/2" 12.6# L-80 9250' 11630' 8229' 8997' 6-1/8" 90 sx Class 'G' 23. Pertorations open to Produc tion (MD + TV D of Top and " " 24. TUBING=RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, L-80 9261' 9205' MD TVD MD TVD 10320' - 11230' 901 T - 9008' 11440' - 11530' 9008' - 9004' 25, ACID, FRACTURE, CEMENT $OUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 155 BBIs Diesel 26. PRODUCTION TEST Date First Production: December 4, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Oate of Test 1/7/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 191 GAS-MCF 3,802 WATER-BBL 2.5 CHOKE $IZE 60° GAS-OIL RATIO 19,904 Flow Tubing Press. 2,00 Casing Pressure 1,540 CALCULATED 24-HOUR RATE OIL-BBL 1,146 GAS-MCF 22,810 WATER-BBL 15 OIL GRAVITY-API (CORK) 28.3 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 ch~~s; if none, state "none". .~' ~ u/fv o..~/ ~~~IS ~F~ A;~l~ ~ 91006 None `~ ~~-~ ~ !~ ~~ ~2rs2. ,~~ T3~Z ~~ Form 10-407 Revised 12/2003 ~,,~ ~"~ ~ ~ CONTIID~ON REVERSE SIDE 28. GEOLOGIC MARKERS 29' MATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top HRZ 8405' 7516' None Base HRZ 8647' 7722' Sag River 9415' 8369' Shublik 9459' 8407' Sadlerochit 9540' 8483' Top CGL 9691' 8632' Base CGL 9785' 8722' 23SB /Zone 26 9832 8766' 22TS 9905' 8833' 21 TS /Zone 2A 9979' 8895' Zone 16 10090' 8967 TDF /Zone 1 A 10238' 9009' 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 D t ~ Titl T h i l A i O,~j ~ d~ a e e ec n ca ss stant / Terrie Hubble PBU C-03B 205-158 Prepared By Name/Number.• Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Ken Allen, 564-4366 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. Frets 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 Printed: 11/21/2005 11:47:07 AM • BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-03 C-03 REENTER+COMPLETE NABOBS ALASKA DRILLING I NABORS2ES Start: 10/27/2005 Rig Release: 11/15/2005 Rig Number: Page 1 of 7 Spud Date: 2/13/1973 End: 11 /15/2005 Date !; From - To 10/29/2005 00:00 - 03:30 Hours Task ', Code', NPT - - - __ 3.50 MOB ~ P 03:30 - 13:30 10.00 MOB P 13:30 - 14:00 0.50 MOB P 14:00 - 16:30 2.50 WHSUR P 16:30 - 20:00 3.50 WHSUR P 20:00 - 21:00 21:00 - 23:00 23:00 - 00:00 10/30/2005 00:00 - 01:00 01:00 - 01:30 01:30 - 02:30 02:30 - 03:30 03:30 - 07:30 07:30 - 08:00 08:00 - 09:00 09:00 - 10:00 10:00 - 11:30 11:30 - 15:00 15:00 - 21:00 21:00 - 22:00 22:00 - 00:00 10/31 /2005 00:00 - 05:00 05:00 - 06:00 1.00 WHSUR P 2.00 WHSUR P 1.00 BOPSU P 1.00 BOPSU P 0.50 BOPSU P 1.00 BOPSU P 1.00 BOPSU P 4.00 BOPSU P 0.50 BOPSU P 1.00 PULL P 1.00 PULL P 1.50 PULL P 3.50 PULL P 6.00 PULL P 1.00 BOPSU P 2.00 DHB P 5.00 DHB P 1.001 BOPSUFi P Phase Description of Operations PRE Move rig from well # C-10 to well C-03. Move camp & pits. Bridle up. UD pipe shed chute. UD derrick. Move off well. PRE Move and spot sub base over C-03B. Spot welding shop, pits & cuttings tank. Raise derrick. Raise and pin cattle chute. Bridal down & hang Iines.R/U floor. Complete pre-spud check list. PRE Hold pre-spud meeting with Tool pusher, WSL and drill crew. Rig accepted Q 14:00 hrs 10/2912005. DECOMP R/U circ lines in cellar to tree & annulus. R/U DSM & pull BPV with lubricator. Tubing & annulus = 0 psi. DECOMP Circ down annulus, displace diesel freeze protect from tubing. R/U and pump down tubing taking returns through choke. Pump 45 bbl Safe-Surf-O & displace well to clean seawater ~ 4 bpm Cam? 350 psi. Monitor well. DECOMP Suck out tree and dry rod BPV in & test from below to 1000 psi. Blow down circ lines and rig down. DECOMP N/D tree & adaptor flange & remove from cellar. DECOMP N/U 13 5/8" x 5000 psi BOPE. DECOMP N/U 13 5/8" x 5000 psi BOPE. DECOMP Test BOP to 250 psi low test & 3500 psi high. TWC valve leaking. (Set clocks back 1 hour for daylight savings time.) Gave 24 hour notice to AOGCC for inital BOP test. Witness of test waived by rep. Jeff Jones.Test witnessed by WSL James Willingham & Tool Pusher Ronnie Dalton. DECOMP Test choke manifold. DECOMP R/U DSM lubricator and pull TWC valve. Install new valve, R/D lubricator. DECOMP Test BOPE. 250/3500 psi. Top drive to 250/3500. Witnessed by Maskell - Co Rep. Witness of test waived by AOGCC Rep J. Jones. Clear rig floor of all testing equipment, blow down lines. DECOMP R/U DSM lubricator, pull TWC, R/D lubricator. DECOMP Bring tubing tools to rig floor. M/U spear for 5 1/2" tubing. DECOMP Spear 5 1/2" tubing. BOLDS. Pull tubing hanger to rig floor. UWT = 165K. DECOMP Release spear, UD landing joint & tools. DECOMP POH UD 5 1/2" 17# tubing, spool up control lines to SSSV 2131'. R/D spooling unit and clear rig floor. Recovered 26 clamps and pins & 3 S.S. bands. According to the records we are missing 1 S.S. band. DECOMP POH UD tubing. Recovered 222 joints of tubing, 4 GLM, 1 BVM, and cut joint @ 19.46'. R/D tubing equipment, clear and clean rig floor. DECOMP M/U test joint, install test plug and test BOPE with 4" test joint. Test top & bottom rams & floor valves to 250/3500. Test annular preventor to 250/2500 psi. Witness of test waived by AOGCC rep Jeff Jones. Test witnessed by WSL James Willingham & Tool pusher Ronnie Dalton. DECOMP PJSM. R/U Schlumberger wire line &RIH with 8.51 GR/JB & CCL. DECOMP RIH w/8.51 GR/JB &CCL to 8800' (36' above 5 1/2" tubing stub) Work through tight spot @ 4280', POH. M/U HES EZSV & CCL, RIH, set EZSV plug @ 8225'. POH & get SWS off to side. DECOMP Close blind rams. Test casing to 3500 psi for 30 min - OK. Printed: 11/21/2005 11:47:15 AM BP EXPLORATION Operations Summary Report Legal Well Name: C-03 Common Well Name: C-03 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 2ES Date From - To Hours ~ Task Code ~ NPT ~__ _ __ 10/31/2005 .06:00 - 08:00 2.00 CASE P 08:00 - 10:00 I 2.001 CASE I P 10:00 - 11:30 I 1.50 I CLEAN I P 11:30 - 12:00 0.50 CASE P 12:00 - 14:30 2.50 CASE P 14:30 - 19:00 ~ 4.50 ~ CASE ~ P 19:00 - 21:00 2.00 CASE P 21:00 - 00:00 3.00 CLEAN P 11 /1 /2005 ~ 00:00 - 01:30 ~ 1.50 ~ CASE ~ P 01:30 - 03:00 1.50 CLEAN ~ P 03:00 - 04:30 1.50 CLEAN P 04:30 - 07:00 I 2.501 DHB I P 07:00 - 07:30 0.50 DHB P 07:30 - 09:00 1.50 DHB P 09:00 - 10:30 I 1.501 BOPSUR P 10:30 - 12:00 I 1.501 BOPSUR P 12:00 - 15:30 ~ 3.50 ~ BOPSUFI P 15:30 - 18:00 ~ 2.501 BOPSUFIP 18:00 - 20:30 2.50 BOPSU~ P 20:30 - 22:00 1.50 BOPSU P 22:00 - 00:00 I 2.001 DHB I P 11/2/2005 00:00 - 01:00 1.00 CLEAN P 01:00 - 02:30 1.50 CLEAN P 02:30 - 03:00 0.50 CASE P 03:00 - 07:00 4.00 CASE P 07:00 - 08:00 1.00 CASE P 08:00 - 10:00 2.00 CASE P Start: 10/27/2005 Rig Release: 11/15/2005 Rig Number: Page 2 of 7 Spud Date: 2/13/1973 End: 11 /15/2005 Phase ~ Description of Operations DECOMP RU SWS &RIH with FasDrill bridge plug. Set plug @ 2069'. POH R/D SWS. Clear rig floor. DECOMP M/U 9 5/8" spear, Spear casing and pull 170K to free seal assy @ 2054', UWT = 155K. DECOMP Circ out arctic pack, pump 160 bbl 80 degree diesel followed by 35 bbl soap pill and clean seawater. Pump @ 260 gpm @ 600 psi. DECOMP Blow down lines. Pull casing to rig floor. DECOMP Release spear & UD. UD landing joint & XOs. Break out 10 3/4" casing pup and use as handling sub on thermo casing, UD 3 joints of thermo casing and 3 space out pups. Change out elevators and R/U power tongs & back-ups. DECOMP POH UD 10 3/4" casing, C/O handling equip. UD 9 5/8" casing and seal assy. Recovered 43 joints of 10 3/4" casing, 2 joints of 9 5/8" casing, 1, FO & 1, seal assy 14.10 long. All casing in good shape & seals on seal assy intact. DECOMP R/D tongs, handling equip & fishing tools. Clear & clean rig floor. DECOMP M/U BHA, P/U 9 5/8" polish mill, 13 3/8" casing scraper, junk basket, bumper sub, jars and drill collars to 324'. DECOMP RIH w/polish mill & 13 3/8" casing scraper P/U drill collars & HWDP to 972'. DECOMP RIH P/U drill pipe, tag bottom of PBR @ 2061'. DECOMP Polish PBR, circ soap pill followed by clean seawater. Pump @ 500 gpm @640 psi. DECOMP Close top pipe rams & test 13 3/8" X 9 5/8" packer and 13 3/8" casing to 3000 psi. DECOMP POH to 1065'. DECOMP M/U storm packer in string and set 5' below well head. Release running tool and POH. Test RTTS to 1000 psi. DECOMP N/D BOPE, remove # 2 annular valve, split bottom flanges and stand back BOP. DECOMP Remove old well head, bring new spool to cellar, prep casing head. DECOMP PJSM. Prep cellar for hot work. Cut & dress 13 3/8" casing stub. DECOMP Install McEvoy S3-YB intermideate spool w/19.5 X 13 3/8" YB bottom pack-off. Energize seals & test void to 1900 psi, hold test for 30 min, OK. DECOMP N/U 13 5/8" X 5000 psi BOPE. DECOMP Install test plug & test BOPlwell head flange against blind rams to 250/3500 psi, OK. Install wear ring. Break & UD test joint. DECOMP M/U storm packer running tool, RIH to top of packer & flush. Screw into & retreive Storm packer & release. POH & UD. Clear rig floor. DECOMP BHA, rack back HWDP, POH UD 9 drill collars. DECOMP Break & UD 13 3/8" casing scraper & 10.4" polish mill assy. DECOMP Pull wear ring. DECOMP R/U & run 9 5/8" 40# L-80 buttress casing with seal assy to 2017'. DECOMP Change bails on top drive. DECOMP M/U circ head, slack off while pumping to comfirm seal assy is in PBR: Space out, drop ball to open EZSV cementer. Slack off Printed: 11/21/2005 11:47:15 AM BP EXPLORATION Page 3 of 7 Operations Summary Report Legal Well Name: C-03 Common Well Name: C-03 Spud Date: 2/13/1973 Event Name: REENTER+COMPLETE Start: 10/27/2005 End: 11/15/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/15/2005 Rig Name: NABOBS 2ES Rig Number: Date I From - To I ~ Task Code NPT Phase Description of Operations - _ Hours 1 1- - - - -- - - ___ 11/2/2005 08:00 - 10:00 2.00 CASE P DECOMP & tag @ 2061'. M/U cement head. Pressure up to 2400 psi to shear cementer open. 10:00 - 12:00 2.00 CASE P DECOMP Pump 5 bbl water & test lines to 4500 psi. Pump 20 bbls mud push, followed by 129 bbl 15.8 ppg "class G" cement. Displace W/155.9 bbl of seawater, bump plug w/2100 psi. Bleed off & check floats held, OK. CIP @ 12:00 hrs. 12:00 - 15:00 3.00 CASE P DECOMP Pump 15 bbl seawater with cement retarder through BOP, kill line & annulus valves to cuttings tank. Blow down lines. R/D casing tools. Suck out 9 5/8" casing below ground level. Drain BOP stack & R/D circ lines in cellar. 15:00 - 21:00 6.00 WHSUR P DECOMP PJSM. N/D BOP, break flange @ wellhead & raise stack. Install 12" X 9 5/8" SB-3 slips on 9 5/8" casing with 90K tension. R/U Wachs casing cutter, cut pipe. Pull mouse hole & riser, set back BOP. Dress casing stub. Install McEvoy 13 5/8" X 5K 2 step tubing spool W/ 9 5/8° YBT BTTM pack-off. Energize YBT seals & test void to 2500 psi for 30 min, OK. 21:00 - 23:00 2.00 CASE P DECOMP N/U BOPE. Install secondary annulus valve on tubing spool. 23:00 - 00:00 1.00 CASE P DECOMP P/U test joint, install test plug. RILDS, test wellhead flange/BOP against blind rams to 250/3500 psi. 11/3/2005 00:00 - 01:00 1.00 CLEAN P DECOMP BOLDS. Pull test plug & install wear ring. 01:00 - 02:30 1.50 CLEAN P DECOMP M/U 8 1/2" bit, 9 5/8" casing scraper, 2 boot baskets & jars. P/U 9 drill collars, RIH with HWDP from derrick to 950'. 02:30 - 03:30 1.00 CLEAN P DECOMP RIH P!U drill pipe to 2038' . 03:30 - 08:00 4.50 CLEAN P DECOMP Drill cement, float equipment & FasDrill plug. From 2038' to 2077'. UWT = 95K, SWT = 90K, RWT = 95K. WOB = 15/30K. Torque = 3/4000K @ 80 rpm. Pump = 475 gpm @ 760 psi. 08:00 - 13:30 5.50 CLEAN P DECOMP RIH P/U drill pipe. Tag EZSV @ 8225' break circ. 13:30 - 14:30 1.00 CLEAN P DECOMP R/U up and test 9 5/8" casing to 3500 psi. Hold for 30 min, OK. 14:30 - 16:30 2.00 CLEAN P DECOMP Pump 45 bbl high vis sweep & displace well to 10.2 ppg LSND mud @ 510 gpm @ 2200 PSI. 16:30 - 18:00 1.50 CLEAN P DECOMP Cut & Slip drill line. Service top drive & drawworks. 18:00 - 21:00 3.00 CLEAN P DECOMP Pump dry job, POH from 8225' to 950' 21:00 - 23:00 2.00 CLEAN P DECOMP Stand back BHA. UD junk baskets, casing scraper, bit sub and jars. Clear rig floor. 23:00 - 00:00 1.00 STWHIP P WEXIT PJSM. M/U whipstock BHA. P/U jt of HWDP, window mills and bit sub. 11/4/2005 00:00 - 03:00 3.00 STWHIP P WEXIT P/U mills & MWD, orient, upload & pulse check. P/U whipstock & bumper sub. RIH with drill collars &HWDP to 1041'. 03:00 - 06:30 3.50 STWHIP P WEXIT RIH with whipstock assy to 8142'. Instal! blower hose on top drive. Orient 79 degrees left of high side, tag EZSV @ 8224'. UWT = 190K. DWT = 145K. 06:30 - 07:00 0.50 STWHIP P WEXIT Set down 18K and trip bottom anchor. P/U 15K and confirm. Set down 40K and shear lug. Obtain SPRs. 07:00 - 14:00 7.00 STWHIP P WEXIT Mill 9 5/8" casing window from 8202' to 8218'. Mill 20' of new formation to 8230'. WOB = 5 /12K. Torque = 8/10K @ 105 rpm. Pump @ 416 gpm @ 2000 psi. Recovered 170 # of metal during milling operations. 14:00 - 15:00 1.00 STWHIP P WEXIT Pump 45 bbl high vis/super sweep. Ream and work through window. 15:00 - 15:30 0.50 STWHIP P WEXIT Perform F.I.T. to 11.5 ppg EMW. TVD = 7351', OMW = 10.2 ppg, surface pressure 500 psi. 15:30 - 19:00 3.50 STWHIP P WEXIT POH to 1018'. 19:00 - 21:00 2.00 STWHIP P WEXIT Stand back HWDP. L/D drill collars & whipstock mills. Printed: 11/21/2005 11:47:15 AM BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: C-03 Common Well Name: C-03 Spud Date: 2/13/1973 Event Name: REENTER+COMPLETE Start: 10/27/2005 End: 11/15/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/15/2005 Rig Name: NABOBS 2ES Rig Number: Date ~ From - To {Hours Task ~~ Code NPT ~I Phase ,' Description of Operations 11/4/2005 21:00 - 22:00 1.00 STWHIP P WEXIT Remove wear ring, P/U ported sub and flush BOPE. 22:00 - 00:00 2.00 STWHIP N RREP WEXIT Work on rig air system. Purge drilling mud from system. 11/5/2005 00:00 - 00:30 0.50 BOPSU P WEXIT Install wear ring. 00:30 - 03:00 2.50 STWHIP P WEXIT P/U 8 1/2" BHA, PDC bit, mud motor, flex collars and MWD to 810'. RIH, shallow hole test @ 500 gpm @ 1250 psi. 03:00 - 05:30 2.50 STWHIP P WEXIT PJSM. RIH P/U drill pipe from shed, 811' to 3982'. 05:30 - 08:00 2.50 STWHIP P WEXIT RIH with drill pipe from 3982' to 8092'. Fill pipe @ 3000' intervals. 08:00 - 09:00 1.00 STWHIP P WEXIT Install top drive blower hose. Orient tool face 79 LHS @ 8092'. Take SPRs & drilling parameters. Slide through window @ 8202'. Ream under gauge hole from bottom of window to 8230'. 09:00 - 00:00 15.00 DRILL P INT1 Drilling from 8350' to 9060'. UWT = 185K, DWT = 145K, RWT = 165K. Pump @ 500 GPM @ 3200 psi, TO off bottom 7-8K, on 8/9 K, ART 6.24 hrs, AST 4.5 hrs 11/6/2005 00:00 - 07:00 7.00 DRILL P INT1 Drill 8 1/2" from 9060' to 9310'. HWT = 190K, DWT = 150K, RWT = 170K. Torque off bottom = 7500K, on = 9500. Pump @ 500 gpm @ 3300 psi. AST = 1.54, ART = 3.24. 07:00 - 08:00 1.00 DRILL P INT1 Circ for samples @ 9402'. Pump @ 500 gpm @ 3300 psi. 08:00 - 10:00 2.00 DRILL P INTi Drill from 9402' to 9410'. Circ for samples. Pump high vis sweep. Monitor well, static. 10:00 - 11:00 1.00 DRILL P INT1 Short trip. POH from 9410' to 9 5/8" window @ 8202'. Hole in good shape. Monitor well, static, mud weight in & out = 10.2 ppg. Blow down top rive. 11:00 - 13:00 2.00 DRILL P INT1 Cut & slip drill line. Adjust brakes. Service rig. 13:00 - 14:30 1.50 DRILL N RREP INT1 Replace air valve on crown saver. Rebuild quick release valves on high and low drum clutches. 14:30 - 15:30 1.00 DRILL P INTi RIH to bottom @ 9410'. 15:30 - 17:00 1.50 DRILL P INT1 Pump high vis sweep and circ out. Spot liner running pill. Monitor well, stable. Mud weight in and out = 10.2 ppg. Drop 2" drill pipe drift. 17:00 - 18:00 1.00 DRILL P INTi POH to 9 5/8" window @ 8202'. Monitor well, stable. 18:00 - 21:00 3.00 DRILL P INTi Pump dry job. POH for 7" liner to BHA @ 811'. 21:00 - 23:30 2.50 DRILL P INT1 L/D HWDP, jars & drill collars. Down load MWD & pull pulsar. Break & L/D MWD, mud motor & bit. Clear & clean rig floor. 23:30 - 00:00 0.50 CASE P LNR1 R/U to run 7" 26# L-80 BTC-M liner. 11/7/2005 00:00 - 02:00 2.00 CASE P LNR1 P/U 7" float equip, fill pipe & check floats. RIH with 7" 26# L-80 BTC-M liner to 1332'. 02:00 - 02:30 0.50 CASE P LNRi P/U 7" liner hanger, packer & 1 stand of drill pipe to 1481'. 02:30 - 03:00 0.50 CASE P LNR1 Circulate liner volume, pump @ 6.5 bbl @ 200 psi. UWT = 62K, DWT = 60K. 03:00 - 06:30 3.50 CASE P LNR1 RIH with liner on drill pipe from 1481' to 8202'. Fill pipe @ 930' intervals. 06:30 - 07:00 0.50 CASE P LNR1 Circ liner & DP volume @ 8,202'. Pump @ 8 BPM @ 1150 psi. UWT = 170K, DWT = 125K. Blow down top drive. 07:00 - 07:30 0.50 CASE P LNR1 RIH from 8202' to 9385', hole in good shape. 07:30 - 08:00 0.50 CASE P LNR1 M/U cement head, manifold & hoses. Tag bottom @ 9410' 08:00 - 09:00 1.00 CEMT LNR1 Stage pump up to 5 BPM @ 850 psi. PJSM 09:00 - 11:00 2.00 CEMT P LNR1 Pump 5 bbl water, test lines to 4500 psi, pump 20 bbl 11.8 ppg mud push followed by 57 bbl 15.8 ppg class G cement. Flush lines with mud. Drop wiper plug. Dowell displace cement 128 bbl. Bump plug to 4,000 psi. Set down 70K on hanger. Bleed off pressure, check floats, OK. CIP 10:45 HRS Printed: 11/21/2005 11:47:15 AM BP EXPLORATION Operations Summary Report Page 5 of 7 Legal Well Name: C-03 Common Well Name: C-03 Spud Date: 2/13/1973 Event Name: REENTER+COMPLETE Start: 10/27/2005 End: 11/15/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 11/15/2005 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code 11/7/2005 11:00 - 12:00 1.00 CEMT P 12:00 - 13:00 1.00 CEMT P 13:00 - 13:30 0.50 CEMT P 13:30 - 16:30 3.00 CEMT P 16:30 - 18:00 1.50 CEMT P 18:00 - 20:00 2.00 DRILL P 20:00 - 23:30 3.50 DRILL P 23:30 - 00:00 0.50 DRILL P 11/8/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 03:00 2.50 DRILL P 03:00 - 04:30 1.50 DRILL P 04:30 - 05:30 1.00 DRILL P 05:30 - 06:00 0.50 DRILL P 06:00 - 00:00 I 18.001 DRILL I P 11/9/2005 100:00 - 12:30 I 12.501 DRILL I P 12:30 - 13:00 I 0.501 DRILL I P 13:00 - 14:00 1.00 DRILL P 14:00 - 15:00 1.00 DRILL P 15:00 - 17:30 2.50 DRILL P 17:30 - 19:00 1.50 DRILL P 19:00 - 21:30 I 2.501 DRILL I P 21:30 - 00:00 2.50 DRILL P 11/10/2005 00:00 - 01:00 1.00 DRILL P 01:00 - 02:00 1.00 DRILL P 02:00 - 07:30 5.50 DRILL P 07:30 - 00:00 I 16.501 DRILL I P 11/11/2005 100:00 - 10:00 I 10.001 DRILL I P NPT ~ Phase ~ Description of Operations LNR1 Rotate 15 turns to the right, pressure up to 1000 psi, unsting from liner, circ 500 strokes. Set down 60K to set liner packer, good surface indication. Rotate down 2 times & set 70K down to confirm. CBU 10 bpm @ 3150 psi. LNR1 Break & UD cement head, blow down lines, R/D. LNRi Service top drive. LNR1 POH, UD liner running tools. LNR1 Clear rig floor. Bring BHA tools to rig floor. PROD1 M/U bit, motor, &MWD. Orient & up load MWD, P/U &RIH with drill collars, jars & HWDP to 352' PROD1 RIH to 9317' PROD1 Test casing to 3500 PSI for 30 min, OK. PROD1 Test 7" x 9 5/8" casing to 3,500 psi for 30 min. Held. Blow down surface equipment. Install blower hose. PROD1 Drill cement & float equipment from 9,324' to 9,408'. Up 195K, DN 125K, RT 155K, TO 7 -8K 280 gpm @ 2,020 psi. PROD1 Displace well to 8.4 ppg FloPro mud. Pump 100 bbl water, 45 bbl sweep followed by mud - 280 gpm Q 1,350 psi. PROD1 Take SPRs. Drill 7" casing shoe and 20' of new formation to 9,430'. CBU. Pull into 7" csg. PRODi Perform F.I.T. test to 9.8 ppg EMW @ 8,367' TVD, with 8.4 ppg mud and 610 psi surface pressure. PROD1 Dir. Drill from 9,430' to 9,970'. AST = 10.59 hrs, ART = 2.41 hrs, UP 180K, DN 148K, RT 168K, TO 6.5 - 7.0 K, 275 gpm 1,480 psi. PROD1 Dir Drill from 9,970' to 10,367'. ART = 4.34 hrs, AST = 4.96 hrs. UP 195K, DN 148K, RT 168k, TO 6 - 7K, 275 gpm Q 1,650 psi. PROD1 Circulate 2 open hole volumes - 274 gpm ~ 1,480 psi. MW in 8.4 ppg, MW out 8.4 ppg -flow check well. PROD1 POOH to 9,410' (pulled 20k over @ 10,169'). Flow check. PROD1 Drop dart -open pump out sub - CBU Q 500 gpm 1,415 psi. Slug DP. PROD1 POOH with 4" DP. PROD1 Pull BHA. Break off bit, down load LWD's. L.D. LWD /MWD / motor. Function blind rams /pipe rams. PROD1 M/U Bit, Motor,& MWD. Orient, P/U DGR & EWR, P/U CTN / ALD & TM HOC, up load MWD. Pulse check MWD ,Load nukes, Continue to RIH W/ BHA to 378' PROD1 RIH to 7941'. PROD1 RIH to 9,410'. PROD1 Service Top Drive and Drawworks. PROD1 RIH to 9,880'. Mad pass log 150 fph from 9,880' to 10,100' - 180 gpm @ 1,050 ps, 15 RPM. Bit taking wt /differential increase C~3 10,100'. Spudded thru tight spot at 10,100' and ran to bottom @ 10,367'. Mad pass log up C~ 150' fph from 10,367' - 10,200' - 260 gpm Q 1,550 psi. Up 195k,DN 150K, RT 164K, T05.5-6.5K. PRODi DRLG F/10,367' T/11,157'. ART = 4.35 hrs, AST = 4.38 hrs. Up 190k, DN 140k, Rot 165k, TO off 6/7.5k, on 7/8k, 300gpm Q2000 GPM. PROD1 Drill from 11,157' - 11,635'. AST = 1.34 hrs, ART = 5.19 hrs. UP 190K, DN 140K, RT 165K, TO off 6 - 7.5k, TO on 7-8K, Printed: 11/21/2005 11:47:15 AM r~ u BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: Page 6 of 7 C-03 C-03 Spud Date: 2/13/1973 REENTER+COMPLETE Start: 10/27/2005 End: 11/15/2005 NABOBS ALASKA DRILLING I Rig Release: 11/15/2005 NABOBS 2ES Rig Number: Date From - To Hours Task ' Code ~ NPT ~_ ~ l 11/11/2005 ~ 00:00 - 10:00 ~ 10.001 DRILL ~ P 10:00-12:00 ~ 2.OO~DRILL ~P 12:00 - 12:30 0.50 DRILL P 12:30 - 16:30 4.00 DRILL P 16:30 - 17:00 0.50 DRILL P 17:00 - 18:00 1.00 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 19:30 1.00 DRILL P 19:30 - 20:30 1.00 DRILL P 20:30 - 21:30 1.00 DRILL P 21:30 - 22:30 I 1.001 DRILL I P 22:30 - 00:00 1.50 DRILL P 11/12/2005 00:00 - 02:30 2.50 DRILL P 02:30 - 05:00 2.50 DRILL P 05:00 - 06:00 1.00 CASE P 06:00 - 08:30 2.50 CASE P 08:30 - 09:30 I 1.001 CASE I P 09:30 - 10:00 0.50 CASE P 10:00 - 15:00 5.00 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 17:00 1.50 CASE P 17:00 - 17:30 0.50 CASE P 17:30 - 18:00 I 0.501 CEMT I P 18:00 - 19:30 I 1.501 CEMT I P 19:30 - 20:00 I 0.501 CEMT 1 P 20:00 - 22:30 2.50 CEMT P 22:30 - 23:00 0.50 CEMT P 23:00 - 00:00 1.00 CEMT P 11/13/2005 00:00 - 03:00 3.00 CEMT P 03:00 - 07:30 I 4.501 PERFOBI P Phase Description of Operations PROD1 2,050 psi C«? 300 gpm. Problems sliding -.pumping lub pills w/ glass beads /nut plug. PROD1 CBU -Pump hi vis sweep around - 300 gpm @ 2,020 psi. Flow check. MW in 8.5 ppg, MW out 8.5 ppg. PROD1 Wiper trip -POOH to 10,860'. PRODi Mad pass log from 10,860' to 10,440' - 150 fph. PROD1 POOH from 10,440' to 9,410'. PROD1 Slip and cut drilling line. PROD1 Lubricate rig and Top Drive. PROD1 RIH to 11,635'. No problems -hole in good shape. PROD1 Circ hi vis sweep into csg - 300 gpm Q 2,000 psi. PROD1 POOH to run 4 1/2" liner -pulled to 9,400'. Open hole in good shape. PROD1 Drop dart and open circ sub. Circ sweep out 550 gpm C~3 1,680 psi. PROD1 POOH w/ DP to 5,974'. PROD1 POOH to BHA. Change handling tools. PROD1 L.D. BHA - HWDP, jars, flex collars. PJSM. Remove RA source. Down load LWD's. Finish laying down BHA. Clear rig floor. RUNPRD PJSM. R.U. handling tools to run 4 1/2" liner. RUNPRD PJSM. M.U. float joints. Check floats. P.U. total 58 jts 4 1/2' 11.6# L80 LT&C liner. RUNPRD Change elevator!. M.U. Baker 5" x 7' liner hanger /packer. RD csg tools and clear floor. RUNPRD MU stand DP. Circ liner volume. 5 bpm @ 160 psi. RUNPRD RIH with 4 1/2"' liner on DP to 9,410'. Fill every 10 stands. RUNPRD Circ DP and liner volume 6 bpm C~3 550 psi. RUNPRD RIH with 4.5" liner from 9,410' to 11,620'. No problems. RUNPRD M.U. cementing head and hoses. Fill pipe and tag bottom C~ 11,635'. Recipicate pipe. 185k up, 125k DN. RUNPRD Circ and stage pumps up to 6 bpm 1,040 psi. Recipicate pipe. PJSM. RUNPRD Test lines to 4,500 psi. Schlumberger cemented -pumped 15 bbls CW 100, 25 bbls mud push 2 @ 9.5 ppg, 62 bbls Class "G" cement @ 15.8 ppg (298 sx). Washed out pump and lines. Displaced with 35 bbls pert pill / 92 bbls mud Q 5 - 6 bpm. Unable to recipicate. Liner stuck 5' off bottom with 7 bbls cement out shoe.Bumped plug 4,000 psi / CIP @ 19:15 hrs. Full returns throughout job. Set wt on hanger. Bled off -floats held. Set packer w/ 50K -good surface indication pkr set. RUNPRD Pressure to 1,000 psi and pulled running tool out of liner. Circ bottoms up @ 550 gpm 2,950 psi -circ out 18 bbls cement. RUNPRD Displace well to 8.5 ppg seawater 485 gpm @ 2,780 psi. RUNPRD L.D. cementing head and blow down all lines. RUNPRD POOH with running tool to 7,000'. RUNPRD POOH with running tool -lay down running tool (Test choke manifold ). OTHCMP Pull wear ring and set test plug.. Test BOP's as per BP policy to 250 psi low and 3,500 psi high. Test witness waived by John Crisp w/ AOGCC. Test witnessed by Jimmy Henson -Nabors, Mike Whiteley &John Rall - BP. Pull test plug and install wear ring. Blow down surface equipment. All rams were functioned. Printed: 11/21!2005 11:47:15 AM • BP EXPLORATION Operations Summary Report Legal Well Name: C-03 Common Well Name: C-03 Event Name: REENTER+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 2ES Date From - To i Hours ' Task Code' NPT Start: 10/27/2005 Rig Release: 11/15/2005 Rig Number: Phase Page 7 of 7 Spud Date: 2/13/1973 End: 11 /15/2005 Description of Operations ,_- - - _ -- 11/13/2005 07:30 - 08:00 ~ 0.50 ~ PERFOB P ~ OTHCMP Test csg against blind rams to 3 500 psi for 30 min. Lost 100 08:00 - 09:00 1.00 PERFO P 09:00 - 10:30 1.50 PERFO P 10:30 - 12:00 1.50 PERFO P 12:00 - 18:00 6.00 PERFO P 18:00 - 19:00 1 1.001 PERFOBI P 19:00 - 19:30 I 0.501 PERFOBI P 19:30 - 00:00 I 4.501 PERFOBI P 11/14/2005 00:00 - 01:30 1.50 PERFO~ P 01:30 - 03:30 2.00 PERFO P 03:30 - 08:00 4.50, PERFO P 08:00 - 09:00 1.00 PERFO P 09:00 - 11:30 2.50 PERFO P 11:30 - 13:00 1.50 BUNCO 13:00 - 21:00 8.00 BUNCO 21:00 - 22:00 ~ 1.00 ~ RUN 22:00 - 00:00 I 2.001 RU 11/15/2005 00:00 - 02:00 2.00 RUN 02:00 - 04:00 2.00 RUN 04:00 - 04:30 0.50 BUNCO 04:30 - 05:00 0.50 BOPSU P 05:00 - 07:00 2.00 BOPSU P 07:00 - 10:00 3.00 WHSUR P 10:00 - 11:00 1.00 WHSUR P 11:00-15:00 4.00 WHSUR P 15:00 - 16:00 I 1.00 I W HSUR I P psi. OTHCMP PJSM. RU handling tools for pert guns. OTHCMP P.U. 2 7/8" pert guns and firing head (1,241'). OTHCMP RIH picking up 36 jts 2 7/8" PAC DP. OTHCMP RIH with 2 7/8" pert gun on 4" DP. Tagged up C~ 11,541'. Pulled up and spotted bottom shot Ca? 11,530'. OTHCMP PJSM. Break circ. Close rams. Pressure up on csg / DP to 2,500 psi. Bled pressure off. Guns fired. Perforated Ivishak f/ 11,530' - 11,440' and 11,230' - 10,320' w/ 4 spf. Fluid level dropped 15' in annulus - 8.5 ppg seawater in hole. OTHCMP POOH w/ 15 stands to 10,311'. Hole took 13 bbls water.Slug DP /blow down. Observe well 15 min. -static. OTHCMP POOH laying down 4" DP to 4,229'. Hole taking 2 bbls / hr seawater. OTHCMP POOH laying down 4" DP. OTHCMP Change out handling tools. PJSM. L.D. 36 jts 2 7/8" PAC DP. OTHCMP PJSM. R.U. handling tools for pert guns. POOH laying down 2 7/8" pert guns. All guns fired. Clean and clear rig floor. Perf interval - 10,320' - 11,230', 11,440' - 11,530'. OTHCMP MU mule shoe sub -RIH w/ 3,800' 4" DP. OTHCMP POOH laying down 4" DP & mule shoe sub. RUNCMP PJSM. RU tubing handling equipmen RUNCMP MU tailpipe and packer. RIH picking up 217 jts 4.5" 12.6# L80 IBTM tubing and GLM's. UP 135K, DN 105k. RUNCMP Space out. MU tbg hanger. Land tbg hanger (75k). RILDS. Back out landing jt. RUNCMP RU and test circ line. Reverse circ 8.5 ppg inhibited seawater for packer fluid @ 3bpm. RUNCMP Reverse circ inhibited 8.5 ppg seawater for packer fluid. RUNCMP Pressure tbg to 3,500 psi and set packer. Held 30 min for tbg test. Bled tbg pressure to 1,600 psi. Pressure csg to 3,500 psi. Held 30 min for packer /csg test. Lost 40 psi in 30 min. Bled tbg press off and sheared DCR valve. RUNCMP Set TWCV and test to 1,000 psi from below. Held. RUNCMP Drain stack. Blow down.PJSM. RUNCMP ND BOP's. RUNCMP NU Tree & adaptor flange. Test tree and adaptor to 5,000 psi. Held. RUNCMP Pull TWCV w/lubricator. RUNCMP RU circ lines. Rev circ 155 bblsl diesel. U-tube. Set BPV and test from below to 1,000 psi. RUNCMP ND second annular valve. Secure well. Released rig @ 1600 hs 11-15-2005. Printed: 11/21/2005 11:47:15 AM Halliburton Sperry-Sun North Slope Alaska BPXA C-03B Job No. AKZZ4030881, Surveyed: 11 November, 2005 Survey Report 1 December, 2005 Your Ref.• API 500292012402 Surface Coordinates: 5959906.00 N, 664500.00E (70° 17' 48.3749" N, 148° 40' 04.2745" VV) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing Elevation: 63.66ft above Mean Sea Level ~G t"'~i"'""'~i~-5lJI"'1 ~~k~-~-~N~ ~~Fty~~~~ Survey Ref:svy4763 A Ha}IPburton ConapBny • Halliburton Sperry-Sun Survey Report for C-038 Your Ref.• API 500292012402 Job No. AKZZ4030881, Surveyed: 11 November, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Locat Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 8189. 16 31. 180 62. 150 7267.50 7331. 16 1723 .60 N 2182. 38E 5961676.96 N 666644.13E 2653.26 Tie On Point M W D+I I FR+MS 8202. 00 31. 370 62. 380 7278.47 7342. 13 1726 .70 N 2188. 28E 5961680.19 N 666649.96E 1.748 2659.14 Window Point 8246. 06 31. 200 60. 020 7316.13 7379. 79 1737 .72 N 2208. 32E 5961691.64 N 666669.76E 2.808 2679.54 8315. 29 31. 040 56. 270 7375.40 7439. 06 1756 .60 N 2238. 70.E 5961711.18 N 666699.72E 2.809 2712.24 8407. 90 30. 980 51. 210 7454.79 7518. 45 1784 .79 N 2277. 15E 5961740.21 N 666737.54E 2.815 2757.19 8470. 24 31. 060 47. 250 7508.22 7571. 88 1805 .76 N 2301. 46E 5961761.70 N 666761.39E 3.276 2788.21 8501. 39 31. 420 51. 530 7534.86 7598. 52 1816 .27 N 2313. 72E 5961772.48 N 666773.41E 7.218 2803.79 8592. 92 31. 710 53. 470 7612.85 7676. 51 1845 .43 N 2351. 73E 5961802.46 N 666810.78E 1.154 2849.30 8685. 52 32. 840 61. 570 7691.17 7754. 83 1871 .88 N 2393. 39E 5961829.82 N 666851.84E 4.824 2894.61 8781. 07 33. 290 64. 500 7771.26 7834. 92 1895 .51 N 2439. 84E 5961854.46 N 666897.77E 1.738 2940.30 8875. 17 32. 970 64. 140 7850.06 7913. 72 1917 .79 N 2486. 19E 5961877.75 N 666943.62E 0.399 2984.81 8967. 17 32. 720 66. 380 7927.35 7991. 01 1938 .68 N 2531. 50E 5961899.62 N 666988.46E 1.348 3027.58 9061. 70 32. 840 61. 450 8006.84 8070. 50 1961 .17 N 2577. 43E 5961923.11 N 667033.89E 2.826 3072.03 9154. 50 33. 310 61. 940 8084.61 8148. 27 1985 .18 N 2622. 02E 5961948.09 N 667077.94E 0.583 3116.98 9248. 47 32. 310 59. 030 8163.59 8227. 25 2010 .24 N 2666. 33E 5961974.12 N 667121.69E 1.987 3162.64 9342. 07 31. 790 59. 830 8242.92 8306. 58 2035. 51 N 2709. 09E 5962000.31 N 667163.89E 0.717 3207.60 9437. 05 30. 360 65. 880 8324.29 8387. 95 2057. 89 N 2752. 64E 5962023.65 N 667206.94E 3.614 3250.63 9469. 00 25. 190 68. 390 8352.55 8416. 21 2063 .70 N 2766. 34E 5962029.76 N 667220.51E 16.587 3263.14 9501. 86 19. 220 71. 950 8382.96 8446. 62 2067 .96 N 2778. 00E 5962034.27 N 667232.07E 18.616 3273.22 9531. 99 14. 470 80. 850 8411.80 8475. 46 2070 .09 N 2786. 44E 5962036.59 N 667240.46E 17.896 3279.74 9562. 50 10. 580 91. 230 8441.58 8505. 24 2070 .64 N 2793. 00E 5962037.28 N 667247.01E 14.682 3283.89 9594. 32 7. 870 113. 650 8472.99 8536. 65 2069 .70 N 2797. 92E 5962036.45 N 667251.95E 13.994 3285.88 9624. 81 8. 910 144. 960 8503.17 8566. 83 2066 .93 N 2801. 19E 5962033.75 N 667255.28E 15.162 3285.43 9656. 72 11. 820 168. 600 8534.57 8598. 23 2061 .70 N 2803. 26E 5962028.56 N 667257.46E 15.968 3282.27 9687. 50 15. 210 187. 640 8564.51 8628. 17 2054 .60 N 2803. 34E 5962021.47 N 667257.70E 18.035 3276.46 9718. 41 16. 370 193. 170 8594.25 8657. 91 2046 .34 N 2801. 81E 5962013.18 N 667256.35E 6.143 3268.77 9749. 68 16. 560 194. 020 8624.24 8687. 90 2037 .73 N 2799. 73E 5962004.52 N 667254.46E 0.981 3260.47 9784. 08 16. 920 205. 130 8657.19 8720. 85 2028 .44 N 2796. 42E 5961995.16 N 667251.35E 9.347 3250.93 9813. 17 17. 920 218. 470 8684.96 8748. 62 2021 .10 N 2791. 83E 5961987.72 N 667246.93E 14.120 3242.28 9843. 60 20. 050 232. 610 8713.75 8777. 41 2014 .26 N 2784. 77E 5961980.73 N 667240.02E 16.607 3232.66 9876. 11 24. 730 243. 220 8743.81 8807. 47 2007 .81 N 2774. 26E 5961974.05 N 667229.65E 18.968 3221.41 9906. 80 29. 650 246. 240 8771.10 8834. 76 2001 .85 N 2761. 57E 5961967.82 N 667217.10E 16.645 3209.34 9936. 81 33. 050 248. 070 8796.73 8860. 39 1995 .80 N 2747. 18E 5961961.45 N 667202.84E 11.764 3196.24 9968. 87 37. 400 250. 230 8822.91 8886. 57 1989 .24 N 2729. 90E 5961954.52 N 667185.71E 14.112 3181.09 9999. 88 42. 830 253. 150 8846.62 8910. 28 1983 .00 N 2710. 94E 5961947.86 N 667166.88E 18.528 3165.24 ~, • 1 December, 2005 - 7:53 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for C-038 Your Ref.• API 50029 2012402 Job No. AK2Z4030881, Surveyed: 11 November, 2005 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) (°/100ft) 10029 .96 48 .710 256 .060 8867.60 8931 .26 1977.30 N 2690.16E 5961941.71 N 667146.24E 20.737 3148.84 10062 .67 54 .680 258 .840 8887.86 8951 .52 1971.75 N 2665.12E 5961935.62 N 667121.32E 19.429 3130.16 10093 .45 59 .230 260 .890 8904.65 8968 .31 1967.23 N 2639.73E 5961930.53 N 667096.04E 15.800 3112.12 10122 .67 64 .890 261 .110 8918.33 8981 .99 1963.19 N 2614.24E 5961925.94 N 667070.64E 19.382 3094.43 10156 .25 72 .390 261 .180 8930.55 8994 .21 1958.38 N 2583.36E 5961920.46 N 667039.88E 22.336 3073.07 10188 .95 78 .690 261 .380 8938.71 9002 .37 1953.59 N 2552,08E 5961914.98 N 667008.71E 19.275 3051.49 10218 .45 83 .510 261 .090 8943.28 9006 .94 1949.14 N 2523.28E 5961909.91 N 666980.02E 16.368 3031.60 10250 .72 84 .190 261 .600 8946.73 9010 .39 1944.32 N 2491.56E 5961904.39 N 666948.41E 2.629 3009.75 10281 .69 84 .250 261 .690 8949.85 9013 .51 1939.84 N 2461.08E 5961899.24 N 666918.03E 0.348 2988.89 10312 .47 84 .560 260 .600 8952.85 9016 .51 1935.12 N 2430.81E 5961893.87 N 666887.87E 3.665 2967.95 10334 .59 85 .430 258 .730 8954.78 9018 .44 1931.17 N 2409.13E 5961889.44 N 666866.29E 9.295 2952.47 10367 .61 87 .660 258 .820 8956.77 9020 .43 1924.76 N 2376.81E 5961882.32 N 666834.11E 6.759 2928.97 10399 .31 90 .310 259 .730 8957.34 9021 .00 1918.86 N 2345.67E 5961875.74 N 666803.11E 8.839 2906.56 10429 .76 90 .930 260. 000 8957.01 9020 .67 1913.50 N 2315.70E 5961869.73 N 666773.26E 2.221 2885.26 10461 .28 91 .600 259. 040 8956.31 9019 .97 1907.77 N 2284.71E 5961863.32 N 666742.41E 3.713 2863.07 10492 .72 93 .270 257. 050 8954.97 9018 .63 1901.26 N 2253.98E 5961856.14 N 666711.83E 8.258 2840.39 10523 .04 93 .460 257. 290 8953.19 9016 .85 1894.54 N 2224.47E 5961848.78 N 666682.47E 1.009 2818.22 10555 .10 93 .270 257. 440 8951.31 9014 .97 1887.54 N 2193.24E 5961841.09 N 666651.40E 0.755 2794.85 10586 .13 91 .610 256. 880 8949.99 9013 .65 1880.65 N 2163.02E 5961833.54 N 666621.33E 5.645 2772.14 10616 .49 89 .750 256. 420 8949.63 9013 .29 1873.64 N 2133.48E 5961825.89 N 666591.96E 6.311 2749.71 10664 .50 89 .880 255 .920 8949.79 9013 .45 1862.17 N 2086.86E 5961813.40 N 666545.60E 1.076 2713.98 10709 .43 90 .060 257 .790 8949.81 9013 .47 1851.95 N 2043.11E 5961802.22 N 666502.09E 4.181 2680.90 10760 .31 90 .190 258 .160 8949.70 9013 .36 1841.35 N 1993.35E 5961790.54 N 666452.57E 0.771 2644.12 10803 .57 91 .480 258 .170 8949.07 9012 .73 1832.48 N 1951.01E 5961780.74 N 666410.44E 2.982 2612.95 10853 .29 92 .160 258 .260 8947.49 9011 .15 1822.33 N 1902.36E 5961769.53 N 666362.02E 1.380 2577.17 10898 .51 92 .650 258 .120 8945.59 9009 .25 1813.08 N 1858.14E 5961759.32 N 666318.01E 1.127 2544.62 10942 .43 92 .650 259 .330 8943.56 9007 .22 1804.50 N 1815.12E 5961749.80 N 666275.18E 2.752 2513.31 10991 .07 91 .230 261 .710 8941.91 9005 .57 1796.50 N 1767.17E 5961740.75 N 666227.43E 5.695 2479.70 11038 .41 90 .620 261 .370 8941.15 9004 .81 1789.53 N 1720.35E 5961732.76 N 666180.77E 1.475 2447.58 11083 .89 89 .750 261 .280 8941.00 9004 .66 1782.67 N 1675.39E 5961724.92 N 666135.97E 1.923 2416.59 11131 .16 88 .270 262 .750 8941.82 9005 .48 1776.11 N 1628.59E 5961717.33 N 666089.33E 4.413 2384.81 11176 .60 88 .950 263 .410 8942.92 9006 .58 1770.64 N 1583.50E 5961710.87 N 666044.36E 2.085 2354.90 11223 .82 88 .150 263. 610 8944.12 9007 .78 1765.30 N 1536.60E 5961704.51 N 665997.59E 1.746 2324.08 11268 .57 89 .140 264. 010 8945.18 9008 .84 1760.48 N 1492.12E 5961698.71 N 665953.23E 2.386 2295.05 11300 .13 89 .570 263. 490 8945.53 9009 .19 1757.04 N 1460.75E 5961694.59 N 665921.94E 2.138 2274.54 BPXA • • 1 December, 2005 - 7:53 Page 3 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for C-036 Your Ref.• API 50029 2012402 Job No. AKZZ4030881, Surveyed: 11 November, 2005 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) (°/100ft) 11330.34 89.570 263 .150 8945. 76 9009.42 1753.53 N 1430.75E 5961690.42 N 665892.02E 1.125 2254.75 11361.97 89.810 262 .020 8945. 93 9009.59 1749.44 N 1399.38E 5961685.65 N 665860.75E 3.652 2233.71 11393.60 91.420 262 .240 8945. 59 9009.25 1745.11 N 1368.05E 5961680.64 N 665829.53E 5.137 2212.49 11424.29 91.910 261 .730 8944. 70 9008.36 1740.84 N 1337.67E 5961675.70 N 665799.25E 2.304 2191.85 11454.86 92.220 262 .020 8943. 60 9007.26 1736.52 N 1307.43E 5961670.72 N 665769.11E 1.388 2171.25 11488.44 92.900 262 .030 8942. 10 9005.76 1731.86 N 1274.21E 5961665.34 N 665736.00E 2.025 2148.70 11520.39 93.090 261 .760 8940. 43 9004.09 1727.37 N 1242.62E 5961660.15 N 665704.52E 1.032 2127.20 11551.21 93.580 262 .000 8938. 63 9002.29 1723.02 N 1212.16E 5961655.14 N 665674.16E 1.770 2106.45 11580.87 93.950 262 .120 8936. 69 9000.35 1718.93 N 1182.85E 5961650.41 N 665644.94E 1.311 2086.57 11603.31 94.140 261 .560 8935. 10 8998.76 1715.75 N 1160.69E 5961646.75 N 665622.86E 2.629 2071.47 11635.00 94.140 261 .560 8932. 82 8996.48 1711.12 N 1129.43E 5961641.43 N 665591.70E 0.000 2050.03 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 34.270° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 11635.OOft., The Bottom Hole Displacement is 2050.25ft., in the Direction of 33.427° (True). n ,........,...... s.. Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8189.16 7331.16 1723.60 N 2182.38 E 8202.00 7342.13 1726.70 N 2188.28 E 11635.00 8996.48 1711.12 N 1129.43 E Comment Tie On Point Window Point Projected Survey BPXA • r: 1 December, 2005 - 7:53 Page 4 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for C-03B Your Ref.• API 500292012402 Job No. AKZZ4030881, Surveyed: 11 November, 2005 North Slope Alaska BPXA Survey tool program for C-03B From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 8189.16 7331.16 BP High Accuracy Gyro - GYD-CT-CMS (C-03) 8189.16 7331.16 11635.00 8996.48 MWD+IIFR+MS (C-036) • • 1 December, 2005 - 7:53 Page 5 of 5 DrillQuest 3.03.06.008 = 4-1/1i HEAD '~ Mc AC:IUAIUK= VIIJ ___., KB. ELEV - .54,46' BF. ELEV = 35.16' KOP = 3000' Max Angle = 94 @ 11603' Datum MD = 9964' TLH DRAFT C ~O 3 B Datum TV D = 8800' SS 20" CSG 80' 1-1/2" TBG 1814' TOP OF 9-5/8" LNR 2043' 9-5/8" CSG, 40#, L-80 BTC, ID = 8.835" 30'-2068' 18-5/8" CSG, ??#, ???, ID = ?.???" ( 2524' 13-3/8" CSG, 72#, L-80, ID = 12.347" 4331' Minimum ID = 3.725" @ 9249' 4-1/2" HES XN NIPPLE 9-5/8"MILL®WINDOW (C-03B) 8202' - 8218' WHIPSTOCK (11/04/05) 8142' ~EZSV PLUG (10/31/05) ~ 8225' 5-1/2" TBG, 17#, L-80, ID=4.892" -{ 9155' TOP OF 7" LNR (40' BOT PBR) ~ 9218' 3.75" DEPLOYMENT SLV, ID = 3.00" 9219' TOP OF 2-7/8" LNR IUD -- 2.37" 9223' 4-1/2" TBG,12.6#, L-80, ID = 3.958" 9291' 9-518" LNR, 47#, N-80, ID = 8.681" 9749' 7" LNR, 29#, N-80, ID = 6.184" 10250' 2-7/8" LNR, 6.16#, STL, ~ = 2.37" 12153' PERFORATION SUMMARY REF LOG: GR/CNL ON 10/13/98 ANGLE AT TOP PERF: 85 @ 10320' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 4 10320 - 11230 O 11/14/05 2-7/8" 4 11440 - 11530 O 11/13/05 S OTES: ORIGINAL WELLBORE (C-03) IS NOT OW N ON DIAGRAM. 2039' --~ 9-5/8" EZ CEMENTER 2054' 9-5/8" SEAL ASSY 2059' 13-3/8" X 9-5/8" BOT PKR /LNR HGR 2074' 9-5l8" FOC 2138' 13-3/8" FOC 2206' 4-1/2" HES X NIP, ID = 3.813" 2332' 13-3/8" FOC GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3308 3295 18 MMG DOME RK 16 11/28/05 3 6120 5599 36 MMGM SO RK 20 11 /28/05 2 8014 7182 31 MMGM DMY RK 0 11/13/05 1 9114 8114 33 KG62 DMY BK 0 11/13/05 8303' 9-5/8" FOC 8054' 9-5l8" X 7" BKR C2 ZXP LTP w /TIEBK SLV, ID = 6.30" 847'{' 9-518" X 7" BKR HMC LNR HNGR, ID = 6.23" 9184' 4-1/2" HES X NIP, ID = 3.813", 9205' 7" X 4-1/2" BKR PKR, ID = 3.875" 922$' 4-1/2" HES X NIP, ID = 3.813" 9249' -{4-112" HES XN NIP, ID = 3.725 9250' 7" x 5" BKR HRD ZXP LTP wlTIEBK SLV, ID = 4.41" 9261' a-v2" wLEG 9270' RS P'O NIP, ID 4.25", 9272' 7" X 5" BKR HMC LNR HNGR, ID = 4.42" 9279' S" X 4-1 /2" XO, ID = 3.960" 4-1/2" TBG, 12.6#, L-80 IBT-MITCII, ~ 9261' I .0152 bpf, ID = 3.958" 7" LNR 26#, L-80 BTGM, .0383 bpf, ID = 6.276" 9410' PBTD 4-1/2" LNR 12.6#, L-80 IBT-M, .0152 bpf, ID = 3.958" -~ DATE REV BY COMMENTS DATE REV BY COMMENTS 03126173 ORIGINAL COMPLETION 10/05/87 RWO 10/14/98 GTD SIDETRACK (C-03A) 11/15105 N4ES SIDETRACK(C-03B) 11/28/05 KSB/TLH GLV GO 12/03/05 ???/TLH DRLG DRAFT CORRECTIONS PRUDHOE BAY UNfT WELL: G036 PERMIT No: 2b501580 API No: 50-029-20124-01 SEC 19, T11 N, R14E, 1316' SNL & 879' WEL BP 6cpioration (Alaska) • . 05-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well C-03B Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,189.16' MD Window /Kickoff Survey: 8,202.00' MD (if applicable) Projected Survey: 11,635.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 ~ ~ ~ ,,,, / / , Date / ~ ar..~~"~ ~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~.OS - /1~~ / ~ ~~ • • 05-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-03B MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,189.16' MD Window /Kickoff Survey: 8,202.00' MD (if applicable) Projected Survey: 11,635.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. ^ / Anchorage, AK 99518 v/l ~ ~,, / // ~f Date ~. J~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) Dave Wesley Fax (so~~ 2~sasaz Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU C-03B BP Exploration (Alaska), Inc. Permit No: 205-158 Surface Location: 1316' FNL, 879' FEL, SEC. 19, Tl 1 N, R 14E, UM Bottomhole Location: 404' FSL, 300' FWL, SEC. 17, T11N, R14E, UM Dear Mr. Wesley: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Com ector at (907) 659- 3607 (pager). DATED this day of October, 2005 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~~~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COM SSION p~j ~ ~ 2005 PERMIT TO DRILL 20 AAC 25.005 ~-ask~ q+! ~ ~~~ parr.. ~a~mi~s~c~n A..._L___...w ia. Type of work ^ Drill ®Redrill ^ Re-Entry 1b. Current Well Class ^ Exploratory ®Development Oil Multi~fle Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: PBU C-03B ~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 11570 TVD 9013 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 1316' FNL 879' FEL SEC T11 N 19 R14E UM 7. Property Designation: ADL 028305 Pool , , . , , , Top of Productive Horizon: 600' FSL, 1589' FWL, SEC. 17, T11N, R14E, UM 8. Land Use Permit: 13. Approximate Spud Date: October 30, 2005 Total Depth: 404' FSL, 300' FWL, SEC. 17, T11N, R14E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property:. 20,065' 4b. Location of Well (State Base Plane Coordinates): Surface: x- 664500 - 5959906 Zone- ASP4 10. KB Elevation (Height above GL):Plan 63.7 feet t5. Distance to Nearest well Within Pool C-37A is 289' away at 10003' 16. Deviated Wells: Kickoff Depth: 8600 feet Maximum Hole Angle: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035). Downhole: 3230 Surface: 2350 18. asing rogram: Size Specffications Setting Depth To Bottom uantity o ement c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data N/A 9-5/8" 47# L-80 BTC-M 2043' Surface Surface 2043' 2043' 25 sx Class 'G' 8-1/2" 7" 26# L-80 BTC-M 942' 8450' 7573' 9392' 8378' 13 sx Class 'G' 6-1/8" 4-1/2" 11.6# L-80 LTC 2328' 9242' 8248' 11570' 9013' sx Class 'G' tjtr a~j 19. PRESENTWELL CONDITI ONSUMMARY (To be completed for Redrill AND Re-entry Operations). Total Depth MD (ft): 12153 Total Depth TVD (ft): 8935 Plugs (measured): 9217 Effective Depth MD (ft): 12072 Effective Depth TVD (ft): 8935 Junk (measured): N/A Casing Len th Size Cement Volume MD ND r I on t r 80' 30" 80' 80' 2524' 18-5/8" 700 sx PF II 2524' 2524' I 4331' 13-3/8" 1210 sx 'G', 950 sx PF II 4331' 4180' o i 9749' 11-3/4' x 10-3/4'x9-5/B• 670 sx Class 'G' 9749' 8671' 625' 7" 84 sx Class 'G' 9218' - 9843' 8211' - 8753' Liner 2934' 2-7/8" 109 sx Class 'G' 9219' - 12153' 8211' - 8935' Perforation Depth MD (ft): 10200' - 12070' Perforation Depth TVD (ft): 8967' - 8935' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ^ Property Plat ^ Diverfer Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Seabed Report ®Drilling Fluid Program ®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 Ken Allen, 564-4366 Printed Name .D'a've Wesle i Title Senior Drilling Engineer T ~ Prepared By Name/Number: Si nature n~~dr ~ ~~`~ +~. ~._. Phone 564-5153 Date d ~/ ~ Terrie Hubble, 564-4628 '- Commission Use Only Permit To Drill Number:..ZO --l API Number: 50- 029-20124-02-00 Permit Approval Date: See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes~'No Mud Log Required ^ Yes ,~,No Hydrog ulfide Measures 'Yes ^ No Directional Survey Required 'Yes ^ No Other _.1_*' t~ ~ ~ (~ ~ u ~, ~ r/ ~, ~ ~, (~.~r- ~ !}- ^ " 5 (~. } C1 ~ ~ ~ (. ~ -2 ~ Lrr. ~~~ ~ ~`rf~E cy,~.c_~ ~s. iv ~,~j zl [~'(~~.~r~-~' r%t ,a~_~? ~~~~~ / vJ~~ c~ . APPROVED BY l~ n~ A roved d THE COMMISSION Date ~ (/ Form 10-401 Revised v X004 . ° i ; ,~~ ( ~' Submit Ir(Duplicate • • Planned Well Summary Well C-03B Well Sidetrack / Target Zone 1 A/1 B T e horizontal Ob'ective AFE Number: PBD 4P2361 API Number: 50-029-20124-02 Surface Northin Eastin Offsets TRS Location 5,959,906 664,500 1315.9' FNL / 878.6' FEL 11 N, 14 E, 19 Target Northin Eastin Offsets TRS Location 5,961,876 666,918- 4679.5' FNU3690.7 FEL 11 N, 14 E, 17 Target Northin Eastin Offsets TRS Locaton 5,961,765 666,402 4778.9' FNU4209.4' FEL 11 N, 14 E, 17 Bottom Northin Eastin Offsets TRS Location 5,961,651 665,634 4875.8' FNU4980.0' FEL 11 N, 14 E, 17 Planned KOP: 8,600' and Planned S ud: 10/30/05 Ri Nabors 2ES / Planned Lateral TD: 11,570' and Planned Lateral TVD: 9,013' tvd GL: 35.16' RTE: 63.T Directional Program A roved Well Ian: WP03 Exit oint: 8,600' and / 7,629' sstvd Maximum Hole Inclination: "'43° at 4,300' in the original well bore, ~92° at 10,277' in the planned 6-1/8 roduction horizontal. There are two wells that need to be risked base to pass the anti-collision scan in the production hole. Proximity Issues: A Pre-Rig Gyro survey will be run prior to drilling in order to improve the positional uncertainty of the parent wellbore. Details are listed in the attached Anti-Collision re ort. Surve Pro ram: Standard MWD+IIFR+MS Nearest Well: Well C-37A, with acenter-to-center distance of 289' at --10,003' md. Nearest Pro a Line 20,065' C-03B Permit to Drill -Version 1.0 Page 1 • • Logging Program Hole Section: Required Sensors /Service 8-1/2" intermediate: MWD DIR/GR/RES throu hout the interval all in real-time mode. 6-1/8" production: DIR/GR/RES/DEN/NEU throughout the interval all in real-time mode. Neutron and Density tools will be picked up on the second run and a MAD performed over the build section BEFORE drilling the lateral. Two sample catchers will be re uired at com an man call out. Cased Hole: None tanned O en Hole: None tanned Mud Program Fresh water LSND Hole Secti on / o eration: 8-1/2" I ntermediate Hole Flowline Depth Density Funnel PV YP API FL Chlorides (ft) (ppg) Vis (cP) (Ib/100ft2) (mU30min) pH (mg/I) MBT sec/ t 8,600 window 10.2 50 - 60 15 - 22 30 - 40 4.0 - 6.0 9.0 - 9.5 <600 <20 millin 8,620 - 9,392 0. 38 - 50 14 - 22 22 - 28 4.0 - 6.0 9.0 - 9.5 <600 <20 Hole Section /operation: 6-1/8" Production Interval Type Density (ppg) PV YP LSRV API FL pH FloPro SF 8.4 ~ 8 - 15 24 - 30 > 20,000 5 - 10 9.0 - 9.5 Casing /Tubing Program Hole Size Casing/Tubing Size Wt. Grade Connection Length Top and / tvd Bottom and / tvd 13-3/8" CSG 9-5/8" 47 L-80 BTC-M 2,043' Surface 2,043' / 2,043' 8.5" 7" 26.0# L-80 BTC-M 942' 8,450' / 7,573' 9,392' / 8,378' 6-1/8" 4-1/2" 11.6# L-80 LTC 2,328' 9,242'/ 8,248' 11,570'/ 9,013' Tubin 4-1/2" 12.6# L-80 IBT-M 9,242' Surface 9,242'/ 8,248' C-03B Permit to Drill -Version 1.0 Page 2 • • Cementing Program Casin Strin 9-5/8", 47#, L-80, BTC-M 9-5/8" Tieback Liner Lead slurry: None Planned. Slurry Design Basis: Tail slurry: 2,043' of 13-3/8" x 9-5/8" annulus, plus 33' of 9-5/8 CSG above lu lus 60' of 9-5/8" 47# shoe track. Pre-Flush None Planned S acer 40bbls MudPUSH II at 12.5 Fluids Sequence /Volume: Lead Slur None lanned ry Tail Slur 129bb1 / 725 ft / 625 sx Class `G' (with freeze protect), 3 15.8 ; 1.16 ft /sk. BHST: 35° ill b i th fl C d ° ement w on e y e m xe BHCT: 52 Casin Strin 7", 26#, L-80, BTC-M Intermediate Liner Slurry Design Basis: Lead slurry: None Planned. Tail slurry: 792' of 8-1/2" x 7" annulus with 40% excess, plus 100' of 7", 26# shoe track, plus 150' of 9-5/8" X 7" liner lap, plus 200' of 9-5/8" X 4" drill pipe annulus. Pre-Flush None Planned Fl id S /V l S acer 30bbls MudPUSH !I at 12.5 u s equence ume: o Lead Slur None lanned Tail Slur 44bb1 / 248 ft / 213 sx Class `G', 15.8 ; 1.16 ft /sk. BHST: 185° ill b th fl t i d C BHCT: 120° emen w e m xe on e y Casin Strin 4-1/2", 11.6#, L-80, LTC solid roduction liner Lead slurry: none planned Slurry Design Basis• • Tail slurry: 2,178' of 4-1/2" X 6-1/8" annulus with 40% excess, plus 100' of 4- 1/2 , 11.6# shoe track, plus 150 of 7 X 4-1/2 liner lap, plus 200 of 7 X 4 drill i e annulus. Pre-Flush 15bbls CW 100 Fl id S /V l S acer 25bbls MudPUSH II at 9.6 u s equence ume: o Lead Slur None lanned Tail Slur 60bb1 / 339 ft / 9 sx Class `G', 15.8 ; 1.16 ft /sk. BHST: 192° f C t ill b b t h i d b i ° ore pump emen w e a c m xe e ng BHCT: 136 Casing /Formation Inteclrity Testing Test Test Point Test Type Test pressure 9-5/8" Casin to surface Bride lu to surface 30 min recorded 3,500 si surface 9-5/8" Casin window 20' be and middle of window FIT 11.5 EMW 7" Casin to surface Landin collar to surface 30 min recorded 3,500 si surface 7" shoe 20' be and middle of window FIT 9.8 EMW C-03B Permit to Drill -Version 1.0 Page 3 ~ • Well Control Well control equipment consisting of 5,000psi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. BOPE and drilling fluid system schematics are currently on file with the AOGCC. Well Interval: 8 1/2" intermediate interval Maximum antici ated BHP: 3,230psi at 8,800' sstvd. Maximum surface ressure: 2,350pS1 (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 10.5 EMW FIT FIT TO 11.5 PPG EMW Planned BOPE test pressure: 250psi low / 3,500psi high - 7 day test cycle until a window is milled in 9-5/8" casing. Once a window is milled a 14 day test cycle can commence. ROPE configuration for 7" Variable Bore Rams will remain installed, rather than C/O to 7" pipe rams Liner while running the 7" liner. In the event of a kick the rig will follow the current, best practice, making up a safety valve crossed over to casing thread, then changing elevators and picking up a joint of drill pipe. This confi uration rovides two sets of em to able rams, rather than one. Planned BOPE function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Well Interval: 6-1/8" roduction liner section Maximum antici ated BHP: 3,230psi at 8,800' sstvd. Maximum surtace ressure: 2,350pS1 (based upon BHP and a full column of gas from TD ~ 0.10 psi/ft) Calculated kick tolerance: Infinite with 8.7 EMW FiT FIT to 9.8 EMW Planned BOPE test ressure: 250 si low / 3,500psi hi h Planned com letion fluid: 8.4 seawater / 7.0 p Diesel Planned BOPE test ressure: 250 si low / 3,500 si hi h -14 da test c cle. Planned BOPS function test BPXA requests a variance to the provisions of 20 AAC 25.035 (e)(10)C regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes, except when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) The activities associated with this re uest will not com romise the inte rit of the BOP a ui ment. Disposal Annular Injection: No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations are to be hauled to the Grind and Inject station at DS-04. An metal cuttin s should be sent to the North Slo a Borou h. Fluid Handling: All drilling and completion fluids and other Class II wastes are to be hauled to DS-04 j for in ection. All Class I wastes are to be hauled to Pad 3 for dis osal. C-03B Permit to Drill -Version 1.0 Page 4 • Geologic Prognosis • Formation Planned MD ft TVDss ft Comments LCU 8654 -7675 TJD 8971 -7950 TJB 9178 -8129 TSGR 9391 -8314 TSAD 9546 -8457 TCG L 9673 -8581 BCGL 9761 -8666 9910 -8800 3230 si TZ16 10040 -8892 BSAD Not crossed -8970 HOT Not crossed -8985 TD Criteria TD Criteria Drill to TD of plan. Wellplan will not be extended due to the polygon boundaries being (horizontal): hardlines from faults and proximity to well C-16A. Fault Prognosis Formation where Est. MD SSTVD Est. Throw Throw Uncertainty encounter the Fault Intersect Intersect Direction Fault #1 (Kin ak) 9,030' - 9,300' 8,000' - 8,235' 25' - 60' S -140'/+90' MD Fault #2 (possible Zone 4) 9,625' -8,530' 0' - 30' S +/- 50' MD The proposed C-038 well lies in a moderate risk province of the field for lost circulation at faults as documented by the WORD team and the risk of loss circulation events should be average. Four loss circulation events were encountered in the Ivishak and Kingak sections in 3 of the surrounding 21 wells as detailed below. A large fault will be encountered by the well between -8000 to -8235 ft SSTVD in the Kingak section. This fault runs east-west nearly parallel to the well path, leading to a large potential range of throw from 25-60 feet. This fault was also penetrated in the parent well, C-03 in the same Kingak section with no loss circulation. Caution is advised in picking the topset casing point at the Sag River since the fault will likely cause correlation difficulties with the parenf well section. A second fault maybe encountered by the proposed well in Zone 4 near -8530 ft SSTVD. This fault, parallel to the first, was also encountered by the parent in Zone 3 with no loss circulation. These two faults, plus three others, are also present at the target TZ18 horizon from 125-200 feet to the north and south of the planned well path. The north and south boundaries of the drilling polygon are thus hardlines. The well cannot be extended to the west beyond the polygon due to two of these faults that converge and pinch off the available room. Loss Circulation Events Well Type Loss (bbl) MD SSTVD Formation Fault? C-03A Coil 20 12110 -8880 Zone 1 No (Trip) C-04A Rig 209 10196 -8692 Zone 3 Poss (circ) C-04A Rig 108 12380 -8886 Zone 2 No (Ream) C-13 Ri 20 10300 -8195 Kin ak No C-036 Permit to Drill -Version 1.0 Page 5 • • Operations Summary Pre-Riq Work: 1. Bleed OOA, OA, IA & TBG to zero psi. PPPOT - OC (13-3/8") 1,500 psi (If test fails then monitor test port while testing OA), PPPOT - IA (11-3/4" x 9-5/8" thermo Casing) 2,400 psi. Test tubing hanger seals to 5000 psi. Function all lock-down screws. Repair or replace as needed (8 known to need repair on 9-5/8"). 2. Pressure test OOA (18-5/8" x 13-3/8") to 500 psi for 30 minutes. Pressure test the OA (13-3/8" x 9-5/8 Thermo casing) to 500 psi for 30 minutes. Pressure test T X IA to 3,500 psi for 30 minutes. Attempt to verify /isolate source of "bubbing" into the cellar noted in May 2004. 3. Rig up slickline. Pull XX plug at 9,217' set on 6/4/05. Drift 5-1/2" x 4-1/2" tubing to the top of the 3.75" deployment sleeve. Drift 2-7/8" liner as deep as possible recording depth. 4. Fluid pack the tubing and inner annulus. 5. P&A perfs in 2-7/8" liner from the top of the PBTD (12,072') to 9,100' in the 5-1/2" tubing. RIH with coil to PBTD. Lay in 21.5 bbls of cement to 8,993' MD and squeeze ~2.5 BBLS into perforations. Wash down to confirm TOC C~3 --9,100'. POH with coil. a. Cement Calculations: • 2-7/8" liner = 12,072' - 9,219' or 2,853' (-16.5 BBLS) • 4-1/2" tubing = 9,219' - 9,180' or 39' (~0.6 BBLS) • 5-1/2" tubing = 9,180' - 9,100' or 80' (~1.9 BBLS) • 2.5 BBLS (--107') for squeeze • Total cement volume of 24.0 BBLS 6. Rig up slickline, drift 5-1/2" tubing. Tag TOC. 7. Chemical cut the 5-1/2", 17#, L-80 tubing in the middle of a joint at ~ 8,800' MD. 8. Pressure test T X IA to 3,500 psi for 30 minutes after cement P&A. 9. Circulate the well to sea water through the Chemical cut. Freeze protect the IA and tubing with diesel to 2,200'. 10. Bleed all casing and annulus pressures to zero. Set a BPV in tubing hanger. Secure well. 11. Remove the well house. Level the pad. Please provide total well preparation cost on the handover form. Riq Operations: 1. MIRU Nabors 2ES 2. Pull BPV. Circulate out freeze protection and displace well to seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. RU. Pull the 5-1/2" tubing from the pre-rig Chemical cut 8,800'. Spool up SSSV control lines. 5. MU 8.5" casing scraper. RIH picking up 4" DP to tubing stub at 8,800'. POOH. 6. RU a-line. Run Gauge Ring /Junk basket and Gamma Ray tool for 9-5/8", 47# casing with CCL to tubing stub ~ 8,800'. POOH 7. RIH with 9-5/8" EZSV on a-line. Set EZSV at 8,620' to avoid cutting a casing collar during window milling operations. POOH and RD a-line. 8. PU a 9-5/8" RTTS. RIH and set RTTS at 2,100'md and test the 9-5/8" casing to the lower bridge plug to 3,500 psi for 30 minutes. Chase down leak if present. Record test. POH and LD RTTS. 9. RIH with 9-5/8" Fas Drill on 4" DP. Set plug at 2,065' (below liner top packer, above FO Cementer). 10. MU casing spear and pull 9-5/8" x 11-3/4" thermo casing, 10-3/4" casing and 9-5/8" seal stem at 2,043' md. Send seal assembly to Backer for redressing seals and machining ports. 11. Close the annular and circulate the arctic pack from the 9-5/8" x 13-3/8" annulus with warm diesel. Note: Be prepared for possible trapped gas entrained in the Arctic Pack. 12. POOH and LD Thermo Casing, 10-3/4" casing and 9-5/8" casing. 13. RIH with a 9-5/8" polish mill and 13-3/8" casing scraper to the BOT tieback seal assembly. CBU and displace to clean sea water. 14. ND BOP stack and Unihead spool. Change the 13-3/8" packoff and test. 15. NU 2-step casing spool and BOP. Test BOP. 16. Close blind rams and test 13-3/8" casing to 3,000 psi. MU 13-3/8" RTTS and isolate leak, if necessary. 17. RIH with 9-5/8" casing and old 9-5/8" seal assembly with ports between seals 1 & 2. 18. Cement 9-5/8" x 13-3/8" annulus to surface. 19. Break BOP stack and set emergency slips. Rough cut 9-5/8" casing. C-03B Permit to Drill -Version 1.0 Page 6 20. ND BOP stack. Dress off casing stub and set pack-off. NU tubing spool and BOP stack. 21. Test 9-5/8" packoff and BOPE. Test casing to 3,500 psi. 22. MU 8.5" mill with an 8.5" string mill. RIH to float collar & test 9-5/8" to 3500 psi. Drill out float equipment and 9-5/8" Fas Drill plug. 23. Continue running in the hole picking up 4" DP to the 9-5/8" EZSV 8,620'. Circulate wellbore clean with seawater. 24. -5 8 whipstock and bottom trip anchor with an 8-1/ " dow milling assembly. RIH on 4" DP to EZSV. Orient and set the whi stock. Swa well over to 0. millin fluid. p P P9 9 25. Mill a window in the 9-5/8" casing at ±8,600' MD plus of formation from mid window. Note: Verify ~ of that the mud weight is 10.2 ppg prior to cutting the window. '', ~~s l~ ~ ~ 26. Perform FIT to 11.5 ppg. POOH for Drilling BHA. `,V.1k, ~ ~ 27. MU the 8-1/2" drilling assembly with DIR/GR/RES and RIH. Kick off and drill 8-1/2" intermediate u'~' ~ interval to 7" casing point at the Top Sag River. CBU, short trip to window and back to TD, circulate / well and POOH. 28. R an cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing 150' to 8,4 MD. Set hanger /liner top packer and displace cement with mud. POOH. 29. ~sf the 9-5/8" x 7" liner to 3,500 psi for 30 minutes if sufficient compressive strength has been ,- achieved. Record the test. 30. MU 6-1/8" BHA with DIR/GR/RES/ABI and RIH to the 7" landing collar. Test casing if not previously done. 31. Drill shoe track. Swap over to 8.4 ppg mud and drill 20' of new formation. Perform FIT to 9.8 ppg. 32. Drill ahead building to horizontal landing point. POOH for bit & BHA change. 33. MU 6-1/8" BHA with DIR/GR/RES/DEN/NEU/ABI. RIH and MAD pass build section. Drill ahead in the horizontal as per plan to an estimated TD of 11,570'. i 34. CBU, short trip, circulate until clean and spot a liner running pill. POOH. 35. Run and cement a 4-1/2", 11.6#, L-80 LTC liner throughout the 6-1/8" wellbore and 150' back into the / 7" drilling liner to 9,241' MD. Set liner top packer and displace well to clean seawater above the liner top. NOTE: A perf pill will be left in the 4-1/2"liner. 36. RIH with DPC pert guns, Perf intervals to be determined from LWD logs. Plan to perforate / overbalance POOH, LD DP and pert guns. 37. Run the 4-1/2", 12.6#, L-80 completion tying into the 4-1/2" liner top. 38. Set packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 39. Set and test TWC. 40. ND BOPS. NU and test the tree to 5,000 psi. 41. Freeze protect the IA and Tubing to 2,200', install BPV and test. Secure the well. 42. RDMO. Post-Rig Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from `XN' nipple below the new production packer. 3. Install gas lift valves. C-03B Permit to Drill -Version 1.0 Page 7 • ~ Job 1: Move In / Rig Up /Test ROPE Reference RP • "Drilling/Workover Close Proximity Surface and Subsurface Wells" SOP. • "Hydrogen Sulfide" SOP. • "ADW Rig Move" RP. Issues and Potential Hazards - BOP test interval during this phase is 7 days. - No wells will require shut-in for the rig move onto C-03A. However, C-35 is about 65' to the North and C-02 is about 100' to the South of C-03A. C-35 and C-02 are the closest surface neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - The C-03A well bore will be secured with the following barriers: • Note on barriers during MIRU procedures: ^ Tubing -Tested Cement plug (P&A perfs), Kill weight fluid and a BPV. ^ IA -Tested Cement plug (P&A perfs), Kill weight fluid and the annular valve. ^ OA -Kill weight fluid, tested Annulus and annular valve. ^ OOA -Kill weight fluid, tested annulus and annular valve. • Note on barriers during ND Tree / NU BOP Procedures ^ Tubing -Tested Cement plug (P&A pens), Kill weight fluid and a TWC. ^ IA -Tested Cement plug (P&A perfs), Kill weight fluid and the annular valve. ^ OA -Kill weight fluid, tested Annulus and annular valve. ^ OOA -Kill weight fluid, tested annulus and annular valve. - Prior to pulling the tree, verify there is a static column of seawater to surface and that no pressure exists. C Pad will be considered as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: Well Name HZS Readin Date #1 Closest SHL with H2S Readin C-35 No Data #2 Closest SHL with H2S Readin C-02 No Data #1 Closest BHL with H2S Readin C-13 No Data #2 Closest BHL with H2S Readin C-34 No Data Max Recorded H2S Readin on the Pad C-26 10 m 10/22/00 The latest readin on C Pad was done in 2003 on C-27A showin 10 m. - Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud. C-036 Permit to Drill -Version 1.0 Page 8 • Job 2: De-complete Well Reference RP • "De-completions" RP Issues and Potential Hazards - BOP test interval during this phase is 7 days. • - Monitor the well to ensure the fluid column remains static prior to pulling the completion. - Note and record required PU weight to pull tubing from cut point (8,800'). - Have all wellhead and completion equipment NORM-tested, following retrieval. - The existing wellhead is a Rockwell (McEvoy) Unihead design completed in 1973. It is threaded onto 18-5/8" casing. There is a string of 13-3/8" set on slips. It has 9-5/8" casing set on a mandrel hanger and packoff. The current completion is a 7" crossed over to 5-1/2" just below the well head and 4-1/2"just below the packer. Top threads of the hanger are listed as 7" TC4S running threads. The bottom threads should be 5-1/2 Butt A/B. Have a spear on location as a contingency to pull the Hanger to the floor. - There is a 5-1/2" Otis SSSV Landing Nipple at 2,131'. There should be 2,'/a" encapsulated control lines run to surface. The historic records are unclear, but there should be 2 control lines. The current tubing tally states there are 26 control line protectors and 4 steel bands securing these control lines. - 11-3/4" x 9-5/8" Thermocase II will be pulled from the wellbore. Arctic Pak will be need to be circulated out of the 13-3/8" x Thermocase annulus with diesel. • Be prepared for gas entrained in the Arctic Pak when pulling the Thermocase. - A 9-5/8" tie-back will be stung into the current 9-5/8" liner and brought back to surface. Cement will be brought up to surface. C-03B Permit to Drill -Version 1.0 Page 9 Job 3: Run Whip Stock Reference RP • "Whipstock SidetracK' RP. • "Leak-off and Formation Integrity Tests" SOP Issues and Potential Hazards - BOP test interval during this phase is 7 days until the window is milled into formation. Once the window is milled the 14 day test cycle starts and continues until the rig moves off the well. - A 9-5/8" whip stock will be run and set in the existing 9-5/8" 47# liner. A 8-1 /2" window will then be milled in the 9-5/8" 47# liner. - A CBL showed decent cement bonding behind the 9-5/8" liner to 8,400' md. There should be cement behind the 9-5/8" casing at the sidetrack point. - The window will be cut in the existing 9-5/8" casing just above the Kingak formation. Ensure entire wellbore has been circulated to 10.2 ppg mud before milling commences. - Once milling is complete, circulate a minimum of 1-1/2 bottoms up and pump a "Super Sweep" pill to remove metal debris created from the milling process. Ditch magnets should be used throughout job. - Once the milling BHA is out of the hole the entire stack and flow lines should be flushed to remove metal debris that may have settled out in these areas. Ensure BOP equipment is operable. Job 4: Drill Intermediate Hole Reference RP • Standard Operating Procedure for Leak-off and Formation Integrity Tests • Prudhoe Bay Directional Guidelines • Lubricants for Torque and Drag Management. • "Shale Drilling- Kingak & HRZ" Issues and Potential Hazards - C-03B is expected to cross one fault in the intermediate hole section. The approximate location of the fault is between 9,030' and - 9,300' and (-100'/+90' and laterally uncertainty) and has an expected throw of 25' - 60' at the planned crossing depth. Lost circulation is considered a minimum risk since the parent wellbore crossed this same fault with no associated losses. If losses/breathing is encountered, consult the Lost Circulation Decision Tree regarding LCM treatments and procedures and adjust drilling practices to reduce breathing phenomena. - KICK TOLERANCE: In the wor case scenario of 8.5 ppg pore pressure at the top Sag River depth, gauge hole, a fractur gra ent of 10.5 ppg at the 8.5" casing window, 10.2 ppg mud in the hole, the kick tolerance i nfinit .FIT will be to 11.5 ppg. C-03B Permit to Drill -Version 1.0 Page 10 r • Phase 6: Run and Cement Intermediate Liner Reference RP • "Intermediate Casing and Cementing Guidelines" RP • "Shale Drilling, Kingak and HRZ" RP Hazards and Contingencies - Swab and surge pressure should be minimized with controlled liner running speeds and by breaking circulation slowly. Excessive swab /surge pressures could initiate HRZ /Kingak instability problems. - Differential Sticking is potentially a problem if lost circulation occurs or if the liner is left stationary across permeable formations. Proper casing centralization and keeping the liner moving will facilitate minimizing the potential for differential sticking. Job 7: Drill Production Hole Interval Reference RP • "Leak-off and Formation Integrity Tests" SOP • "Prudhoe Bay Directional Guidelines" RP • "Lubricants for Torque and Drag Management" RP Issues and Potential Hazards - The C-036 wellbore has a possible fault crossing around 9,625' MD (+/- 50' and laterally uncertainty) and has an expected throw of up to 30' at the planned crossing depth. This possible fault was also crossed in the parent wellbore in zone 3 with no associated hole problems. A detailed list of faulting issues is listed on page 5 of this program. - Differential sticking is a concern. The 8.4 ppg mud will be -614 psi over balanced to the Sag River and Ivashak formations. Minimize the time the pipe is left stationary while in open hole (making connections, surveying, etc). - An EMI-920 sweep will be pumped just ahead of the new Flo-Pro mud during displacement after drilling the shoe track due to the tortuosity of this wellbore. - A liner running pill will be left in the open hole on the final trip out of the hole to run the solid liner. C-036 Permit to Drill -Version 1.0 Page 11 r • Job 9: Run Production Liner Reference RP • "Modified Conventional Liner Cementing' RP • Schlumberger Cement Program. Issues and Potential Hazards - The completion design is to run a 4-1/2", 11.6#, L-80 LTC solid liner throughout the production interval. Note: This is not the normal weight 4-1/2"liner and it has lower specifications as listed below. 4-1/2", 11.6#, L-80, LTC Collapse Burst Tensile ID Make-up Torque - O timal ft-Ibs 100% 6,350 psi 7,780 psi 212,000 Ib Body 4.000" Optimal - 2,230 80% 5,080 si 6,224 si 169,600 Ib 3.875" drift - Differential sticking is possible. The 8.4 ppg Flo-Pro will be 614 psi over balanced to the Ivishak formations when static. Minimize the time the pipe is left stationary while running the liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 4-1/2" liner will be run to extend 150' above the bottom of the 7" liner shoe (est 9,242' md). - A Hi-Vis perforation pill will be spotted in the 4-1/2" liner as per MIDF recommendations. Phase 10: DPC Perforate Reference RP • "Drill Pipe Conveyed Perforating" RP Issues and Potential Hazards - The well will be DPC perforated overbalanced, after running and cementing the 4-1/2 liner. Ensure all personnel are well briefed on Schlumberger's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. - Expect to lose fluid to the formation after perforating. Have ample seawater on location and be prepared with LCM if necessary. C-03B Permit to Drill -Version 1.0 Page 12 • • Job 12: Run Comuletion Reference RP • "Completion Design and Running' RP • "Handling and Running 13 Chrome" RP • "Casing and Tubing connections" RP Issues and Potential Hazards - Diesel will be used to freeze protect the well to 2200'. The diesel flash point is 100° F. Diesel vapor pressure is ~ 0.1 psia at 100° F. - The completion, as designed, will be to run a 4-1/2", 12.6#, L-80, IBT-M production tubing string, stinging into the 4-1/2" production liner tieback sleeve. Job 13: ND/NU/Release Rig Reference RP • "ADW Rig Move" RP. • "Freeze Protecting an InnerAnnu/us" RP. Issues and Potential Hazards - No wells will require shut-in for the rig move off C-03B. However, C-35 is about 65' to the North and C-02 is about 100' to the South of C-036. C-35 and C-02 are the closest surface neighboring wells. Care should be taken while moving onto the well. Spotters should be employed at all times. - Note on Barriers during the ND BOP / NU Tree procedures: ^ Tubing -Kill weight fluid on a RHC plug with ball & rod and a TWC. ^ IA -Kill weight fluid, tested annulus and annular valve. ^ OA -Fully Cement Annulus. ^ OOA -Kill weight fluid, tested annulus and annular valve. - Note on Barriers during the RDMO procedures: • Tubing -Kill weight fluid on a RHC plug with ball & rod and a BPV. ^ IA -Kill weight fluid, tested annulus and annular valve. • OA -Fully Cement Annulus. ^ OOA -Kill weight fluid, tested annulus and annular valve. C-036 Permit to Drill -Version 1.0 Page 13 TREE = 4 1 /16" CNV WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 54.46' BF. ELEV = 35.16' KOP = 3000' Max Angle = Datum MD = Datum TVD = 8800' S C=~3 B Pro o s e d S OTES: 9-5/8"CSG HAS FOC'S AT , 17 / 207 4303' 11'"' 13-3/8" CSG HAS FOCS AT 2138' & 2332' S 20" CSG 80' 1-1/2" TBG 1814' Cemented 9-5/8" x 13-3/8" Annulus ~ 9-5/8" SEAL ASSY ~ OF 9-5/8" LNR ~-~ 2043' ~ ~ 2059' ~~ 13-3/8" X 9-5/8" BOT PKR /LNR HGR 18-5/8" CSG, ??#, ???, ID = ?.???" 2524' 2100' 4 1/2" 'X' LANDING NIP, ID = 3.813" Est TOC - 3300` 13-3/8" CSG, 72#, L-80, ID = 12.347" 4331' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PDRT DATE 4 TBD TBD 3 TBD TBD 2 TBD TBD 1 TBD TBD CBL Shows Bonding 8400` - 9749'- Legend ~~ Cement Estimates from previous operations - ~ ~ Cement proposed during - !.n this sidetrack operation. cut TOC - 9100` TOP OF 7" LNR (40' BOT PBR) I 9218' 9-5/8" LNR, 47#, N-80, 9749' ~ .0732 bpf, ID = 8.681" TOP OF 2-7/8" LNR CEMENT-~ -10, 000' ~_ 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" ~~ 10250' 8600' 9 5/8" Window / 9180' 4 1/2" X Nipple (3.813" ID) 9190' 7" x 4 1/2" Baker Premier Packer 9210' 4 1/2" X Nipple (3.813" ID) 9230' 4 1/2" XN Nipple (3.725" IDj 9243' 4 1/2" WLEG 9240' 4 1/2" Hanger /liner top packer T 9392' 7" 26# L-80 (6.276" ID) 0.383 bpf I4 1/2" 12.6# L-80 Liner PBTD ~--~ 11,490' ~ 4 1 /2" 12.6# (3.958" ID) 0.0152 bpf 11, 570' Abandoned 2-7/8" LNR 12153' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/26/73 ORIGINAL COMPLETION 10/05/87 RWO 10/14198 CTD SIDETRACK (C-03A) 10/20/05 KWA PROPOSED RIG SIDETRACK PRUDHOE BAY UNIT WELL: G03B PERMfr No: 1981840 API No: 50-029-20124-02 SEC 19, T11 N, R14E, 1316' SNL & 879' WEL BP Exploration (Alaska) TREE = 6" CM/ WELLHEAp= McEVOY ACTUATOR = OTIS KB. ELEV = 54.46' BF. ELEV = 35.16' Max Angle = 97 @ 11518' Datum MD = 9964' Datum ND = 8800' SS 20" CSG 1-1/2" TBG 10-3/4" CSG, 55.5#, K-55, ID = 9.760" TOP OF 9-5/8" LNR • C-03A 80' 1814' 1951' 2043' 18-5/8" CSG, ??#, ???, ID = ?.???" I~ 2524' 13-3/8" CSG, 72#, L-80, ID = 12.347" I-~ 4331' Chemical Cut ~ 8,800` CMT P&A plug ~ 9,100` 5-1/2" TBG, 17#, L-80, 9155' .0232 bpf, ID = 4.892" Minimum ID = 2.372" @ 9223' TOP OF 2-7/8" LINER TOP OF 7" LNR (40' BOT PBR) 9218' 3.75" DEPLOYMENT SLV, ID = 3.00" 9219' TOP OF 2-7/8" LNR, ID = 2.37" 9223' 1/2" TBG,12.6#, L-80, .0152bpf, ID = 3.958" 9291' 9-5/8" LNR 47#, N-80, 9749' .0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: GR/CNL ON 10/13/98 ANGLE AT TOP PERF: 82 @ 10200' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10200 - 10225 O 12/26/02 2" 6 10307 - 10332 O 12/26/02 2" 6 10340 - 10365 O 12/26/02 2" 6 10398 - 10423 O 12/26/02 1-2/3" 4 10800 - 10980 O 10/14/98 1-2/3" 4 11100 - 11300 O 10/14/98 1-2/3" 4 11470 - 11570 O 10/14/98 1-2/3" 4 11690 - 11840 O 10/14/98 1-2/3" 4 11890 - 11920 0 10/14/98 1-2/3" 4 11960 - 12070 O 10/14/98 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 10250' S~ NOTES: WELL IXCEEDS 70° @ 10130' 8~ GO HORIZONTAL @ 10614'. 142' --j 11-3/4" X 9-5/8" THERMOCASE II I NOTE 9-5/8" CSG HAS FOC'S AT 1993', 2074' 8 4303' I 2051' 10-3/4" X 9-5/8" XO 2054' 9-5/8" SEAL ASSY NOTE 13-3/8" CSG HAS FOC'S AT 2138' 8, 2332' 1059' 13-3/8" X 9-5/8" BOT PKR /LNR HGR 1131' S-1/2" SSSV OTIS LANDING NIP, ID = 4.562" GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 5 3023 2968 9 OTIS LBD DMY RM 0 05/17/04 4 5786 5282 37 OTIS LBD DMY RM 0 05/17/04 3 8119 7228 31 OTIS LBD DMY RM 0 05/17/04 2 8808 7814 33 OTIS LBD DMY RA 0 10/15/98 1 ._._. 8990 7964 .~. 34 ~~....v. OTIS LBD , DMY ~ ~ RA 0 10/15!98 .. 9097' I-i 5.1/2" OTIS SLIDING SLV, ID = 4.562" 9155' 5-1/2" SEAL ASSY 9170' H 9-5/8" X5-1/2" GUIB PKR, ID = 4.75" 91~ 5-1/2" X4-1/2" XO, ID = 3.892" 9217' I-I 4-1/2" Ol1S X NIP, ID = 3.813" 9256' ~ 4-1/2" OTIS XN NIP, ID = 3.725" 9292' 4-1/2" TBG TAIL ID = 3.958" 9279' ELMD TT LOG NOT AVAILABLE SIDETRACK WINDOW @9843' -9849' TOP OF WHIPSTOCK @ 9840' RA TAG @ 9849' I PBTD I ~ 2-7/8" LNR, 6.16#, STL, .0058 bpf, ID = 2.37" I DATE REV BY COMMENTS DATE REV BY COMMENTS 03/26/73 ORIGINAL COMPLETION 09/14/03 CMO/TLP DATUM MD & PERF ANGLE 10/05/87 RWO 05/17/04 KSB/KAK GLV GO 10/14/98 CTD SIDETRACK (C-03A) 10/10/04 JLA/TLH CSG CORRECTION 07/27/01 CWKAK CORRECTIONS 12/26/02 DV/D ADD PERFS 04/05/03 KAK CLEANUP PRUDHOE BAY UNfT WELL: G03A PERMIT No: 1981840 API No: 50-029-20124-01 SEC 19, T11 N, R14E, 1316' SNL & 879' WEL BP Exploration (Alaska) Pre-Rig I I .." F ~ » • ~~ n' ° , ~~ s TREE = 6" CM/ WELLh~AJ~ = McEVOY ACTUATOR = OTIS KB. ELEV = 54.46' BF. ELEV = 35.16' KOP = 3000' Max Angle = 97 @ 11518' Datum MD = 9964' Datum TVD = 8800' SS 20" CSG 1-1/2" TBG 10-3/4" CSG, 55.5#, K-55, ID = 9.760" TOP OF 9-5/8" LNR ~ C-03A Current u 1814' 1951' r2~ 18-5/8" CSG, ??#, ???, Ip = ?.???^ ~ 2524' ~ I I 13-3/8" CSG, 72#, L-80, ID = 12.347" I .4331' I Minimum ID = 2.372" @ 9223' TOP OF 2-7/8" LINER 5-1/2" TBG, 17#, L-80, 9155' .0232 bpf, ID = 4.892" S/~ NOTES: WELL EXCEEDS 70° @ 7 07 30' 8~ G~O``~ ~HORIZONTAL(a~ 70674'. 142' --~ 11-3/4" X 9-5/8" THERMOCASE II NOTE 9-5/8" CSG HAS FOC'S AT 1993', 2074' & 4303' I 2051' 10-3/4" X 9-5/8" XO 2054' 9-5/8" SEAL ASSY NOTE 13-3/8" CSG HAS FOC'S AT 2138' & 2332' 2059' 13-3/8" X 9-5/8" BOT PKR /LNR HGR 2131' 5-1/2" SSSV OTIS LANDNVG Nom, ID = 4.562" GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 5 3023 2968 9 OTIS LBD DMY RM 0 05!17/04 4 5786 5282 37 OTIS LBD DMY RM 0 05/17/04 3 8119 7228 31 OTIS LBD DMY RM 0 05/17/04 2 8808 7814 33 OTIS LBD DMY RA 0 10/15/98 1 8990 7964 34 OTIS LBD DMY RA 0 10/15!98 909~~ 5-1/2" Ol1S SLIDING SLV, ID = 4.562" 9155' 5-1/2" SEAL ASSY 9170' H 9-5/8" X5-1/2" GUIB PKR, ID = 4.75" 91~ 5-1/2" X4-1/2" XO, ID = 3.892" TOP OF 7" LNR (40' BOT PBR) ~~ 9218' r 3.75" DEPLOYMENT SLV, ID = 3.00" 9219' TOP OF 2-7/8" LNR, ID = 2.37" 9223' 1/2" TBG,12.6#, L-80, .0152bpf, ID = 3.958" 9291' 9-5/8" LNR, 47#, N-80, 9749' .0732 bpf, ID = 8.681" PERFORATION SUMMARY REF LOG: GR/CNL ON 10/13/98 ANGLE AT TOP PERF: 82 @ 10200' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 10200 - 10225 O 12/26/02 2" 6 10307 - 10332 O 12/26/02 2" 6 10340 - 10365 O 12/26/02 2" 6 10398 - 10423 O 12/26/02 1-2/3" 4 10800 - 10980 O 10/14/98 1-2/3" 4 11100 - 11300 O 10/14/98 1-2/3" 4 11470 - 11570 O 10/14/98 1-2/3" 4 11690 - 11840 O 10/14/98 1-2/3" 4 11890 - 11920 O 10/14/98 1-2/3" 4 11960 - 12070 O 10/14/98 7" LNR 29#, N-80, .0371 bpf, ID = 6.184" 10250' 9217' H 4-1/2" OTIS XNIP, ID = 3.813" 9256' -L 4-1/2" OTIS XN NIP, ID = 3.725" 9292' 4-1/2" TBG TAIL ID = 3.958" 9279' ELMD TT LOG NOT AVAILABLE SIDETRACK WINDOW @ 9843' -9849' TOP OF WHIPSTOCK @9840' RA TAG @9849' I PBTD I 2-7/8" LNR, 6.16#, STL, .0058 bpf, ID = 2.37" I-i 12153' DATE REV BY COMMENTS DATE REV BY COMMENTS 03/26173 ORIGINAL COMPLETION 09/14/03 CMO/TLP DATUM MD 8 PERF ANGLE 10/05/87 RWO 05/17/04 KSB/KAK GLV GO 10/14/98 CTD SIDETRACK (C-03A) 10/10/04 JLA/TLH CSG CORRECTION 07/27/01 CWKAK CORRECTIONS 12/26/02 DV/ ADD PERFS 04/05/03 KAK CLEAN UP PRUDHOE BAY UNfr WELL: G03A PERMIT No: 1981840 API No: 50-029-20124-01 SEC 19, T11N, R14E, 1316' SNL & 879' WEL BP 6cploratlon (Alaska) t't Mtl`ANY I)I:I nil ~ Kl~aI-KGNC'I- INI~OKAIAI ION SUKVI~.Y I'KI x~ KAM flan: ('-OiN v•nll_i 1('-U3~1'Iwi l~-D7131 P HI' Am,n.~ (')War Ale0uxl Mnwnrwr t'wr uu ' t ....ni ~ IN 1.1 K I R II l l a i I N.ne \en'I(I\nlKl R ~i i R \'~KI k 31 N.xrl ~.1 I .pr61'm Ilepih I Wxxr)x II<n'/.~) ' , I'iau IWww.l: t'~iiix pui Vl I.~~~I ' hIN'n-U-K~M.~ l raak•J I{y'. I)iRnal Huuuari(lianl I I' f Dula". .IS'.IIIJS (I ~' ~k J I) I-. eNa>rcm IK( WNA ~ t' N mL w M h l r h l M.•as Ilkpl K l rc R.. i fii.'ll l raY a : ara . .au n w rar v a n I~maxurfac : IJtipuul ~ t'asmy t al.u aa~n h 1aM 1 Almnnwn c rmaww Kav iaa a~J O:ua~'. W'mnnR McJxxl: Kuk' IW.wrl N'l] I Ill~l,\II CASING DETAILS Nwrx~ N -~ -I~:-N' N.~NnnR ('wsunR I awak I ~~nRinxl.~ tiles Nu TVD MD Name Size tali ~nWnx ,alas sv~`rnx,.lw Mwsar,rxl w°n'ix37sN IavvurwznW ..r 1 8377.70 9391.$6 7" 7.00(1 SECTION DETAILS i 2 9012.70 11569.00 41/2" 4.500 Sec MD Inc Azi TVD +N/-S +E.--W DLeg TFace VSec Target '. TARGBT DETAILS I 8600.00 31.79 69.64 7692.82 1682.94 2442.40 0.(10 0.00 2766.12 2 8620.00 32.08 65.14 7709.79 1687.01 2452.16 12.00 -85.00 2774.98 Name l'VD +Ni-S +E/-W Northing Easting Shape 3 8677.74 29.>6 63.36 7759.27 1699.93 2478.96 4.00 -157.38 2800.74 4 9410.37 29.96 6336 8394.00 1864A0 2806.00 0.00 0.00 3120.49 C-03BKingak 8203.70 1864.71 1821.38 9961810.00 666280.00 Polygon 5 9669.12 15.2; 307.73 8640.41 1915.77 2838.1 1 15A0 -157.80 3181.35 C-03B Fault Zone 4 859370 193036 2478.02 5961890.00 666935.00 Polygon 6 9763.65 19.23 307.73 8731.62 1930.96 2818.47 0.00 0.00 3182.85 C-036 Eault 3 8962.70 2081.07 2676.38 5962045,00 667I30A0 Polygon 7 10265.05 90.00 258.00 9022.70 1916.74 2460.7 1 16A0 -50.74 2969.63 C'-03B'FI C-036 Fault 4 8')63.70 1965.83 1543.50 5961905,00 666000.00 Polygon 8 10277.35 91.85 258.68 9022.50 1914.25 2448.67 16.00 20.27 2960.79 C-036Pau11TZ1B 8981.70 1916.74 2460.71 9961876.00 666918.00 Polygon 9 10680.40 91.85 258.68 9009.52 1835,19 2053.66 0.00 0.00 2673.02 C-03B Fault 5 8983.70 1686.67 58210 5961605.00 6G505f1.00 Polygon 10 1079320 90A0 262.80 9007.70 1817.05 1942.37 4.00 114.1 I 259536 C-03B T2 C-03B T2 9007.70 1817.05 1942.37 5)61765.00 666402.00 Point II 10802.49 89.63 262.81 9007.73 181$.89 1933.16 4.00 178.29 2589.21 C-03B T3 9012.70 1719.88 1172.01 5961651.00 665634A0 Point 12 11569.69 89.63 262.81 9012.70 1719.88 1172.0 1 0..00 0.00 208125 ('-038 T3 C-03B Poly 9012.70 1804.76 2960.42 5')61775.00 667420.00 Polygon ~ 8200 ~ ~ ~~ ~ ~ ~ I I ~ ~ ~ ~ ~ FORMATION TOP DETAILS I ~ ! I ~~ ~ ~ i i I ' ~ ~ I ~ I ` No TVDPath MDPath Formation _ _ _.. _ _.1 _ _ ~ f I ~ 4 ___ ~ I ~ I I __ { ~ 1 7738.70 6 .89 LCU i I I I ~ - _- ~~ I _ I ! ~ 8 71 2 8013.70 .41 TJD I ~ ~ ~ I i 3 8192.70 9 78.02 TJB _ _ __ ' -- - ~ - I -- -- - ~. ~ ~ I _ -. -.. ~ ~. - - - 4 8377 7U 9391.56 TSGR ~ ~ _ f ~ ~ ~ 5 8520 70 9546.65 TSAD i ~ ~ I i I i . ~ 6 8644 70 967'i.57 TCGL . , . ~ . ~ - - , i ~ ~ TS GR . :Siam Dir Ud100 : 94 0.37 MD, 8 394TWD~ 7 8729.70 9761.66 BCGL 8x00 - I ~ ~ T 8 8955.70 10039.98 TZIB _I ~ - - -- I ~ , . - ' ` 9509, 5U ' ,~ ~- ! ~ TSAD ~- i i ._ i ~ . I . __~ _ . . ~, I .. End Dir :_9669. 2'~MD. 864 0.41'T~'D ~ ~ ~ c . . ...__ 0 8600 I ~, r : ' : ' N z - I __ - , _ - ~ , 3c L _ ~ . - . . Sent Dir ; IOEN : 976 A 65' MD N7 Lb2 "D . . n ~ i I ~ I . ; ~ - ._ _ - - - _ i 0 Y Di IOP773u M' E ~ D 2 5'l'V i i I ~. ~ ~ I _ 1 - - - ~ Ix . [ . ~ B -__ _ v - i _ _. _. __ - _ __ __ __ -_ '- _. _ I I ._. . I .- _.~ . . .. ` _ I ~ I ~ i I ~i 8800 l ~ DIt4 0 1068D '' A'M~ .9009.52'TVD ~ i ~ ! I ~ i Zo J __ ~ ~~ E d 4 41r 108 2.49' MD , 9D07.73 TV^ 1 _ ~ i ~ ~. _ ~ a 1.. _ I ,. - I I '`r la ` I . i _ - _} r, ~~~1 .w tea' ' 2800 3000 Vertical Section at 34?7° [200Nin] l'(iAll'ANY I)I+I All.% W:1=I:KINI'I: INIi)KAL\ I Il)N Ill' Amra~~ (~.iali w N I K I N' II r ra' t I I nr` h~~nl~ \'rnx.ulI IA UIK 1 % i. .'+63. 7 ('.il.uLn .x Alctlnxl: At n~mwn ('w. ~~wc \.lru l\.IK.lir.~w. Akn 113 (n IxlN.ll. X11.1 1~-mgr %y.iein: I~<'W'\A Ale~.wrcd l k~l6 Kef•rt~ae. '_x5 - 3i.2 M13.7u .k:ni AlcJnvl~. Iri. ('(tnxlcr N.~nl~ ('al culunun hlnlxvl: Atnninm( l'un uM r,.m.r lwlua- I'Ihpuol - c ;~mg \Pammp Atcu..l: Wdc., I1Jal SECTION DETAILS Sec MD Inc Azi "R-'U +N%-S +E/-W DLeg TFace VSec Target I 8600.00 31.79 69.64 7692.82 1682.91 2112.40 0.00 0.00 2766.12 2 8620.00 3'_.OR 65.14 7709.79 1687.01 3152,16 12.00 -85.00 2774.98 3 8677.74 29.96 63.36 7759.27 1699.93 2478.96 4.00 -157.38 2800.74 4 9410.37 29.96 63.36 8394.00 1861.00 2806.00 O.UO OAO 3120.49 5 9669.12 15.23 307.73 8640.41 1915.77 2838.11 15AU - 157.80 3181.35 6 9763.65 1523 307.73 8731.62 1930.96 2818.47 OAO OAO 3182.85 7 10265.05 90.00 258.00 9022.70 1916.74 2460.71 16.00 -50.74 2969.63 G03B-FI 8 10277.35 91.85 258.68 ')022.50 191425 3448.67 16.00 20.27 2960.79 9 10680.40 91.88 258.68 9009.52 1835.19 2053.66 0.00 O.OU 2673.02 10 10793.20 90.00 262.80 9007.70 181 ZOS 1942.37 4.00 114.1 I 2595.36 C-036 l2 II 10802.49 89.63 262.81 90(17.73 1815.89 1933.16 4.00 178.29 2989.21 12 11569.69 89.63 262.81 9012.70 1719.88 1172.01 0.00 0.00 2081.25 C-036 "I'3 %lfK\'1:1' I'Ktxik\Af IAryrrh lln Ihph 1.. tiune) I'Iwi I~x~l w~lxllro Il~n)nv Ilwnw+Ll fill r~Mlt\17 AI W'U-II~K-Ali flan: ('-fI1Ff uPll i Il~-II is I'Iatt l'-1)i131 l7eaI..J N)': I)i~ilal Il '' ~~t'I~un Ilµq I)a1~:2 17211115 ('hiY'Aid. I)a1n. WI~:1 1 nl~.l All.% Nnmc N-~ - I~---N' Krn hmg IvsiniE I.anfuk I.n~yn~~h~ Urn t'ai3 2rNJ.bi{ 2w177~ cr)cy~NW.INf MW~IxI.IXi 711"17'Jxl7~N I J%'JII'IW,27~W' 111 TARGET DETAILS Name TVD +N/-S +Ef-W Northing Easting Shape ('-038 Kingak 8203.70 1864.71 1821.38 9961810.00 666280.00 Polygon C-036 Fault Zone 4 8593.70 193036 2478.02 9961890.00 666935.00 Polygon - C-036 Fault3 8962.70 208L07 2676.38 5962045.00 667130.00 Polygun C-036 Fault4 8962.70 1965.83 1543.50 )961905.00 666000.00 Pulygon C-036 Fault TZ16 8981.70 1916.74 2460.71 5961876.00 666')18.00 Polygon C-036 Fault 5 8983.70 1686.67 587.10 5961608,00 G6i050.00 Polygon C-03BT2 9007.70 1817.05 1942.37 8961765.00 666402.00 Point C-0367.3 9012.70 1719.88 1172A1 5961651.00 665634.00 Puint ' - C-03B Poly 9012.70 1804.76 2960.42 5961775.00 66742000 Polygon ' C-036 TI 9022.70 1916.74 2460.71 5961876.00 666918AU Point c 0 0 c z s '0 1 1 zoo- f I" - _ ' _ - - _ - _ ~ ~ ~ ~ ~i Stnrt Di :8620' MD, 77 .79'TVD ' I i ~_ __~ . _ i ~ I _- . ~ - -- -- -- -- -- - - - - _...:. I - j ' j Sear( Dir Eli 1110' :'86W MU; 7692..82'TVD - i - -. '' . ~ I' I - -- _ ~ I I L _. ~ - - FORMATION l'OP DEl'AILS --- - - -- _, ~ - - I ~ ~ ~. i 7000. ...+ ~ _ . - i .. .... _ ~, I I ~ , No. TVDPath MDPath Formatiun - ~ ~ ~ j i ~ ~ ~ - - ~ , , ~ ~ ~ I - I 7738.70 8653.89 LCU - - ~ ~ ~ ~ - ~ I I - ' 1 i -I - : CASING DETAILS - 2 8013.70 8971.41 TJD ~ ~ ~ ~ I I ~ 3 8192.70 9178.02 TJB _ ~ ~ _ ~ ~ _ ~ ~ _...... ~ T ~ No. TVD MD Name Size 4 8377.70 9391.56 TSGR _' + 5 8520.70 9546 65 l'SAD 1 ~ 6 i __ _ _ _ I 1 8377.70 9391.56 7" 7.000 6 8644.70 9679.57 TCGL ' ' ~ ~ ~ _ I ~ ! ~ _ - ~ 2 9012.70 II)69.00 4 I/2" 4.500 7 87_9.70 9761 66 B(Y]L I ~ I ~ ~ _ ~ 8 8')55.70 1003298 TZIB , ..-- I ... _ ~ ,- . L , -- - 1200 1400 1600 1800 2000 2200 2400 2600 2800 West(-1/East(+) [200ft'inJ - - S err -Sun i P Y BP Planning Report Company:' BP Amoco Date: 2/14/2005. Time: 16:19:05 Page: Field: Prtadhoe Bay Co-ardinate(NE)$eference: Weil' C-03; True North Site: PB C Pad Vertical (TVD) Reference: 28.5.+:35.2 63.7 Well: C-03 Section (VS) Reference: Welf (O.OON,O,OOE,34;27Azi} Wellpath: Plan C=03B Survey Calculation Method: ' Minimum Curvature Db: Oracle Plan: C-036 wp03 Date Composed: 2/3/2005 Version: 17 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2004 Site: PB C Pad TR-11-14 UNITED STATES :North Slope Site Position: Northing: 5957218.72 ft Latitude: 70 17 22.367 N From: Map Easting: 662550.03 ft Longitude: 148 41 2.797 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.24 deg Well: C-03 Slot Name: 03 C-03 Well Position: +N!-S 2644.68 ft Northing: 5959906.00 ft Latitude: 70 17 48.375 N +E(-W 2007.75 ft Easting : 664500.00 ft Longitude: 148 40 4.275 W Position Uncertainty: 0.00 ft Casing Points MD TVD Diameter Hole Size Name ft ft in in 9391.56 8377.70 7.000 8.500 7" 11569.00 9012.70 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction' ft fY deg deg:. 8653.89 7738.70 LCU 0.00 0.00 8971.41 8013.70 TJD 0.00 0.00 9178.02 8192.70 TJB 0.00 0.00 9391.56 8377.70 TSGR 0.00 0.00 9546.65 8520.70 TSAD 0.00 0.00 9673.57 8644.70 TCGL 0.00 0.00 9761.66 8729.70 BCGL 0.00 0.00 10039.98 8955.70 TZ16 0.00 0.00 0.00 BSAD 0.00 0.00 0.00 HOT 0.00 0.00 Targets Map Map <--- Latitude --->" <-- Longitude --->' Name' Description TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Ser Dip.. Din ft ft ft ft ft C-036 Kingak 8203.70 1864.71 1821.38 5961810.00 666280.00 70 18 6.712 N 148 39 11.171 W -Polygon 1 8203.70 1864.71 1821.38 5961810.00 666280.00 70 18 6.712 N 148 39 11.171 W -Polygon 2 8203.70 1815.24 2710.57 5961780.00 667170.00 70 18 6.223 N 148 38 45.247 W -Polygon 3 8203.70 1795.02 3405.34 5961775.00 667865.00 70 18 6.021 N 148 38 24.991 W -Polygon 4 8203.70 1815.24 2710.57 5961780.00 667170.00 70 18 6.223 N 148 38 45.247 W C-036 Fault Zone 4 8593.70 1930.36 2478.02 5961890.00 666935.00 70 18 7.356 N 148 38 52.026 W -Polygon 1 8593.70 1930.36 2478.02 5961890.00 666935.00 70 18 7.356 N 148 38 52.026 W -Polygon 2 8593.70 1907.37 2842.63 5961875.00 667300.00 70 18 7.129 N 148 38 41.396 W -Polygon 3 8593.70 1848.37 3481.53 5961830.00 667940.00 70 18 6.546 N 148 38 22.769 W -Polygon 4 8593.70 1907.37 2842.63 5961875.00 667300.00 70 18 7.129 N 148 38 41.396 W C-036 Fault 3 8962.70 2081.07 2676.38 5962045.00 667130.00 70 18 8.837 N 148 38 46.241 W -Polygon 1 8962.70 2081.07 2676.38 5962045.00 667130.00 70 18 8.837 N 148 38 46.241 W -Polygon 2 8962.70 2425.64 2929.00 5962395.00 667375.00 70 18 12.225 N 148 38 38.871 W S err -sun P Y BP Planning Report Companyt BP AmoCO Date: 2(14/2005 Time: 16:19:05 . ~ ~ Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: WeIL C-03, True North . Site: PB G Pad Vertical (TVD) Reference: 28:5.+ 35.263:7 Well: C-03 Section (~?S)Reference: Welf(O.OON,I).006,34.27Azi) Wellpath: Plan C-036 Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <-- Latitude ----> ~. Longitude ~> Name Description TV D +N/-S +FJ-W Northi ng Easting Deg Min Sec Deg Mi n Sec - Dip... . Dir. ft ft ft ft ft C-03B Fault 4 8962. 70 1965. 83 1543.50 5961905 .00 666000.00 70 18 7.707 N 148 39 19.272 W -Polygon 1 8962. 70 1965. 83 1543.50 5961905 .00 666000.00 70 18 7.707 N 148 39 19.272 W -Polygon 2 8962. 70 2062. 49 1925.74 5962010 .00 666380.00 70 18 8.657 N 148 39 8.127 W C-036 Fault TZ1B 8981. 70 1916. 74 2460.71 5961876 .00 666918.00 70 18 7.222 N 148 38 52.530 W -Polygon 1 8981. 70 1599. 90 895.30 5961525 .00 665360.00 70 18 4.109 N 148 39 38.173 W -Polygon 2 8981. 70 1514. 77 1813.72 5961460 .00 666280.00 70 18 3.270 N 148 39 11.397 W -Polygon 3 8981. 70 1457. 89 2812.78 5961425 .00 667280.00 70 18 2.708 N 148 38 42.271 W -Polygon 4 8981. 70 1514. 77 1813.72 5961460 .00 666280.00 70 18 3.270 N 148 39 11.397 W C-036 Fault 5 8983. 70 1686. 67 587.10 5961605 .00 665050.00 70 18 4.963 N 148 39 47.158 W -Polygon 1 8983. 70 1686. 67 587.10 5961605 .00 665050.00 70 18 4.963 N 148 39 47.158 W -Polygon 2 8983. 70 1931. 23 1067.60 5961860 .00 665525.00 70 18 7.368 N 148 39 33.148 W -Polygon 3 8983. 70 2099. 09 1396.37 5962035 .00 665850.00 70 18 9.018 N 148 39 23.561 W -Polygon 4 8983. 70 1931. 23 1067.60 5961860 .00 665525.00 70 18 7.368 N 148 39 33.148 W C-036 T2 9007. 70 1817. 05 1942.37 5961765 .00 666402.00 70 18 6.243 N 148 39 7.644 W C-036 T3 9012. 70 1719. 88 1172.01 5961651 .00 665634.00 70 18 5.289 N 148 39 30.105 W C-03B Poly 9012. 70 1804. 76 2960.42 5961775 .00 667420.00 70 18 6.119 N 148 38 37.962 W -Polygon 1 9012. 70 1804. 76 2960.42 5961775 .00 667420.00 70 18 6.119 N 148 38 37.962 W -Polygon 2 9012. 70 1803. 96 2540.27 5961765 .00 667000.00 70 18 6.113 N 148 38 50.212 W -Polygon 3 9012. 70 1628. 00 1896.22 5961575 .00 666360.00 70 18 4.384 N 148 39 8.991 W -Polygon 4 9012. 70 1678. 97 1167.11 5961610 .00 665630.00 70 18 4.887 N 148 39 30.248 W -Polygon 5 9012. 70 1838. 95 1170.61 5961770 .00 665630.00 70 18 6.460 N 148 39 30.145 W -Polygon 6 9012. 70 1840. 19 1570.76 5961780 .00 666030.00 70 18 6.471 N 148 39 18.478 W -Polygon 7 9012. 70 1984. 18 2304.14 5961940 .00 666760.00 70 18 7.886 N 148 38 57.095 W -Polygon 8 9012. 70 1994. 73 2964.58 5961965 .00 667420.00 70 18 7.987 N 148 38 37.839 W C-036 T1 9022. 70 1916. 74 2460.71 5961876 .00 666918.00 70 18 7.222 N 148 38 52.530 W Plan Section Information MD Ind Azim TVD +N/-S +E/-W DLS Build. Turn TFO Target ft deg deg ft ff ft deg/100ft deg/100ft degl100ff deg 8600.00 31.79 69.64 7692.82 1682.94 2442.40 0.00 0 .00 0.00 0.00 8620.00 32.08 65.14 7709.79 1687.01 2452.16 12.00 1 .45 -22.52 -85.00 8677.74 29.96 63.36 7759.27 1699.93 2478.96 4.00 -3. 67 -3.08 -157.38 9410.37 29.96 63.36 8394.00 1864.00 2806.00 0.00 0 .00 0.00 0.00 9669.12 15.23 307.73 8640.41 1915.77 2838.11 15.00 -5. 69 -44.69 -157.80 9763.65 15.23 307.73 8731.62 1930.96 2818.47 0.00 0 .00 0.00 0.00 10265.05 90.00 258.00 9022.70 1916.74 2460.71 16.00 14 .91 -9.92 -50.74 C-038 T1 10277.35 91.85 258.68 9022.50 1914.25 2448.67 16.00 15 .01 5.55 20.27 10680.40 91.85 258.68 9009.52 1835.19 2053.66 0.00 0 .00 0.00 0.00 10793.20 90.00 262.80 9007.70 1817.05 1942.37 4.00 -1. 64 3.65 114.11 C-036 T2 10802.49 89.63 262.81 9007.73 1815.89 1933.16 4.00 -4. 00 0.12 178.29 11569.69 89.63 262.81 9012.70 1719.88 1172.01 0.00 0. 00 0.00 0.00 C-036 T3 S err -Sun p Y BP Planning Report Company: BP Amoco Date: 2/14/2005 Time: 16:19:05 Page:: 3 Field: Prudhoe bay Co-ordinate(NE) Reference: WeIL C-03; True North Site: PB C Pad Vertical'(TVD) Reference: 28.5 + 35.2 63.7 Well: C-03 Section (VS) Reference: Welf {O.OON,000E,34.27Azi) Wellpatb:- Plan C-036 Survey Calculation Metbod: Minimum Curvature Db: Oracle Survey MD Inc! Azim TVD Sys TVD N/5 E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft deg/100ft fti ft 8600.00 31.79 69.64 7692.82 7629.12 1682.94 2442.40 0.00 5961641.88 666904.81 Start Dir 12/10 8610.00 31.92 67.38 7701.31 7637.61 1684.88 2447.31 12.00 5961643.92 666909.68 MWD+IFR+MS 8620.00 32.08 65.14 7709.79 7646.09 1687.01 2452.16 12.00 5961646.16 666914.48 Start Dir 4!100 8630.00 31.71 64.84 7718.28 7654.58 1689.25 2456.95 4.00 5961648.50 666919.22 MWD+IFR+MS 8640.00 31.34 64.54 7726.81 7663.11 1691.48 2461.68 4.00 5961650.84 666923.89 MWD+IFR+MS 8650.00 30.98 64.24 7735.36 7671.66 1693.72 2466.34 4.00 5961653.17 666928.51 MWD+IFR+MS 8653.89 30.83 64.12 7738.70 7675.00 1694.59 2468.14 4.00 5961654.08 666930.29 LCU 8660.00 30.61 63.93 7743.95 7680.25 1695.95 2470.95 4.00 5961655.51 666933.06 MWD+IFR+MS 8670.00 30.24 63.61 7752.58 7688.88 1698.19 2475.49 4.00 5961657.85 666937.56 MWD+IFR+MS 8677.74 29.96 63.36 7759.27 7695.57 1699.93 2478.96 4.00 5961659.66 666940.99 End Dir :8677 8680.00 29.96 63.36 7761.23 7697.53 1700.43 2479.97 0.00 5961660.19 666941.99 MWD+IFR+MS 8690.00 29.96 63.36 7769.89 7706.19 1702.67 2484.43 0.00 5961662.52 666946.40 MWD+IFR+MS 8700.00 29.96 63.36 7778.56 7714.86 1704.91 2488.90 0.00 5961664.86 666950.81 MWD+IFR+MS 8710.00 29.96 63.36 7787.22 7723.52 1707.15 2493.36 0.00 5961667.20 666955.23 MWD+IFR+MS 8720.00 29.96 63.36 7795.89 7732.19 1709.39 2497.83 0.00 5961669.53 666959.64 MWD+IFR+MS 8730.00 29.96 63.36 7804.55 7740.85 1711.63 2502.29 0.00 5961671.87 666964.05 MWD+IFR+MS 8740.00 29.96 63.36 7813.21 7749.51 1713.87 2506.75 0.00 5961674.20 666968.47 MWD+IFR+MS 8750.00 29.96 63.36 7821.88 7758.18 1716.11 2511.22 0.00 5961676.54 666972.88 MWD+IFR+MS 8760.00 29.96 63.36 7830.54 7766.84 1718.35 2515.68 0.00 5961678.88 666977.30 MWD+{FR+MS 8770.00 29.96 63.36 7839.20 7775.50 1720.59 2520.15 0.00 5961681.21 666981.71 MWD+IFR+MS 8780.00 29.96 63.36 7847.87 7784.17 1722.83 2524.61 0.00 5961683.55 666986.12 MWD+IFR+MS 8790.00 29.96 63.36 7856.53 7792.83 1725.07 2529.07 0.00 5961685.89 666990.54 MWD+IFR+MS 8800.00 29.96 63.36 7865.19 7801.49 1727.31 2533.54 0.00 5961688.22 666994.95 MWD+IFR+MS 8810.00 29.96 63.36 7873.86 7810.16 1729.55 2538.00 0.00 5961690.56 666999.36 MWD+IFR+MS 8820.00 29.96 63.36 7882.52 7818.82 1731.79 2542.47 0.00 5961692.90 667003.78 MWD+IFR+MS 8830.00 29.96 63.36 7891.19 7827.49 1734.02 2546.93 0.00 5961695.23 667008.19 MWD+IFR+MS 8840.00 29.96 63.36 7899.85 7836.15 1736.26 2551.39 0.00 5961697.57 667012.60 MWD+IFR+MS 8850.00 29.96 63.36 7908.51 7844.81 1738.50 2555.86 0.00 5961699.91 667017.02 MWD+IFR+MS 8860.00 29.96 63.36 7917.18 7853.48 1740.74 2560.32 0.00 5961702.24 667021.43 MWD+-FR+MS 8870.00 29.96 63.36 7925.84 7862.14 1742.98 2564.78 0.00 5961704.58 667025.84 MWD+IFR+MS 8880.00 29.96 63.36 7934.50 7870.80 1745.22 2569.25 0.00 5961706.92 667030.26 MWD+IFR+MS 8890.00 29.96 63.36 7943.17 7879.47 1747.46 2573.71 0.00 5961709.25 667034.67 MWD+IFR+MS 8900.00 29.96 63.36 7951.83 7888.13 1749.70 2578.18 0.00 5961711.59 667039.08 MWD+IFR+MS 8910.00 29.96 63.36 7960.49 7896.79 1751.94 2582.64 0.00 5961713.93 667043.50 MWD+IFR+MS 8920.00 29.96 63.36 7969.16 7905.46 1754.18 2587.10 0.00 5961716.26 667047.91 MWD+IFR+MS 8930.00 29.96 63.36 7977.82 7914.12 1756.42 2591.57 0.00 5961718.60 667052.32 MWD+IFR+MS 8940.00 29.96 63.36 7986.49 7922.79 1758.66 2596.03 0.00 5961720.94 667056.74 MWD+IFR+MS 8950.00 29.96 63.36 7995.15 7931.45 1760.90 2600.50 0.00 5961723.27 667061.15 MWD+IFR+MS 8960.00 29.96 63.36 8003.81 7940.91 1763.14 2604.96 0.00 5961725.61 667065.56 MWD+IFR+MS 8970.00 29.96 63.36 8012.48 7948.78 1765.38 2609.42 0.00 5961727.94 667069.98 MWD+IFR+MS 8971.41 29.96 63.36 8013.70 7950.00 1765.69 2610.05 0.00 5961728.27 667070.60 TJD 8980.00 29.96 63.36 8021.14 7957.44 1767.62 2613.89 0.00 5961730.28 667074.39 MWD+IFR+MS 8990.00 29.96 63.36 8029.80 7966.10 1769.86 2618.35 0.00 5961732.62 667078.81 MWD+IFR+MS 9000.00 29.96 63.36 8038.47 7974.77 1772.10 2622.81 0.00 5961734.95 667083.22 MWD+IFR+MS 9010.00 29.96 63.36 8047.13 7983.43 1774.34 2627.28 0.00 5961737.29 667087.63 MWD+IFR+MS 9020.00 29.96 63.36 8055.79 7992.09 1776.58 2631.74 0.00 5961739.63 667092.05 MWD+IFR+MS 9030.00 29.96 63.36 8064.46 8000.76 1778.81 2636.21 0.00 5961741.96 667096.46 MWD+IFR+MS 9040.00 29.96 63.36 8073.12 8009.42 1781.05 2640.67 0.00 5961744.30 667100.87 MWD+IFR+MS 9050.00 29.96 63.36 8081.79 8018.09 1783.29 2645.13 0.00 5961746.64 667105.29 MWD+IFR+MS 9060.00 29.96 63.36 8090.45 8026.75 1785.53 2649.60 0.00 5961748.97 667109.70 MWD+IFR+MS 9070.00 29.96 63.36 8099.11 8035.41 1787.77 2654.06 0.00 5961751.31 667114.11 MWD+IFR+MS 9080.00 29.96 63.36 8107.78 8044.08 1790.01 2658.53 0.00 5961753.65 667118.53 MWD+IFR+MS 9090.00 29.96 63.36 8116.44 8052.74 1792.25 2662.99 0.00 5961755.98 667122.94 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: BP Amoco Date: 2/14/2005 Time: 16:19:05 --- Page: 4 Fietd: Piudhoe$ay Co-ordinate(NE) Reference: Well: C-03, True North Site: PB C Pad Vertical (TVD) Reference: 28.5.+35.2 63:7 Well: G03 Section (VS) Reference: Well (O.OON,O. OOE,34.27Azi} , Wetlpath: Plan C-U3B Survey Calculation Method: Minimum Curvature Db: Oracle survey MD Inch Azim TVD Sys TVD , N!S E!W DLS MapN MapE TooUComme t ft deg deg. ft fit ft ft degJ100ft ft ft 9100.00 29.96 63.36 8125.10 8061.40 1794.49 2667.45 0.00 5961758.32 667127.35 MWD+IFR+MS 9110.00 29.96 63.36 8133.77 8070.07 1796.73 2671.92 0.00 5961760.66 667131.77 MWD+IFR+MS 9120.00 29.96 63.36 8142.43 8078.73 1798.97 2676.38 0.00 5961762.99 667136.18 MWD+IFR+MS 9130.00 29.96 63.36 8151.09 8087.39 1801.21 2680.85 0.00 5961765.33 667140.59 MWD+IFR+MS 9140.00 29.96 63.36 8159.76 8096.06 1803.45 2685.31 0.00 5961767.67 667145.01 MWD+IFR+MS 9150.00 29.96 63.36 8168.42 8104.72 1805.69 2689.77 0.00 5961770.00 667149.42 MWD+IFR+MS 9160.00 29.96 63.36 8177.09 8113.39 1807.93 2694.24 0.00 5961772.34 667153.83 MWD+IFR+MS 9170.00 29.96 63.36 8185.75 8122.05 1810.17 2698.70 0.00 5961774.68 667158.25 MWD+IFR+MS 9178.02 29.96 63.36 8192.70 8129.00 1811.96 2702.28 0.00 5961776.55 667161.79 TJB 9180.00 29.96 63.36 8194.41 8130.71 1812.41 2703.16 0.00 5961777.01 667162.66 MWD+IFR+MS 9190.00 29.96 63.36 8203.08 8139.38 1814.65 2707.63 0.00 5961779.35 667167.07 MWD+IFR+MS 9190.72 29.96 63.36 8203.70 8140.00 1814.81 2707.95 0.00 5961779.52 667167.39 C-036 Kingak 9200.00 29.96 63.36 8211.74 8148.04 1816.89 2712.09 0.00 5961781.68 667171.49 MWD+IFR+MS 9210.00 29.96 63.36 8220.40 8156.70 1819.13 2716.56 0.00 5961784.02 667175.90 MWD+IFR+MS 9220.00 29.96 63.36 8229.07 8165.37 1821.37 2721.02 0.00 5961786.36 667180.31 MWD+IFR+MS 9230.00 29.96 63.36 8237.73 8174.03 1823.61 2725.48 0.00 5961788.69 667184.73 MWD+IFR+MS 9240.00 29.96 63.36 8246.39 8182.69 1825.84 2729.95 0.00 5961791.03 667189.14 MWD+IFR+MS 9250.00 29.96 63.36 8255.06 8191.36 1828.08 2734.41 0.00 5961793.37 667193.58 MWD+IFR+MS 9260.00 29.96 63.36 8263.72 8200.02 1830.32 2738.88 0.00 5961795.70 667197.97 MWD+IFR+MS 9270.00 29.96 63.36 8272.39 8208.69 1832.56 2743.34 0.00 5961798.04 667202.38 MWD+{FR+MS 9280.00 29.96 63.36 8281.05 8217.35 1834.80 2747.80 0.00 5961800.38 667206.80 MWD+IFR+MS 9290.00 29.96 63.36 8289.71 8226.01 1837.04 2752.27 0.00 5961802.71 667211.21 MWD+IFR+MS 9300.00 29.96 63.36 8298.38 8234.68 1839.28 2756.73 0.00 5961805.05 667215.62 MWD+IFR+MS 9310.00 29.96 63.36 8307.04 8243.34 1841.52 2761.19 0.00 5961807.39 667220.04 MWD+IFR+MS 9320.00 29.96 63.36 8315.70 8252.00 1843.76 2765.66 0.00 5961809.72 667224.45 MWD+IFR+MS 9330.00 29.96 63.36 8324.37 8260.67 1846.00 2770.12 0.00 5961812.06 667228.86 MWD+IFR+MS 9340.00 29.96 63.36 8333.03 8269.33 1848.24 2774.59 0.00 5961814.40 667233.28 MWD+IFR+MS 9350.00 29.96 63.36 8341.69 8277.99 1850.48 2779.05 0.00 5961816.73 667237.69 MWD+IFR+MS 9360.00 29.96 63.36 8350.36 8286.66 1852.72 2783.51 0.00 5961819.07 667242.10 MWD+IFR+MS 9370.00 29.96 63.36 8359.02 8295.32 1854.96 2787.98 0.00 5961821.41 667246.52 MWD+IFR+MS 9380.00 29.96 63.36 8367.69 8303.99 1857.20 2792.44 0.00 5961823.74 667250.93 MWD+IFR+MS 9390.00 29.96 63.36 8376.35 8312.65 1859.44 2796.91 0.00 5961826.08 667255.34 MWD+IFR+MS 9391.56 29.96 63.36 8377.70 8314.00 1859.79 2797.60 0.00 5961826.44 667256.03 7" 9400.00 29.96 63.36 8385.01 8321.31 1861.68 2801.37 0.00 5961828.41 667259.76 MWD+IFR+MS 9410.00 29.96 63.36 8393.68 8329.98 1863.92 2805.83 0.00 5961830.75 667264.17 MWD+IFR+MS 9410.37 29.96 63.36 8394.00 8330.30 1864.00 2806.00 0.00 5961830.84 667264.33 Start Dir 15110 9420.00 28.63 62.22 8402.40 8338.70 1866.15 2810.19 14.99 5961833.08 667268.48 MWD+IFR+MS 9430.00 27.26 60.93 8411.23 8347.53 1868.38 2814.31 15.00 5961835.40 667272.55 MWD+IFR+MS 9440.00 25.90 59.51 8420.17 8356.47 1870.60 2818.19 15.00 5961837.71 667276.38 MWD+IFR+MS 9450.00 24.55 57.95 8429.22 8365.52 1872.81 2821.84 15.00 5961840.00 667279.97 MWD+IFR+MS 9460.00 23.22 56.23 8438.36 8374.66 1875.01 2825.24 15.00 5961842.27 667283.33 MWD+IFR+MS 9470.00 21.92 54.30 8447.60 8383.90 1877.20 2828.39 15.00 5961844.52 667286.43 MWD+IFR+MS 9480.00 20.64 52.15 8456.91 8393.21 1879.37 2831.30 15.00 5961846.76 667289.29 MWD+IFR+MS 9490.00 19.39 49.73 8466.31 8402.61 1881.52 2833.96 15.00 5969848.97 667291.90 MWD+IFR+MS 9500.00 18.17 47.00 8475.78 8412.08 1883.66 2836.36 15.00 5961851.16 667294.26 MWD+IFR+MS 9510.00 17.00 43.89 8485.31 8421.61 1885.78 2838.52 15.00 5961853.32 667296.37 MWD+IFR+MS 9520.00 15.88 40.35 8494.90 8431.20 1887.87 2840.42 15.00 5961855.46 667298.22 MWD+IFR+MS 9530.00 14.83 36.31 8504.54 8440.84 1889.95 2842.06 15.00 5961857.57 667299.82 MWD+IFR+MS 9540.00 13,86 31.69 8514.23 8450.53 1892.00 2843.45 15.00 5961859.65 667301.16 MWD+IFR+MS 9546.65 13.27 28.26 8520.70 8457.00 1893.35 2844.23 15.00 5961861.02 667301.91 TSAD 9550.00 12.99 26.43 8523.96 8460.26 1894.02 2844.58 15.00 5961861.70 667302.25 MWD+IFR+MS 9560.00 12.24 20.48 8533.72 8470.02 1896.02 2845.45 15.00 5961863.72 667303.07 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: BP Amoco Date: 2/14!2005 Time: 16':19:05 Page;. 5 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: C-03, True North Site: PB C Pad Vertical (TVD) Reference: 28.5 +35.2 63.7 Well: C-03 Section (VS) Reference: Well (O.OOtV,0,00E,34.27Azi) Wellpath: Plan.C-03B Survey Calculation Method: Minimum Curvature Db: _. OraCie Survey MD Inc! Azim TVD Sys TVD N/S E!W DLS Mapl~i MapE TooUGomme t ft deg deg ft ft ft ft deg/100ft ft ' ft 9570.00 11.63 13.84 8543.50 8479.80 1898.00 2846.06 15.00 5961865.70 667303.64 MWD+IFR+MS 9580.00 11.19 6.59 8553.31 8489.61 1899.94 2846.41 15.00 5961867.65 667303.95 MWD+IFR+MS 9590.00 10.94 358.88 8563.12 8499.42 1901.85 2846.51 15.00 5961869.57 667304.00 MWD+IFR+MS 9600.00 10.88 350.95 8572.94 8509.24 1903.73 2846.34 15.00 5961871.44 667303.79 MWD+{FR+MS 9610.00 11.03 343.09 8582.76 8519.06 1905.58 2845.91 15.00 5961873.28 667303.33 MWD+{FR+MS 9620.00 11.38 335.58 8592.57 8528.87 1907.39 2845.23 15.00 5961875.08 667302.60 MWD+{FR+MS 9621.15 11.43 334.74 8593.70 8530.00 1907.60 2845.13 15.00 5961875.28 667302.50 C-03B Fault Zo 9630.00 11.90 328.60 8602.36 8538.66 1909.17 2844.28 15.00 5961876.84 667301.62 MWD+IFR+MS 9640.00 12.58 322.29 8612.14 8548.44 1910.91 2843.08 15.00 5961878.55 667300.38 MWD+IFR+MS 9650.00 13.39 316.66 8621.88 8558.18 1912.62 2841.62 15.00 5961880.22 667298.88 MWD+IFR+MS 9660.00 14.31 311.71 8631.59 8567.89 1914.28 2839.90 15.00 5961881.85 667297.13 MWD+IFR+MS 9669.12 15.23 307.73 8640.41 8576.71 1915.77 2838.11 15.00 5961883.29 667295.30 End Dir :9669 9670.00 15.23 307.73 8641.26 8577.56 1915.91 2837.93 0.08 5961883.43 667295.12 MWD+IFR+MS 9673.57 15.23 307,73 8644,70 8581.00 1916.48 2837.19 0.00 5961883.99 667294.37 TCGL 9680.00 15.23 307.73 8650.91 8587.21 1917.51 2835.85 0.00 5961884.99 667293.01 MWD+-FR+MS 9690.00 15.23 307.73 8660.56 8596.86 1919.12 2833.77 0.00 5961886.55 667290.89 MWD+IFR+MS 9700.00 15.23 307.73 8670.21 8606.51 1920.73 2831.70 0.00 5961888.11 667288.78 MWD+IFR+MS 9710.00 15.23 307.73 8679.85 8616.15 1922.34 2829.62 0.00 5961889.68 667286.67 MWD+IFR+MS 9720.00 15.23 307.73 8689.50 8625.80 1923.94 2827.54 0.00 5961891.24 667284.56 MWD+IFR+MS 9730.00 15.23 307.73 8699.15 8635.45 1925.55 2825.46 0.00 5961892.80 667282.45 MWD+IFR+MS 9740.00 15.23 307.73 8708.80 8645.10 1927.16 2823.39 0.00 5961894.36 667280.33 MWD+IFR+MS 9750.00 15.23 307.73 8718.45 8654.75 1928.77 2821.31 0.00 5961895.92 667278.22 MWD+IFR+MS 9760.00 15.23 307.73 8728.10 8664.40 1930.38 2819.23 0.00 5961897.48 667276.11 MWD+IFR+MS 9761.66 15.23 307.73 8729.70 8666.00 1930.64 2818.89 0.00 5961897.74 667275.76 BCGL 9763.65 15.23 307.73 8731.62 8667.92 1930.96 2818.47 0.00 5961898.05 667275.34 Start Dir 16/10 9770.00 15.89 304.86 8737.74 8674.04 1931.97 2817.10 16.00 5961899.03 667273.94 MWD+IFR+MS 9780.00 17.00 300.79 8747.33 8683.63 1933.50 2814.72 16.00 5961900.51 667271.53 MWD+IFR+MS 9790.00 18.19 297.22 8756.86 8693.16 1934.96 2812.08 16.00 5961901.91 667268.86 MWD+IFR+MS 9800.00 19.43 294.09 8766.33 8702.63 1936.36 2809.17 16.00 5961903.24 667265.92 MWD+IFR+MS 9810.00 20.72 291.32 8775.72 8712.02 1937.68 2806.00 16.00 5961904.49 667262.73 MWD+IFR+MS 9820.00 22.04 288.87 8785.03 8721.33 1938.93 2802.58 16.00 5961905.67 667259.28 MWD+IFR+MS 9830.00 23.40 286.68 8794.25 8730.55 1940.10 2798.90 16.00 5961906.76 667255.57 MWD+IFR+MS 9840.00 24.79 284.73 8803.38 8739.68 1941.21 2794.97 16.00 5961907.78 667251.62 MWD+IFR+MS 9850.00 26.20 282.97 8812.41 8748.71 1942.24 2790.79 16.00 5961908.72 667247.42 MWD+IFR+MS 9860.00 27.63 281.38 8821.33 8757.63 1943.19 2786.37 16.00 5961909.57 667242.98 MWD+IFR+MS 9870.00 29.07 279.94 8830.13 8766.43 1944.07 2781.70 16.00 5961910.35 667238.29 MWD+IFR+MS 9880.00 30.53 278.62 8838.80 8775.10 1944.87 2776.80 16.00 5961911.04 667233.37 MWD+IFR+MS 9890.00 32.01 277.41 8847.35 8783.65 1945.59 2771.66 16.00 5961911.65 667228.22 MWD+IFR+MS 9900.00 33.49 276.30 8855.76 8792.06 1946.23 2766.29 16.00 5961912.18 667222.83 MWD+IFR+MS 9910.00 34.98 275.27 8864.03 8800.33 1946.80 2760.69 16.00 5961912.62 667217.23 MWD+IFR+MS 9920.00 36.48 274.32 8872.15 8808.45 1947.29 2754.87 16.00 5961912.98 667211.40 MWD+IFR+MS 9930.00 37.99 273.43 8880.11 8816.41 1947.69 2748.83 16.00 5961913.26 667205.36 MWD+IFR+MS 9940.00 39.50 272.60 8887.91 8824.21 1948.02 2742.58 16.00 5961913.45 667199.10 MWD+IFR+MS 9950.00 41.02 271.82 8895.54 8831.84 1948.27 2736.13 16.00 5961913.55 667192.64 MWD+IFR+MS 9960.00 42.54 271.08 8903.00 8839.30 1948.44 2729.47 16.00 5961913.58 667185.98 MWD+IFR+MS 9970.00 44.07 270.39 8910.27 8846.57 1948.53 2722.61 16.00 5961913.51 667179.12 MWD+IFR+MS 9980.00 45.60 269.74 8917.36 8853.66 1948.53 2715.56 16.00 5961913.37 667172.07 MWD+IFR+MS 9990.00 47.14 269.12 8924.26 8860.56 1948.46 2708.32 16.00 5961913.14 667164.84 MWD+IFR+MS 10000.00 48.68 268.52 8930.97 8867.27 1948.31 2700.90 16.00 5961912.82 667157:42 MWD+IFR+MS 10010.00 50.22 267.96 8937.47 8873.77 1948.07 2693.31 16.00 5961912.42 667149.84 MWD+IFR+MS 10020.00 51.76 267.42 8943.76 8880.06 1947.76 2685.54 16.00 5961911.94 667142.08 MWD+IFR+MS 10030.00 53.31 266.90 8949.84 8886.14 1947.37 2677.62 16.00 5961911.37 667134.17 MWD+IFR+MS 10039.98 54.85 266.41 8955.70 8892.00 1946.90 2669.55 16.00 5961910.72 667126.11 TZ1 B S err -Sun P Y BP Planning Report Company:- BP Amoco Date: 2/14/2005 Time: 16;19:05 Page; 6 Field: Prudhoe Bay Co-0rdinate(NE) Reference:. : WeIL' C-03, True North Site: PB C Pad Vertical (TVD) Reference: 28:5 + 35.2 63.7 Well: C-03 Section (VS) Reference: Well (O.OON,O: OOE,3427Azi} Wellpath: Plan C-036 Survey Calcu-ation Method:. Minimum Curvature Db: Orate Survey MD Iucl Azim TVD Sys TVD N/S E/W DLS MapN MapE TooUComme t ft deg deg ft ft ft ft - deg/100ft ' ft ` ft 10040.00 54.86 266.41 8955.71 8892.01 1946.89 2669.53 16.00 5961910.72 667126.10 MWD+IFR+MS 10050.00 56.41 265.93 8961.36 8897.66 1946.34 2661.30 16.00 5961909.99 667117.87 MWD+IFR+MS 10052.44 56.79 265.82 8962.70 8899.00 1946.20 2659.26 16.00 5961909.80 667115.84 C-03B Fauit 3 10060.00 57.96 265.47 8966.77 8903.07 1945.71 2652.92 16.00 5961909.18 667109.51 MWD+IFR+MS 10070.00 59.51 265.02 8971.96 8908.26 1945.00 2644.40 16.00 5961908.28 667101.01 MWD+IFR+MS 10080.00 61.07 264.59 8976.92 8913.22 1944.22 2635.75 16.00 5961907.31 667092.38 MWD+IFR+MS 10090.00 62.63 264.17 8981.64 8917.94 1943.35 2626.97 16.00 5961906.25 667083.63 MWD+IFR+MS 10090.14 62.65 264.17 8981.70 8918.00 1943.34 2626.85 16.00 5961906.24 667083.51 C-03B Fault TZ 10094.54 63.33 263.99 8983.70 8920.00 1942.94 2622.95 16.00 5961905.75 667079.61 C-036 Fault 5 10100.00 64.19 263.77 8986.11 8922.41 1942.42 2618.08 16.00 5961905.12 667074.76 MWD+IFR+MS 10110.00 65.74 263.37 8990.35 8926.65 1941.40 2609.08 16.00 5961903.91 667065.78 MWD+IFR+MS 10129.00 67.30 262.98 8994.33 8930.63 1940.31 2599.97 16.00 5961902.62 667056.70 MWD+IFR+MS 10130.00 68.87 262.61 8998.06 8934.36 1939.15 2590.77 16.00 5961901.25 667047.52 MWD+IFR+MS 10140.00 70.43 262.24 9001.54 8937.84 1937.91 2581.47 16.00 5961899.81 667038.26 MWD+IFR+MS 10150.00 71.99 261.87 9004.76 8941.06 1936.60 2572.10 16.00 5961898.30 667028.92 MWD+IFR+MS 10160.00 73.55 261.52 9007.72 8944.02 1935.22 2562.65 16.00 5961896.71 667019.50 MWD+IFR+MS 10170.00 75.12 261.16 9010.42 8946.72 1933.77 2553.13 16.00 5961895.05 667010.02 MWD+IFR+MS 10179.32 76.57 260.84 9012.70 8949.00 1932.36 2544.21 16.00 5961893.45 667001.13 C-036 Poly 10180.00 76.68 260.82 9012.86 8949.16 1932.25 2543.55 16.00 5961893.33 667000.47 MWD+IFR+MS 10190.00 78.25 260.48 9015.03 8951.33 1930.67 2533.92 16.00 5961891.53 666990.88 MWD+IFR+MS 10200.00 79.81 260.14 9016.93 8953.23 1929.01 2524.24 16.00 5961889.67 666981.24 MWD+IFR+MS 10210.00 81.38 259.81 9018.57 8954.87 1927.30 2514.53 16.00 5961887.74 666971.57 MWD+IFR+MS 10220.00 82.94 259.47 9019.93 8956.23 1925.51 2504.78 16.00 5961885.74 666961.87 MWD+IFR+MS 10230.00 84.51 259.14 9021.02 8957.32 1923.67 2495.02 16.00 5961883.68 666952.14 MWD+IFR+MS 10240.00 86.08 258.82 9021.84 8958.14 1921.77 2485.23 16.00 5961881.57 666942.40 MWD+IFR+MS 10250.00 87.64 258.49 9022.39 8958.69 1919.80 2475.44 16.00 5961879.39 666932.66 MWD+IFR+MS 10260.00 89.21 258.16 9022.67 8958.97 1917.78 2465.65 16.00 5961877.15 666922.92 MWD+IFR+MS 10265.05 90.00 258.00 9022.70 8959.00 1916.74 2460.71 16.00 5961876.00 666918.00 C-03B T1 10270.00 90.74 258.27 9022.67 8958.97 1915.72 2455.87 16.00 5961874.88 666913.18 MWD+IFR+MS 10277.35 91.85 258.68 9022.50 8958.80 1914.25 2448.67 16.00 5961873.25 666906.02 End Dir :1027 10280.00 91.85 258.68 9022.42 8958.72 1913.73 2446.07 0.00 5961872.68 666903.43 MWD+IFR+MS 10290.00 91.85 258.68 9022.09 8958.39 1911.77 2436.27 0.00 5961870.50 666893.68 MWD+iFR+MS 10300.00 91.85 258.68 9021.77 8958.07 1909.81 2426.47 0.00 5961868.33 666883.92 MWD+IFR+MS 10310.00 91.85 258.68 9021.45 8957.75 1907.85 2416.67 0.00 5961866.15 666874.17 MWD+IFR+MS 10320.00 91.85 258.68 9021.13 8957.43 1905.88 2406.87 0.00 5961863.97 666864.41 MWD+IFR+MS 10330.00 91.85 258.68 9020.81 8957.11 1903.92 2397.07 0.00 5961861.80 666854.66 MWD+IFR+MS 10340.00 91.85 258.68 9020.48 8956.78 1901.96 2387.27 0.00 5961859.62 666844.90 MWD+IFR+MS 10350.00 91,85 258.68 9020.16 8956.46 1900.00 2377.47 0.00 5961857.45 666835.15 MWD+IFR+MS 10360.00 91.85 258.68 9019.84 8956.14 1898.04 2367.67 0.00 5961855.27 666825.39 MWD+IFR+MS 10370.00 91.85 258.68 9019.52 8955.82 1896.08 2357.87 0.00 5961853.10 666815.64 MWD+IFR+MS 10380.00 91.85 258.68 9019.20 8955.50 1894.12 2348.07 0.00 5961850.92 666805.89 MWD+IFR+MS 10390.00 91.85 258.68 9018.87 8955.17 1892.15 2338.27 0.00 5961848.75 666796.13 MWD+IFR+MS 10400.00 91.85 258.68 9018.55 8954.85 1890.19 2328.47 0.00 5961846.57 666786.38 MWD+IFR+MS 10410.00 91.85 258.68 9018.23 8954.53 1888.23 2318.67 0.00 5961844.40 666776.62 MWD+IFR+MS 10420.00 91.85 258.68 9017.91 8954.21 1886.27 2308.87 0.00 5961842.22 666766.87 MWD+IFR+MS 10430.00 91.85 258.68 9017.58 8953.88 1884.31 2299.07 0.00 5961840.05 666757.11 MWD+IFR+MS 10440.00 91.85 258.68 9017.26 8953.56 1882.35 2289.27 0.00 5961837.87 666747.36 MWD+IFR+MS 10450.00 91.85 258.68 9016.94 8953.24 1880.38 2279.46 0.00 5961835.69 666737.60 MWD+tFR+MS 10460.00 91.85 258.68 9016.62 8952.92 1878.42 2269.66 0.00 5961833.52 666727.85 MWD+IFR+MS 10470.00 91.85 258.68 9016.30 8952.60 1876.46 2259.86 0.00 5961831.34 666718.10 MWD+IFR+MS 10480.00 91.85 258.68 9415.97 8952.27 1874.50 2250.06 0.00 5961829.17 666708.34 MWD+IFR+MS 10490.00 91.85 258.68 9015.65 8951.95 1872.54 2240.26 0.00 5961826.99 666698.59 MWD+IFR+MS S err -Sun P Y BP Planning Report Company:. BP Amoco Date: 2/14/2005 Time: 16:19:05 Page:: 7` Field:. Pnulhoe Bay Co-ordioate(NE) Reference: WeIL' G03, True North : Site:. PB C Pad Vertical (TVD) Reference:.. 28.5 + 35.2' 63:7 Well: C-03 Secfion (VS) Reference: Well. (O.OON,O.OOE,34.27Azi) Wellpath: Plan C-036 Survey Calculation Method: Minimum Curvature Db: Qracle Survey MD Incl Azim TVD ft deg deg ft 10500.00 91.85 258.68 9015.33 10510.00 91.85 258.68 9015.01 10520.00 91.85 258.68 9014.69 10530.00 91.85 258.68 9014.36 10540.00 91.85 258.68 9014.04 10550.00 91.85 258.68 9013.72 10560.00 91.85 258.68 9013.40 10570.00 91.85 258.68 9013.07 10580.00 91.85 258.68 9012.75 10590.00 91.85 258.68 9012.43 10600.00 91.85 258.68 9012.11 10610.00 91.85 258.68 9011.79 10620.00 91.85 258.68 9011.46 10630.00 91.85 258.68 9011.14 10640.00 91.85 258.68 9010.82 10650.00 91.85 258.68 9010.50 10660.00 91.65 258.68 9010.18 10670.00 91.85 258.68 9009.85 10680.00 91.85 258.68 9009.53 10680.40 91.85 258.68 9009.52 10690.00 91.69 259.03 9009.22 10700.00 91.53 259.40 9008.94 10710.00 91.36 259.76 9008.69 10720.00 91.20 260.13 9008.47 10730.00 91.03 260.49 9008.27 10740.00 90.87 260.86 9008.10 10750.00 90.71 261.22 9007.97 10760.00 90.54 261.59 9007.86 10770.00 90.38 261.95 9007.78 10780.00 90.22 262.32 9007.72 10790. 00 90 .05 262 .68 9007.70 10793. 20 90 .00 262 .80 9007.70 10800. 00 89 .73 262 .81 9007.72 10802. 49 89 .63 262 .81 9007.73 10810. 00 89 .63 262 .81 9007.78 10820. 00 89 .63 262 .81 9007.84 10830. 00 89 .63 262 .81 9007.91 10840. 00 89 .63 262 .81 9007.97 10850. 00 89 .63 262 .81 9008.04 10860. 00 89 .63 262 .81 9008.10 10870. 00 89 .63 262 .81 9008.17 10880. 00 89 .63 262 .81 9008.23 10890. 00 89 .63 262 .81 9008.30 10900. 00 89 .63 262 .81 9008.36 10910. 00 89 .63 262 .81 9008.43 10920. 00 89 .63 262 .81 9008.49 10930. 00 89 .63 262 .81 9008.56 10940. 00 89 .63 262 .81 9008.62 10950. 00 89 .63 262 .81 9008.69 10960. 00 $9 .63 262 .81 9008.75 10970. 00 89 .63 262 .81 9008.82 10980. 00 89 .63 262 .81 9008.88 10990. 00 89 .63 262 .81 9008.94 Sys TVD fit 8951.63 8951.31 8950.99 8950.66 8950.34 8950.02 8949.70 8949.37 8949.05 8948.73 8948.41 8948.09 8947.76 8947.44 8947.12 8946.80 8946.48 8946.15 8945.83 8945.82 8945.52 8945.24 8944.99 8944.77 8944.57 8944.40 8944.27 8944.16 8944.08 8944.02 8944.00 8944.00 8944.02 8944.03 8944.08 8944.14 8944.21 8944.27 8944.34 8944.40 8944.47 8944.53 8944.60 8944.66 8944.73 8944.79 8944.86 8944.92 8944.99 8945.05 8945.12 8945.18 8945.24 N/S E/W ft " ft 1870.58 2230.46 1868.62 2220.66 1866.65 2210.86 1864.69 2201.06 1862.73 2191.26 1860.77 2181.46 1858.81 2171.66 1856.85 2161.86 1854.88 2152.06 1852.92 2142.26 1850.96 2132.46 1849.00 2122.66 1847.04 2112.86 1845.08 2103.06 1843.12 2093.26 1841.15 2083.46 1839.19 2073.66 1837.23 2063.86 1835.27 2054.05 1835.19 2053.66 1833.34 2044.25 1831.47 2034.43 1829.66 2024.60 1827.91 2014.75 1826.23 2004.90 1824.61 1995.03 1823.05 1985.15 1821.56 1975.27 1820.13 1965.37 1818.76 1955.46 1817.45 1945.55 1817.05 1942.37 1816.20 1935.63 1815.89 1933.16 1814.95 1925.71 1813.70 1915.79 1812.44 1905.87 1811.19 1895.94 1809.94 1886.02 1808.69 1876.10 1807.44 1866.18 1806.19 1856.26 1804.94 1846.34 1803.68 1836.42 1802.43 1826.50 1801.18 1816.57 1799.93 1806.65 1798.68 1796.73 1797.43 1786.81 1796.18 1776.89 1794.92 1766.97 1793.67 1757.05 1792.42 1747.13 DLS MapN de9/100ff ft 0.00 5961824.82 0.00 5961822.64 0.00 5961820.47 0.00 5961818.29 0.00 5961816.12 0.00 5961813.94 0.00 5961811.76 0.00 5961809.59 0.00 5961807.41 0.00 5961805.24 0.00 5961803.06 0.00 5961800.89 0.00 5961798.71 0.00 5961796.54 0.00 5961794.36 0.00 5961792.19 0.00 5961790.01 0.00 5961787.84 0.00 5961785.66 0.00 5961785.57 4.00 5961783.51 4.00 5961781.43 4.00 5961779.41 4.00 5961777.45 4.00 5961775.55 4.00 5961773.71 4.00 5961771.94 4.00 5961770.23 4.00 5961768.58 4.00 5961767.00 4.00 5961765.48 4.00 5961765.00 4.00 5961764.00 4.00 5961763.64 0.00 5961762.53 0.00 5961761.07 0.00 5961759.60 0.00 5961758.13 0.00 5961756.66 0.00 5961755.19 0.00 5961753.73 0.00 5961752.26 0.00 5961750.79 0.00 5961749.32 0.00 5961747,85 0.00 5961746.38 0.00 5961744.92 0.00 5961743.45 0.00 5961741.98 0.00 5961740.51 0.00 5961739.04 0.00 5961737.58 0.00 5961736.11 MapE TooUComme ft 666688.83 MWD+IFR+MS 666679.08 MWD+IFR+MS 666669.32 MWD+IFR+MS 666659.57 MWD+IFR+MS 666649.81 MWD+IFR+MS 666640.06 MWD+IFR+MS 666630.31 MWD+IFR+MS 666620.55 MWD+IFR+MS 666610.80 MWD+IFR+MS 666601.04 MWD+IFR+MS 666591.29 MWD+IFR+MS 666581.53 MWD+IFR+MS 666571.78 MWD+IFR+MS 666562.02 MWD+IFR+MS 666552.27 MWD+IFR+MS 666542.51 MWD+IFR+MS 666532.76 MWD+IFR+MS 666523.01 MWD+IFR+MS 666513.25 MWD+IFR+MS 666512.86 Start Dir 4/100 666503.49 MWD+IFR+MS 666493.71 MWD+IFR+MS 666483.93 MWD+IFR+MS 666474.12 MWD+IFR+MS 666464.31 MWD+IFR+MS 666454.48 MWD+IFR+MS 666444.64 MWD+IFR+MS 666434.79 MWD+IFR+MS 666424.93 MWD+IFR+MS 666415.05 MWD+IFR+MS 666405.17 MWD+IFR+MS 666402.00 C-03B T2 666395.28 MWD+IFR+MS 666392.82 End Dir :1080 666385.39 MWD+IFR+MS 666375.50 MWD+IFR+MS 666365.61 MWD+IFR+MS 666355.72 MWD+IFR+MS 666345.83 MWD+IFR+MS 666335.94 MWD+IFR+MS 666326.04 MWD+IFR+MS 666316.15 MWD+IFR+MS 66630626 MWD+IFR+MS 666296.37 MWD+IFR+MS 666286.48 MWD+IFR+MS 666276.59 MWD+IFR+MS 666266.70 MWD+IFR+MS 666256.81 MWD+IFR+MS 666246.92 MWD+IFR+MS 666237.03 MWD+IFR+MS 666227.14 MWD+IFR+MS 666217.25 MWD+IFR+MS 666207.36 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: BP Amoco Date: .2!14!2005 Time: 16:19:05 Page:... 8 Field: Prudhoe Bay Co-ordinate(NE) Referenced .. Well; C-03, True North Site: PB C Pad Vertical (TVI?) Referenced 28.5 + 35:2 63.7 Well: C-03 Section (VS) Reference: Well (O.OON,t):OOE,34.27Azi) Wellpath: Plan C-036 Survey Calculation Method: . Minimum Curvature Db: Oracle Survey MD Intl Azim TVD Sys TVD N/S E/W DLS MapN MapE" TooUComme t ft deg deg ft ft ft ft deg/100ft ft' < ft 11000.00 89.63 262.81 9009.01 8945.31 1791.17 1737.21 0.00 5961734.64 666197.47 MWD+IFR+MS 11010.00 89.63 262.81 9009.07 8945.37 1789.92 1727.28 0.00 5961733.17 666187.57 MWD+IFR+MS 11020.00 89.63 262.81 9009.14 8945.44 1788.67 1717.36 0.00 5961731.70 666177.68 MWD+IFR+MS 11030.00 89.63 262.81 9009.20 8945.50 1787.42 1707.44 0.00 5961730.24 666167.79 MWD+IFR+MS 11040.00 89.63 262.81 9009.27 8945.57 1786.16 1697.52 0.00 5961728.77 666157.90 MWD+IFR+MS 11050.00 89.63 262.81 9009.33 8945.63 1784.97 1687.60 0.00 5961727.30 666148.01 MWD+IFR+MS 11060.00 89.63 262.81 9009.40 8945.70 1783.66 1677.68 0.00 5961725.83 666138.12 MWD+IFR+MS 11070.00 89.63 262.81 9009.46 8945.76 1782.41 1667.76 0.00 5961724.36 666128.23 MWD+IFR+MS 11080.00 89.63 262.81 9009.53 8945.83 1781.16 1657.84 0.00 5961722.89 666118.34 MWD+fFR+MS 11090.00 89.63 262.81 9009.59 8945.89 1779.91 1647.91 0.00 5961721.43 666108.45 MWD+IFR+MS 11100.00 89.63 262.81 9009.66 8945.96 1778.66 1637.99 0.00 5961719.96 666098.56 MWD+IFR+MS 11110.00 89.63 262.81 9009.72 8946.02 1777.41 1628.07 0.00 5961718.49 666088.67 MWD+IFR+MS 11120.00 89.63 262.81 9009.79 8946.09 1776.15 1618.15 0.00 5961717.02 666078.78 MWD+IFR+MS 11130.00 89.63 262.81 9009.85 8946.15 1774.90 1608.23 0.00 5961715.55 666068.89 MWD+IFR+MS 11140.00 89.63 262.81 9009.92 8946.22 1773.65 1598.31 0.00 5961714.09 666058.99 MWD+IFR+MS 11150.00 89.63 262.81 9009.98 8946.28 1772.40 1588.39 0.00 5961712.62 666049.10 MWD+IFR+MS 11160.00 89.63 262.81 9010.05 8946.35 1771.15 1578.47 0.00 5961711.15 666039.21 MWD+IFR+MS 11170.00 89.63 262.81 9010.11 8946.41 1769.90 1568.55 0.00 5961709.68 666029.32 MWD+IFR+MS 11180.00 89.63 262.81 9010.18 8946.48 1768.65 1558.62 0.00 5961708.21 666019.43 MWD+IFR+MS 11190.00 89.63 262.81 9010.24 8946.54 1767.39 1548.70 0.00 5961706.74 666009.54 MWD+IFR+MS 11200.00 89.63 262.81 9010.31 8946.61 1766.14 1538.78 0.00 5961705.28 665999.65 MWD+IFR+MS 11210.00 89.63 262.81 9010.37 8946.67 1764.89 1528.86 0.00 5961703.81 665989.76 MWD+IFR+MS 11220.00 89.63 262.81 9010.43 8946.73 1763.64 1518.94 0.00 5961702.34 665979.87 MWD+IFR+MS 11230.00 89.63 262.81 9010.50 8946.80 1762.39 1509.02 0.00 5961700.87 665969.98 MWD+IFR+MS 11240.00 89.63 262.81 9010.56 8946.86 1761.14 1499.10 0.00 5961699.40 665960.09 MWD+IFR+MS 11250.00 89.63 262.81 9010.63 8946.93 1759.89 1489.18 0.00 5961697.94 665950.20 MWD+IFR+MS 11260.00 89.63 262.81 9010.69 8946.99 1758.63 1479.25 0.00 5961696.47 665940.31 MWD+IFR+MS 11270.00 89.63 262.81 9010.76 8947.06 1757.38 1469.33 0.00 5961695.00 665930.42 MWD+IFR+MS 11280.00 89.63 262.81 9010.82 8947.12 1756.13 1459.41 0.00 5961693.53 665920.52 MWD+IFR+MS 11290.00 89.63 262.81 9010.89 8947.19 1754.88 1449.49 0.00 5961692.06 665910.63 MWD+IFR+MS 11300.00 89.63 262.81 9010.95 8947.25 1753.63 1439.57 0.00 5961690.60 665900.74 MWD+fFR+MS 11310.00 89.63 262.81 9011.02 8947.32 1752.38 1429.65 0.00 5961689.13 665890.85 MWD+IFR+MS 11320.00 89.63 262.81 9011.08 8947.38 1751.13 1419.73 0.00 5961687.66 665880.96 MWD+IFR+MS 11330.00 89.63 262.81 9011.15 8947.45 .1749.87 1409.81 0.00 5961686.19 665871.07 MWD+IFR+MS 11340.00 89.63 262.81 9011.21 8947.51 1748.62 1399.89 0.00 5961684.72 665861.18 MWD+IFR+MS 11350.00 89.63 262.81 9011.28 8947.58 1747.37 1389.96 0.00 5961683.25 665851.29 MWD+IFR+MS 11360.00 89.63 262.81 9011.34 8947.64 1746.12 1380.04 0.00 5961681.79 665841.40 MWD+IFR+MS 11370.00 89.63 262.81 9011.41 8947.71 1744.87 1370.12 0.00 5961680.32 665831.51 MWD+IFR+MS 11380.00 89.63 262.81 9011.47 8947.77 1743.62 1360.20 0.00 5961678.85 665821.62 MWD+IFR+MS 11390.00 89.63 262.81 9011.54 8947.84 1742.37 1350.28 0.00 5961677.38 665811.73 MWD+IFR+MS 11400.00 89.63 262.81 9011.60 8947.90 1741.12 1340.36 0.00 5961675.91 665801.84 MWD+IFR+MS 11410.00 89.63 262.81 9011.67 8947,97 1739.86 1330.44 0.00 5961674.45 665791.95 MWD+IFR+MS 11420.00 89.63 262.81 9011.73 8948.03 1738.61 1320.52 0.00 5961672.98 665782.05 MWD+IFR+MS 11430.00 89.63 262.81 9011.80 8948.10 1737.36 1310.59 0.00 5961671.51 665772.16 MWD+IFR+MS 11440.00 89.63 262.81 9011.86 8948.16 1736.11 1300.67 0.00 5961670.04 665762.27 MWD+IFR+MS 11450.00 89.63 262.81 9011.92 8948.22 1734.86 1290.75 0.00 5961668.57 665752.38 MWD+IFR+MS 11460.00 89.63 262.81 9011.99 8948.29 1733.61 1280.83 0.00 5961667.10 665742.49 MWD+IFR+MS 11470.00 89.63 262.81 9012.05 8948.35 1732.36 1270.91 0.00 5961665.64 665732.60 MWD+IFR+MS 11480.00 89.63 262.81 9012.12 8948.42 1731.10 1260.99 0.00 5961664.17 665722.71 MWD+IFR+MS 11490.00 89.63 262.81 9012.18 8948.48 1729.85 1251.07 0.00 5961662.70 665712.82 MWD+fFR+MS 11500.00 89.63 262.81 9012.25 8948.55 1728.60 1241.15 0.00 5961661.23 665702.93 MWD+IFR+MS 11510.00 89.63 262.81 9012.31 8948.61 1727.35 1231.23 0.00 5961659.76 665693.04 MWD+IFR+MS S err -Sun P Y BP Planning Report Company: BP Amoco Date: 2/14/2005 ` Time: 16:19:05. Page: 9 Field:. Prudhoe l3ay Co-ordinate(NE) Reference: - We1L' G03, True North Site: PB C Pad Vertical (TVD) leferencea 28.5 + 35.2 63:7 Well: C-03 Section (VS) Reference: Well (O.OON,O.OOE,34.27Azi) Wellpath: Plan C-038 Survey Calculation Method; Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E(W DLS - MapN MapE,- TooUCorome t ft deg deg ft ft ft ft deg/100ft ft ft 11520.00 89.63 262.81 9012.38 8948.68 1726.10 1221.30 0.00 5961658.30 665683.15 MWD+IFR+MS 11530.00 89.63 262.81 9012.44 8948.74 1724.85 1211.38 0.00 5961656.83 665673.26 MWD+IFR+MS 11540.00 89.63 262.81 9012.51 8948.81 1723.60 1201.46 0.00 5961655.36 665663.37 MWD+IFR+MS 11550.00 89.63 262.81 9012.57 8948.87 1722.34 1191.54 0.00 5961653.89 665653.48 MWD+IFR+MS 11560.00 89.63 262.81 9012.64 8948.94 1721.09 1181.62 0.00 5961652.42 665643.58 MWD+IFR+MS 11569.00 89.63 262.81 9012.70 8949.00 1719.97 1172.69 0.00 5961651.10 665634.68 41/2" 11569.69 ~ 89.63 262.81 9012.70 8949.00 1719.88 1172.01 0.00 5961651.00 665634.00 C-036 T3 Name +Nl-S +EI-W C-03 2644.68 2007.75 WELL DETAILS Northing Eaelmg Latitude Longhude 59594116A0 664500.011 70°IT48.37SN 146°40'04.275W Slot OS ANTI-COLLISION SETTINGS Interpolation Method:MD Interval: 25.00 Depth Range From: 8600.00 T0: 115()9.(9 Maximum Range: 1354.12 Reference: Plan: C-038 wp03 COMPANY DETAILS BP Amoco CalcWation Method: Minimum Curvature Emor s stem: ISCwSA scan ~ mad: rm. cylinder Nodn Emar Sutiacr. Elliptical+Casmg Worming Mnnod: Aides BaaM S[1RVEY PROGRAM Depth Fm Depth To Survey/Plan Tool BbOD.O(1 11569.69 Plmmed: C-03B wp03 VIS MWD+IFR+MS WEU.PATH DETAILS 8 I From Colour To MD Plan C-036 0 8500 Parem Wd ~-03 o 75 -------- ssoo 900o eboo.ao Tie re, 'S 3ll. J ~ O 9~~0 950 Ref Dmumg~ 28.5+75.2 63.70ft . _ 9500 ^°^"-° ' 9750 9750 1000 vseatan origjn diem smreag Angle +N/-S +B/-W From ND 3 10000 _-"- 10250 3a.zr D.oo D.DD zgso 10250 10500 ~,,~ 10500 10750 ~ 10750 11000 ,. ~_-------"'"~ 11000 11250 LecEND 0 11250 11500 ~ C-01 (C-0D, Minor Riek ~°° C-0l (C-Oi A) Majoc Risk 11500 11750 , c-0z (c-0z>, Major Risk ~ 11750 12000 .--. c-03 (amt rzoBRRORR30RS 12000 12260 °` `°' G04A (C4NA), Menm Rtck 3U Olz2so 12500 C-04APB1 (C-04APB1), Mayor Riek "°"""' C4)4APB2 (C4WAPB2) Major Riek , k McJOr Risk (C 3 8 12500 12750 -.- C414 -04). Major Rle mmw.m. ~ ~ 12750 13000 -- c-07 (c-07j, Major work ' 3000 13500 ~~ C477 (C-07A), Major Risk --- c-og(c-0e),Ma;o{Risk 500 14000 c-0g (c-0SA), Ma,« ILak C418 (C418APBI), Major Risk 1 00 ~° ~'° ~` ° 14500 ~^ C-08 (Plmtgz c-0sH), Major Risk 5 ~'~ C419 (C-09), Major' Risk ~ C-09 (C-09A). Ma}a Rick C-10 (G1D), klajor Risk ~~ C-t2A (C-!2A), Mayor Risk '^'^""° C-12APB1 (G12APBIk Major Risk s G12 (C-12), Major Risk ~ C-13A (C-17A), M jor Risk *~ C-13 (C-13), Major Risk 13 ^^'» C-14 (C-14). Mayor Risk C-16 (C-16), Major Risk '. : ~^^° C-16 (C-16A). Major Risk '•^° C-16 (C-16APB1). Major Rill: ae~. C-2J (C-23), Maym Risk ' : ~ G23 (C-23A), Major Riek e-v (GnB), hlajar Riek ' G24 (G24), Ma) ILsk O 270 ~ 90 C-20 (C-24A). Ma)«Riek ~ G25 (G25), Major Rrsk C-25 (G25A), Mayor Risk ~"^ C-2S (C 258), Mayor R~ak +~"~ C-25 (Plan C-258). Melor Risk ~ ~~ C-2bA (G26A), Major Rrek k^'=^"'. C-26 (C-26), Major' Risk C-70 (C3D), Major Risk 13 C-34 (C-74), Major Risk . C-35A (C 75A), Major Wsk ~«° C-351C-75), Major Rlsk ~"~ G76A (G36A), M Jm Risk '4 ~^®° C-36AP81 (G36APB7), Major Riek ~~ C-36 (C-36), Major Risk ~~ C•37 (C-I7), Minor 1200 ~ ~ G37 (G37Ak Minor 1/200 5 ~~ r C 77 (C-37AP82), M wr 1/200 W~ C•38 (G38), Major Riak 1- C-39 (Plan kd C-39A), Major Risk "- C-02 (C-02), Mvmr 1200 l '~• Plan C-038 ,..,.„, CA3B wp03 38 240 `'' 120 ~a, 0 c 3 21 5U SECTION DETAILS Sec MD Rc Azi TVD +NI-S +Fl-W DLeg TFace VSec Target 5 1 860D.00 71.79 69.64 7692.82 1682.94 2442.40 0.00 0.00 27fi6.12 2 8620,00 32.08 3 8677.74 29.96 65.14 7709.79 6).76 7759.27 1687.01 2452.16 12.00 -85.00 27!4.98 1699.93 2478.96 4.00 -15798 2800.74 81 4 9410.17 29.96 5 9669 12 15 27 63.36 8394.00 307 73 8640 41 1864.00 2806.00 0.00 00(1 7120.49 1915 77 2838 11 1500 -157 80 3181 35 l ~ 1 f . . 6 97fi365 15.73 . . 30773 8731.62 . . . . 195096 2818.47 ODO D.00 3182.85 7 10265.05 90.00 258.00 9D22.70 1916.74 24(A.71 16.00 •50.74 2969.63 C-03B T1 8 1027735 91.85 258.68 9022.50 1914.25 2A48.67 16.00 20.27 2960.79 ' ° - "' 9 10680.40 91.g5 258.68 9009.62 1835.19 2053.66 0.00 0.00 267).02 10 10797.20 90.00 2E2.80 9007.70 1817.05 194237 4.00 114.11 259436 C-038 T2 11 1D80249 89.63 262.81 9(107.7) 181589 1933.16 4.00 178.29 2589.21 77 T I-C71~LIIjj~`i ~~Y11I11~C7 _7~1'~ ~` '7 ;~/i11~U1Ij ~ I f'1.11-.^l /_~) f ~ (~. c } ~~] VS l.Ll'ltnjl 1(1 Ll't~~l l' k7 C', l'(Jxat,1~1] _q,~ L~~1L/ln] 12 11569.69 89.67 261.81 9012.70 1719.88 1172.01 0,110 0.00 208125 C-036 T3 ttxw Sperry-Sun Anticollision Report (bmpam: BP Arnoco Date: 2/14/2005 7~imc: 17:00:12 Patio 1 ~ field: Prudhoe Bay i Reference Site: PB C Pad C0-ordinate(1l{1 Reference: Well: C-03, Title Nort h I Reference ~~ell: C-03 ~~~crticnl (T1'U) Reference: 28.5 ~ 35.2 63.7 ~ Reference ~Yellpath: Pfan C-03B Db: Oracle GLOBAL SCAN APPLIED: All wellpaths within 200'+ 100/1000 of reference -There are Tllraidi@~is in this f$h3lcipal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 25.00 ft Error Model: ISCWSA Ellipse Depth Range: 8600.00 to 11569.69 ft Scan Method: Trav Cylinder North Maximum Radius: 1354.12 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 2!3/2005 Validated: No Version: 0 Planned From To Survey Toolcode Tool Name ft ft 109.20 8600.00 1 : Camera based gyro muttisho (109.20-102691~t1<.j`(RO-MS Camera based gyro multishot 8600.00 11569.69 Planned: C-03B wp03 V18 MWD+IFR+MS MWD +IFR + Multi Station Casing Points r-- ~1D TVD Diameter f101cSi~~c Name ~ ft ft in in ' -_ -- '- 9391.56 8377.70 7.000 ( 8.500 7" -_---- -- - - - _ - 11569.00 9012.70 4.500 6.125 4 1/2" Summary Offset Wellpath - Reference Offset Ctr-Ctr 10-00 Allowable Site Well Wellpath MD Mll Distance :area lleviation Warning ft ft ft ft ft ~ PB C Pad G01 C-01 V1 Out of range PB C Pad C-01 C-01A V5 Out of range PB C Pad C-02 C-02 V1 Out of range PB C Pad C-03A C-03A V1 8600.00 8600.00 0.01 No Reference Casings PB C Pad C-03 C-03 V1 8600.00 8600.00 0.01 No Reference Casings PB C Pad C-04A C-04A V1 Out of range PB C Pad C-04AP61 C-04APB1 V1 Out of range PB C Pad C-04APB2 C-04AP62 V1 Out of range PB C Pad C-04APB3 C-04AP63 V1 Out of range PB C Pad C-04 C-04 V1 Out of range PB C Pad C-07 C-07 V2 Out of range PB C Pad C-07 C-07A V4 Out of range PB C Pad C-08 C-08 V1 Out of range PB C Pad G08 C-08A V2 Out of range PB C Pad C-08 C-08APB1 V1 Out of range PB C Pad C-08 Plan#2 C-08B VO Plan: Out of range PB C Pad C-09 C-09 V1 Out of range PB C Pad C-09 C-09A V1 Out of range PB C Pad C-10 C-10 V1 Out of range PB C Pad C-12A C-12A V1 Out of range PB C Pad C-12APB1 C-12AP61 V1 Out of range PB C Pad C-12 C-12 V1 Out of range PB C Pad C-13A C-13A V9 8606.79 8850.00 1072.65 808.17 264.48 Pass: Major Risk PB C Pad C-13 C-13 V1 8606.79 8850.00 1072.65 808.17 264.48 Pass: Major Risk PB C Pad C-14 C-14 V2 Out of range PB C Pad C-16 C-16 V4 Out of range PB C Pad C-16 C-16A V5 Out of range PB C Pad C-16 C-16APB1 V5 Out of range PB C Pad C-23 C-23 V3 Out of range PB C Pad C-23 C-23A V1 Out of range PB C Pad C-23 C-236 V8 Out of range PB C Pad C-24 C-24 V8 Out of range PB C Pad C-24 C-24A V7 Out of range PB C Pad C-25 C-25 V2 Out of range PB C Pad C-25 C-25A V2 Out of range PB C Pad C-25 C-256 V2 Out of range PB C Pad C-25 Plan C-25B V1 Plan: C- Out of range PB C Pad C-26A C-26A V 1 Out of range PB C Pad C-26 C-26 V1 Out of range PB C Pad C-30 C-30 V1 Out of range PB C Pad C-34 C-34 V1 11069.95 9675.00 1133.54 441.98 691.56 Pass: Major Risk PB C Pad C-35A C-35A V1 Out of range PB C Pad C-35 C-35 V1 Out of range Sperry-Sun Anticollision Report I Company: BP Amoco Date: 7114I2C05 "time : 17:00:12 Pa};c: ? I Field: Pn~dhoe Bay j Reference S itc_ PB C Pad Cu~irdinat c(\E) Refe rence: Well; C-03, True Nort h I Reference NcII: C-03 ~~crtical (1 ~~D) Kefere ncc 28.5 + 35.2 63.7 ~ 1Zefcrence Wcllpa~b: Plan G038 Db: Oracle ~ Summary ~ ~ ~ ~~ ~ ~ ~ ~ ~ ~ ~----- ~ ---- t) 17sct ylcllpath --- - -~ Reference Offset C.tr-Ctr \u-(:o 111owablc ~ ~ - ~ ~~ ~ ~ Site ~i'ell ~~'rllpath MD AlD Distance area Deviation ~Varnmt; ft ft ft ft ii PB C Pad C-36A C-36A V4 1 1496.22 12000.00 547.32 498.80 48.52 Pass: Major Risk PB C Pad C-36AP61 C-36APB1 V1 Out of range PB C Pad C-36 C-36 V6 Out of range PB C Pad C-37 C-37 V4 1 0003.89 9600.00 289.54 0.00 289.54 Pass: Minor 11200 PB C Pad C-37 C-37A V4 1 0003.89 9600.00 289.54 No Offset Casings PB C Pad C-37 C-37AP61 V1 1 0003.89 9600.00 289.54 No Offset Casings PB C Pad C-37 C-37APB2 V1 1 0003.89 9600.00 289.54 No Offset Casings PB C Pad C-38 C-38 V1 Out of range PB C Pad C-39 Plan #4 C-39A VO Plan: 9798.08 11950.00 1027.79 560.65 467.14 Pass: Major Risk PB C Pad C-42 C-42 V1 1 1493.35 9800.00 436.09 0.00 436.09 Pass: Minor 1/200 Site: PB C Pad Well: C-03A Rule Assigned: NOERRORS Wellpath: C-03A V1 Inter-Site Error: 0.00 ft Refe rence Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD 'PVD kcf Offset TFO+AZI TFO-HS Casing~ HSl)istance Area Deviation y1'arnin~ ft ft ft ft it ft deg deg in ft ft ft 8600.00 7692.81 8600.00 7692.82 133.21 133.18 69.64 0.00 0.01 FAIL 8624.98 7714.01 8625.00 7714.06 134.03 134.42 163.11 98.12 0.67 No Reference Casings 8649.94 7735.31 8650.00 7735.29 134.11 135.20 153.15 88.91 1.95 No Reference Casings 8674.86 7756.78 8675.00 7756.49 134.19 135.97 144.21 80.75 3.56 No Reference Casings 8699.78 7778.37 8700.00 7777,67 134.20 136.67 138.50 75.14 5.45 No Reference Casings 8724.69 7799.95 8725.00 7798.81 134.20 137.38 135.61 72.26 7.48 No Reference Casings 8749.60 7821.53 8750.00 7819.91 134.20 138.09 133.68 70.32 9.63 No Reference Casings 8774.49 7843.10 8775.00 7840.96 134.20 138.80 132.22 68.87 11.89 No Reference Casings 8799.38 7864.66 8800.00 7861.95 134.21 139.51 131.05 67.70 14.28 No Reference Casings 8824.25 7886.20 8825.00 7882.89 134.21 140.24 130.05 66.69 16.79 No Reference Casings 8849.11 7907.74 8850.00 7903.76 134.21 140.98 129.09 65.74 19.40 No Reference Casings 8873.96 7929.27 8875.00 7924.57 134.21 141.72 128.18 64.82 22.13 No Reference Casings 8898.80 7950.79 8900.00 7945.31 134.21 142.46 127.30 63.95 24.97 No Reference Casings 8923.62 7972.30 8925.00 7966.01 134.21 143.20 126.54 63.18 27.90 No Reference Casings 8948.44 7993.80 8950.00 7986.73 134.21 143.95 126.08 62.72 30.87 No Reference Casings 8973.26 8015.30 8975.00 8007.50 134.21 144.70 125.87 62.52 33.87 No Reference Casings 8998.08 8036.80 9000.00 8028.29 134.21 145.45 125.86 62.50 36.90 No Reference Casings 9022.89 8058.30 9025.00 8049.13 134.21 146.18 125.99 62.63 39.94 No Reference Casings 9047.71 8079.80 9050.00 8070.03 134.21 146.90 126.27 62.91 42.95 No Reference Casings 9072.53 8101.30 9075.00 8091.00 134.21 147.63 126.66 63.30 45.93 No Reference Casings 9097.35 8122.81 9100.00 8112.03 134.21 148.36 127.15 63.79 48.88 No Reference Casings 9122.19 8144.32 9125.00 8133.12 134.21 149.07 127.65 64.29 51.72 No Reference Casings 9147.06 8165.88 9150.00 8154.26 134.21 149.79 127.92 64.57 54.17 No Reference Casings 9171.98 8187.47 9175.00 8175.44 134.21 150.50 127.99 64.63 56.19 No Reference Casings 9196.93 8209.08 9200.00 8196.66 134.22 151.21 127.86 64.50 57.78 No Reference Casings 9221.89 8230.71 9225.00 8217.91 134.22 151.91 127.68 64.32 59.12 No Reference Casings 9246.83 8252.31 9250.00 8239.22 134.22 152.61 127.84 64.48 60.84 No Reference Casings 9271.73 8273.89 9275.00 8260.59 134.22 153.30 128.35 64.99 62.99 No Reference Casings 9296.58 8295.41 9300.00 8281.99 134.22 153.99 129.17 65.81 65.59 No Reference Casings 9321.37 8316.89 9325.00 8303.43 134.22 154.67 130.21 66.85 68.58 No Reference Casings 9346.14 8338.35 9350.00 8324.91 134.22 155.33 131.30 67,95 71.68 No Reference Casings 9370.89 8359.80 9375.00 8346.44 134.22 155.99 132.43 69.08 74.88 No Reference Casings 9395.63 8381.22 9400.00 8368.02 134.23 156.65 133.59 70.23 78.18 No Reference Casings 9419.12 8401.62 9425.00 8389.63 134.30 157.34 134.55 72.22 81.65 No Reference Casings 9440.68 8420.79 9450.00 8411.28 134.42 158.03 134.67 75.26 85.83 No Reference Casings 9461.97 8440.18 9475.00 8432.96 134.44 158.62 134.12 78.26 90.86 No Reference Casings 9482.87 8459.61 9500.00 8454.67 134.39 159.12 133.02 81.53 96.72 No Reference Casings 9503.28 8478.90 9525.00 8476.41 134.25 159.53 131.50 85.48 103.42 No Reference Casings • C TERRfE L NUBBLE as-s,rz5z 229 BP EXPLORATION AK INC "Mastercard Check." +zt ~ f.~c. PO BOX 196612 MB 7-5 `1.W ANCHORAGE, AK 99519-6612 cArE ~~ PAY TO THE ~ ~ ~ 1 U~ OAOER_OF First National ank Alaska Anchorage, AK 99501 MEMO ~/ O~ ~:~25200~60~:9914~~~622?~~~L556~~' 0229 a • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME `'D PTD# ~~ '~~ CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) it is for a new wellbore segment of Th MULTI e perm LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of .the original API number stated i i are between 60-69) above. ~ PILOT HOLE In accordance with 20 AAC 25.005(f), all (per records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PIT) ~ and API number (50 - 70/SO) from records, data and togs acquired for well (name on permit). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to i ent contin t i /i f g s . ec n perforate and produce upon issuance of a conservation order j, approving a spacing exception. (Comuany Name) assumes the liability of any protest to the spacing exception that may occur. the d t i DRY DITCH ~ tte o All dry ditch sample sets subm SAMPLE Commission must be in no greater than 30' f sample intervals from below the permafrost i, or from where samples are first caught and i 10' sample intervals through target zones. Rev: 04/01/05 C\ J o d y\tra ns m itta t_c hec k l ist WELL PERMIT CHECKL]ST Field & Pool PRUDHOE BAY, PRUDHOE OIL -640150 _~Well Name: PRUDHOE BAY UNIT C-03B Program DEV _ Well bore seg ^ PTD#:2051580 Company BP EXPLORATION tALASKAI INC Initial Classltype DEV / 1-OIL GeoArea 890 Unit 1 65~_ On/Off Shore ~__ Annular Disposal ^ Administration 1 Permit_feeattached,____________________ Yes._-____-.._ 2 Lease number appropriate_____ _----------------__ ---Yes.________, 3 Uniquewell_nameandnumber-._-__--____-,------------------- --Yes.--------------------------_-__-, 4 Well locatedina_defned_pool. _-_--_______-_. ____-_- __Yes-_- -_-___ 5 Well located proper di_skance from drilling unikboundary_ _ _ _ - _ - _ _ _ - _ _ _ _ _ . _ - _ Yes _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 Well located proper distance from other wells_ _ Yes _ - _ . 7 Sufficient acreage_ayailablein_drillingunit__-_________ _______________ ___Yes,___-_-________.__,_-_-___.__,_ 8 Ifdeviated,is_wellboreplat_inc_luded________________ _____________ ___Yes__-_-_,._, -_-______ 9 Ope[atot only affected pady - - - - Yes - - 10 Operator has-appropriate_bondinforce_______________________-.._- _--Yes_____-.,-__._.________, __-__- 11 Pe(mit_can be issued without conservation order_ _ _ - - _ . _ . _ Yes - Appr Date 12 Permit c_an be issued without administrative_approval Yes - - - - - - - - - - - - - - - - - - - RPC 10!25/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorizedbylnjeotionOrder#(puk1O#in-comments)-(For-NA____________ ___ ___________ _____________ ______________ ______ ___ _______ 15 All wells within 114_mile area of review identified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ - - _ - - - - - - - - - . - - _ _ - 16 Pre-produced injector duratio_n_of pre production less than- 3 months_ (FQr service well only) - NA - _ . _ i 1 7 ACMP-Finding of Consistency_has been issued_for_this project_ - _ _ - .. _ NA_ _ _ - _ _ Engineering 18 Canductorstring.provided NA 19 SurfacecasingprotectsalLknpwnUSDWs.__-_-__ -------------- --- ---NA___-__ _._ 20 CMT_vol_adeguate-to circulate_on conductor& surf_csg . NA_ _ _ _ - 21 CMT_v~l adequate_to tie-in long string to surf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ _ _ NA_ - _ - _ _ _ . _ . _ - . _ . 22 GMT-willcover_all know_n.productivehorizons___-________________ __ ._-Yes_-___,_Adequate excess,__,-__-___ __-____-.-_-___-_-_____._-_-__,-_-___._-_-_ 23 Casing designs adequate forG,TB&-permafrost_----------------- Yes-----.-------.-----------.------------.---------. ------------- 24 Adequatetankage_orreservepit__ _-_ ___________________---__, -_-Yes___ _Nabors-2ES,_____ 25 If a_re-drill, has_a 10-403 for abandonment been approved - _ Yes - 1QI14/2005. - - - - 26 Adequatewellboreseparationproposed----------------------_..-.-. -.-Yes_____.-____- 27 If diverterlequired,doesitmeetregulations_____ ________________.._-_ ._. NA-__,__..Sidetrack.____-____-_-__-______ Appr Date 28 Drillingfluid_programschematic&equiplistadequate___________________ __ ___ Yes_-___..MaxNIW10,2_ppg.__- _._.-.____._-_ -__-___---____-_-____.__-_ _-_ WGA 10126f2005 29 BOPEs,-dolheymeet_regu_lotion__._-__-_____.-__-..__-__._-_. _.Yes__._ _-_-_-,.__-___.___._-___-____-_-__.-_____-_____-_-.-_______-_- 30 BOPE-press rating appropriate; test to-(put psig in comments)_ . Yes - - _ - _ Test to 3500 psi. -MSP 2350 psi.- _ _ _ - _ _ _ _ - 31 Choke_manifpldcomplieswlAPl_RP-53 (May84)_________ _______________ ___Yes____-__-_-_.,_ 32 Work will occur without operation shutdown_ Yes - - - . 33 Ispresence_ofH2Sgas_probable- ----------------_. -_-___---- __-Yes__-__DesignatedH2S pad:____,____-_-_-_,_____-___-_-._,_._-____.__,. 34 Mechanical condition of wells withinAORuerified(For_se[vicewellonly)___________ ___NA_-___-___ __--__-.__.__- -_,__-__-___-__._--__ _____-__._____-___ ___ Geology 35 Pe[mitcanbeissuedwlohydrogen.sulfidemeasures__ ___________________ ___No_____-_-_.__-.-_-____-_-_.-_.__-_____-___--___._ 36 Data-presented on potential overpressure zones _ _ _ - _ _ _ - _ _ , _ _ . _ _ - _ - _ _ NA_ - _ _ _ - _ _ . _ _ Appr Date 37 Seismic_analysis_ofshallow gas_zones- .. _ _ - . _ _ _ _ _ _ - _ _ _ _ _ - NA_ - _ - _ _ _ - _ - _ _ , _ - RPC 1012512005 38 Seabed cgndibon survey (ifoff-shore) - . _ _ _ _ - _ NA_ _ . _ 39 Contact name/phone}or weekly progress reports [exploratory only]_ NA_ Geologic Engineering blic Commissioner: Date: Commissioner//: Date o issi r Date • • • ,~aos-isa Pages in the appendix have not been microfilmed. • 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 Nistory file and to simplify finding information, iniormalion 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. ~~~ MAC ~ 200 C-036.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ wed Feb 06 15:00:54 2008 Reel Header Service name .............LISTPE Date . ...................08/02/06 Ori 9in ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Previous Reel Name.......UNKNOWN Comments...... .........STS LIS Writing Tape Header Service name .............LISTPE Date . ...................08/02/06 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Library. scientific Technical Services Physical EOF ~~~~ M~~ ~ ~ ~~~$ Comment Record TAPE HEADER Prudhoe Bay MWD/MAD LOGS WELL NAME: C-03B API NUMBER: 500292012402 OPERATOR: BPXA LOGGING COMPANY: Sperry Sun TAPE CREATION DATE: 06-FEB-08 JOB DATA MWD RUN 2 MWD RUN 3 JOB NUMBER: MW-000403088 MW-000403088 LOGGING ENGINEER: S. BLAJSZCZA A. SHANAHAN OPERATOR WITNESS: J. RALL J. RALL MAD RUN 4 JOB NUMBER: MW-000403088 LOGGING ENGINEER: A. SHANAHAN OPERATOR WITNESS: J. RALL SURFACE LOCATION SECTION: 19 TOWNSHIP: 11N RANGE: 14E FNL: 1316 FSL: FEL: 879 FWL: Page 1 ~C3J-lS`6 ~lJ~loLl MWD RUN 4 Mw-000403088 A. SHANAHAN J. RALL d ~ C-036.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: .00 DERRICK FLOOR: 63.66 GROUND LEVEL: 35.16 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8218.0 2ND STRING 6.125 7.000 9410.0 3RD STRING 6.125 7.000 9410.0 PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS TO ORIENT WHIPSTOCK AND MILL WINDOW. NO LWD DATA WERE ACQUIRED. TOP OF WHIPSTOCK IS AT 8202'MD 7342'TVD, AND BOTTOM OF WHIPSTOCK IS AT 8218'MD/7356'TVD. 4. MWD RUNS 2 & 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4), AND DRILLING DYNAMICS SENSOR (DDS). THE SHALLOW SPACING RELIEVER OF THE EWR TOOL FAILED ON MWD RUN 3 AND THAT SPACING'S DATA IS UNAVAILABLE. 5. MWD RUN 4 IS DIRECTIONAL WITH DGR, EWR-4, COMPENSATED THERMAL NEUTRON POROSITY (CTN), AND AZIMUTHAL LITHO- DENSITY (ALD). POROSITY DATA IN THE INTERVAL 9802'MD/ 8738'TVD TO 10283'MD/9014'TVD WAS ACQUIRED ON A MEASURE- MENT AFTER DRILLING (MAD) PASS WHILE RUNNING IN THE HOLE FOR MWD RUN 4. A MAD PASS WAS ALSO PERFORMED OVER THE INTERVAL 10821'MD/9012'TVD UP TO 10398'MD/9021'TVD FOR DETECTING INVASION ZONES VIA THE EWR TOOL. THAT DATA IS PRESENTED ON A SEPARATE LOG TAIL. 6. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED VIA THE E-MAIL FROM DOUG DORTCH OF SAIL ON BEHALF OF DOUG STONER, GEOLOGIST FOR BP EXPLORATION ALASKA, INC. DATED 11-NOV-07. MWD DATA IS CONSIDERED PDC. Page 2 ~!, ~ C-036.tapx MWD RUNS 2-4 REPRESENT WELL C-03B WITH API#: 50-029-20124-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11635'MD/8996'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SRAT = SMOOTHED RUNNING SPEED WHILE NOT DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX). SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . CURVES WITH THE LABEL "M" SUFFIX DENOTE MAD PASS DATA. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4-8.5 PPG MUD SALINITY: 2500 - 5000 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8196.0 11583.5 RPX 8202.5 11590.5 RPS 8202.5 11590.5 RPM 8202.5 11590.5 RPD 8202.5 11590.5 ROP 8202.5 11635.5 FET 8202.5 11590.5 Page 3 C-036.tapx FCNT 9802.0 11555.5 NPHI 9802.0 11555.5 NCNT 9802.0 11555.5 RHOB 9818.0 11572.5 DRHO 9818.0 11572.5 PEF 9818.0 11572.5 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 $196.0 9410.0 MwD 3 9410.0 10367.0 MWD 4 9760.5 11635.5 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............Undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999.25 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 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 8196 11635.5 9915.75 6880 8196 11635.5 ROP MWD FT/H 0.25 210.47 83.1028 6867 8202.5 11635.5 GR MWD API 13.41 561.39 91.2692 6776 8196 11583.5 RPX MWD OHMM 0.33 1746.82 19.2719 6718 8202.5 11590.5 RPS MWD OHMM 0.67 32.48 9.4711 4870 8202.5 11590.5 RPM MWD OHMM 0.33 2000 28.7176 6718 8202.5 11590.5 RPD MWD OHMM 0.26 2000 30.1909 6718 8202.5 11590.5 Page 4 C-03B.tapx FET MWD HOUR 0.25 47.79 1.83122 6718 8202.5 11590.5 NPHI MWD PU-S 14.9 35.61 25.1306 3508 9802 11555.5 FCNT MWD CNTS 8.39 1117.55 186.132 3508 9802 11555.5 NCNT MWD CNTS 617.6 35006.2 8380.66 3508 9802 11555.5 RHOB MWD G/CM 2.106 2.912 2.36134 3510 9818 11572.5 DRHO MWD G/CM -0.108 0.501 0.0483484 3510 9818 11572.5 PEF MWD BARN 0.64 6.09 2.07524 3510 9818 11572.5 First Reading For Entire File..........8196 Last Reading For Entire File...........11635.5 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.001 Comment Record FILE HEADER FILE NUMBER: 2 EDITED MERGED MAD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPD RPM RPX RPS RAT MERGED DATA PBU TOOL MWD REMARKS: MERGED MAD PASS. Data Format Specification Record Data Record Type ..................0 SOURCE CODE clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH 9760.5 9766.0 9766.0 9766.0 9767.0 9767.0 9811.5 STOP DEPTH 10810.5 10821.0 10821.0 10821.0 10821.0 10821.0 10862.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 4 1 9760.5 10862.0 Page 5 C-036.tapx Data specification Block Type..... 0 Logging Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999.25 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 RAT MAD FT/H 4 1 68 4 2 GR MAD API 4 1 68 8 3 RPX MAD OHMM 4 1 68 12 4 RPS MAD OHMM 4 1 68 16 5 RPM MAD OHMM 4 1 68 20 6 RPD MAD OHMM 4 1 68 24 7 FET MAD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9760.5 10862 10311.3 2204 9760.5 10862 RAT MAD FT/H 0.34 2897.97 335.441 1930 9811.5 10862 GR MAD API 10.72 221.48 43.5638 1947 9760.5 10810.5 RPX MAD OHMM 7.77 57.39 19.1886 1953 9767 10821 RPS MAD OHMM 8.5 92.2 22.2135 1953 9767 10821 RPM MAD OHMM 9.32 156.76 29.0274 1956 9766 10821 RPD MAD OHMM 9.9 166.87 30.7496 1956 9766 10821 FET MAD HOUR 18.0298 33.676 26.8015 1956 9766 10821 First Reading For Entire File..........9760.5 Last Reading For Entire File...........10862 File Trailer service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type ................L0 Next File Name...........sTSLIB.003 Physical EOF File Header service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.002 Comment Record FILE HEADER FILE NUMBER: Page 6 • C-03B.tapx RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8196.0 9374.0 RPD 8202.5 9370.0 FET $202.5 9370.0 RPM 8202.5 9370.0 RPS 8202.5 9370.0 RPX 8202.5 9370.0 ROP 8231.5 9410.0 LOG HEADER DATA DATE LOGGED: 06-Nov-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 9410.0 TOP LOG INTERVAL (FT): 8196.0 BOTTOM LOG INTERVAL (FT): 9410.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 31.0 MAXIMUM ANGLE: 33.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8218.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 10.20 MUD VISCOSITY (S): 64.0 MUD PH: 9.6 MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .460 90.0 MUD AT MAX CIRCULATING TERMPERATURE: .300 141.8 MUD FILTRATE AT MT: 1.380 70.0 MUD CAKE AT MT: .740 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 7 C-03B.tapx Data Format specification Record Data Record Type... .......... 0 Data Specification Block Type..... 0 Logging Direction ................. DOwn optical log depth units........... Feet Data Reference Point .............. Undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. Undefined Absent value ...................... -999.25 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 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 8196 9410 8803 2429 8196 9410 ROP MWD020 FT/H 10.045 209.26 86.2338 2358 8231.5 9410 GR MWD020 API 72.08 399.58 158.112 2357 8196 9374 RPX MWD020 OHMM 0.69 8.28 1.971 2336 8202.5 9370 RPS MWD020 OHMM 0.67 7.4 1.94 2336 8202.5 9370 RPM MwD020 OHMM 0.62 6.9 1.94485 2336 8202.5 9370 RPD MwD020 OHMM 0.58 360.02 2.23101 2336 8202.5 9370 FET MWD020 HOUR 0.43 44.26 1.87975 2336 8202.5 9370 First Reading For Entire File..........8196 Last Reading For Entire File...........9410 File Trailer Service name... .......STSLIB.003 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type ................Lo Next File Name...........ST5LI6.004 Physical EOF File Header Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......sT5LI6.003 Page 8 • • c-03B.tapx comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9374.5 10316.0 FET 9400.0 10323.5 RPD 9400.0 10323.5 RPX 9400.0 10323.5 RPM 9400.0 10323.5 ROP 9410.5 10367.0 LOG HEADER DATA DATE LOGGED: 09-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 6.02 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10367.0 TOP LOG INTERVAL (FT): 9410.0 BOTTOM LOG INTERVAL (FT): 10367.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 7.9 MAXIMUM ANGLE: 85.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 1 EWR4 ELECTROMAG. RESIS. 4 90518 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 9410.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) 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): Page 9 Polymer 8.40 47.0 10.0 6000 .0 1.100 68.0 .490 161.0 1.050 68.0 1.250 68.0 • C-036.tapx REMARKS: Data Format specification Record ', Data Record Type... ..... ... .0 Data specification Block Type ... ',.0 Logging Direction ............ ... '.Down optical log depth units...... ... '..Feet Data Reference Point ......... ....'.undefined Frame spacing....... ....... ... '. 60 .lIN Max frames per record........ ... !,.undefined Absent value ................. ......-999.25 Depth units. .. .. ... ', Datum specification Block sub -type...0 Name service order units size N sam Rep Code offset Channel DEPT FT 4 1 168 0 1 ROP MWD030 FT/H 4 1 '', 68 4 2 GR MwD030 API 4 1 168 8 3 RPx MWD030 oHMM 4 1 ''68 12 4 RPM MWD030 OHMM 4 1 ', 68 16 5 RPD MWD030 OHMM 4 1 '68 20 6 FET MWD030 HOUR 4 1 '68 24 7 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 9374.5 1Q367 9870.75 1986 9374.5 10367 ROP MWD030 FT/H 0.25 19.14 52.8649 1914 9410.5 10367 GR MWD030 API 13.41 56.39 52.3225 1884 9374.5 10316 RPx MWD030 OHMM 0.33 174(.82 46.0301 1848 9400 10323.5 RPM MWD030 OHMM 0.33 2000 78.368 1848 9400 10323.5 RPD MWD030 OHMM 0.26 2000 84.1368 1848 9400 10323.5 FET MWD030 HOUR 0.78 47.79 2.03704 1848 9400 10323.5 First Reading For Entire File.......'. ..9374.5 Last Reading For Entire File........'. ..10367 File Trailer Service name... .......STSLIB.004 service Sub Level Name... version Number. ........1.0.0 '' Date of Generation.......OS/02/06', Maximum Physical Record..65535 File TyE~e ................L0 Next File Name...........STSLIB.005 Physical EOF File Header ' Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06', Maximum Physical Record..65535 File Type. ............LO previous File Name.......sTSLi6.004 ' Page 10 • • 'C-03B.tapx comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for ea',ch bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 9802.0 11555.5 FCNT 9802.0 11555.5 NPHI 9802.0 11555.5 PEF 9818.0 ' 11572.5 DRHO 9818.0 11572.5 RHOB 9818.0 ' 11572.5 GR 10316.5 ' 11583.5 FET 10324.0 11590.5 RPD 10324.0 11590.5 RPM 10324.0 ' 11590.5 RP5 10324.0 ' 11590.5 RPX 10324.0 ' 11590.5 ROP 10367.5 ' 11635.5 LOG HEADER DATA DATE LOGGED: 11-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: ', 6.02 DATA TYPE (MEMORY OR REAL-TIME): ' Memory TD DRILLER (FT): ' 11635.0 TOP LOG INTERVAL (FT): 9760.0 BOTTOM LOG INTERVAL (FT): 11635.0 BIT ROTATING SPEED (RPM): ', HOLE INCLINATION (DEG ' MINIMUM ANGLE: 88.2 MAXIMUM ANGLE: 94.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE ' TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL'NEUTRON 1844674407370955 EWR4 ELECTROMAG. RESIS. 4 159436 ALD AZIMUTHAL LI7H0-DEN 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): ', 6.125 DRILLER'S CASING DEPTH (FT): 9410.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): ' 8.45 MUD VISCOSITY (S): 48.0 MUD PH: 9.2 MUD CHLORIDES (PPM): 2500 FLUID LOSS (C3): ' .O RESISTIVITY (OHMM) AT TEMPERATWRE (DEG F) MUD AT MEASURED TEMPERATURE'(MT): 1.070 80.0 MUD AT MAX CIRCULATING TERMPERATURE: .508 176.0 MUD FILTRATE AT MT: .890 68.0 MUD CAKE AT MT: 1.100 68.0 ' Page 11 • • C-036.tapx NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Da ta Format specification Record Data Record Type... .......... 0 Data Specification clock Type..... 0 Loggin Direction ................. DOwn Optical log depth units........... Feet Data Reference Point .............. undefined Frame Spacing....... ............ 60 .lIN Max frames per record ............. undefined Absent value ...................... -999.25 Depth units. .. .. ..... Datum specification Block sub-type ...0 Name Service order units size Nsam Rep code offset channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MwD040 Pu-s 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9802 11635.5 10718.8 3668 9802 11635.5 ROP MWD040 FT/H 0.52 210.47 104,586 2537 10367.5 11635.5 GR MWD040 API 20.79 171.37 58.0644 2535 10316.5 11583.5 RPX MWD040 OHMM 7.42 31.23 15.7066 2534 10324 11590.5 RPS MWD040 OHMM 8.35 32.48 16.4137 2534 10324 11590.5 RPM MWD040 OHMM 9.14 35.36 17.1892 2534 10324 11590.5 RPD MWD040 OHMM 10.2 28.4 16.6242 2534 10324 11590.5 FET MWD040 HOUR 0.25 20.83 1.63637 2534 10324 11590.5 NPHI MWD040 Pu-s 14.9 35.61 25.1306 3508 9802 11555.5 FONT MwD040 CNTS 8.39 1117.55 186.132 3508 9802 11555.5 NCNT MWD040 CNTS 617.6 35006.2 8380.66 3508 9802 11555.5 RHOB MWD040 G/CM 2.106 2.912 2.36134 3510 9818 11572.5 DRHO MWD040 G/CM -0.108 0.501 0.0483484 3510 9818 11572.5 PEF MwD040 BARN 0.64 6.09 2.07524 3510 9818 11572.5 First Reading For Entire File..........9802 Last Reading For Entire File...........11635 Page 12 • • C-036.tapx File Trailer Service name... .......STSLIB.005 service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MAD Curves and log header data DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY for each pass of each run in separate files. VENDOR TOOL CODE START DEPTH GR 9760.5 FET 9766.0 RPD 9766.0 RPM 9766.0 RPS 9767.0 RPX 9767.0 RAT 9811.5 LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN ALD EWR4 STOP DEPTH 10810.5 10821.0 10821.0 10821.0 10821.0 10821.0 10862.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON AZIMUTHAL LITHO-DEN E:LECTROMAG. RESIS. 4 Page 13 11-NOV-05 Insite 6.02 Memory 11635.0 9760.0 10862.0 88.2 94.1 TOOL NUMBER 203301 1844674407370955 1050894 159436 • C-036.tapx $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT ): 9410.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.45 MUD VISCOSITY (S): 48.0 MUD PH: 9,2 MUD CHLORIDES (PPM): 2500 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMP ERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.070 80.0 MUD AT MAX CIRCULATING TERMPERATURE: .508 176.0 MUD FILTRATE AT MT: .890 68.0 MUD CAKE AT MT: 1.100 68.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..... .....0 Data Specification Block Type .....0 Logging Direction ............ .....DOwn optical log depth units...... .....Feet Data Reference Point ......... .....undefined Frame Spacing....... ....... .....60 .lIN Max frames per record ........ .....undefined Absent value ................. .....-999.25 Depth units. .. .. .. ..... Datum Specification Block sub -type...0 Name service order units size N sam Rep code offset channel DEPT FT 4 1 68 0 1 RAT MAD041 FT/H 4 1 68 4 2 GR MAD041 API 4 1 68 8 3 RPx MAD041 OHMM 4 1 68 12 4 RPS MAD041 OHMM 4 1 68 16 5 RPM MAD041 OHMM 4 1 68 20 6 RPD MAD041 OHMM 4 1 68 24 7 FET MAD041 HOUR 4 1 68 28 8 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 9760.5 10862 10311.3 2204 9760.5 10862 RAT MAD041 FT/H 0.34 2897.97 335.441 1930 9811.5 10862 GR MAD041 API 10.72 221.48 43.5638 1947 9760.5 10810.5 RPx MAD041 OHMM 7.77 57.39 19.1886 1953 9767 10821 RPS MAD041 OHMM 8.5 92.2 22.2135 1953 9767 10821 RPM MAD041 OHMM 9.32 156.76 29.0274 1956 9766 10821 RPD MAD041 OHMM 9.9 166.87 30.7496 1956 9766 10821 Page 14 • C-036.tapx FET MAD041 HOUR 18.0298 33.676 26.8015 1956 First Reading For Entire File..........9760.5 Last Reading For Entire File...........10862 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number.. ........1.0.0 Date of Generation.......08/02/06 Maximum Physical Record..65535 File TyE~e ................LO Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/06 Origin ...................STs Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS writing Library. Reel Trailer Service name .............LISTPE Date . ...................08/02/06 Origin ...................STS Reel Name. .... ........UNKNOWN Continuation Number......01 Next Reel Name...........UNKNOWN Comments .................STS LIS writing Library. Physical EOF Physical EOF End Of LIS File 9766 10821 scientific Technical services scientific Technical services Page 15
