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202-094
Imag( )roject Well History File Cover f .~e 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. J Q d.. - 0 ~ L}well History File Identifier Organizing (do"\~) RE~N ~ Color items: ;¡ Grayscale items: 0 Poor Quality Originals: 0 Two-Sided DI<;?" AL DATA ~ Diskettes, No. 0 Other, Norrype 0 Other: NOTES: BY: BEVERLY ROBIN VINCENT SHERY~ WINDY Project Proofing BY: BEVERLY ROBIN VINCENT SHERYL~'NDY Scanning Preparation / x 30 = 'i~() BY: BEVERLY ROBIN VINCENT SHERYL ÐINDY ~scan Needed OVERSIZED (Scannable) f 0 Maps: Other items scannable by large scanner 0 OVERSIZED (Non-Scannable) 0 Logs of various kinds 0 Other DATEfP 2Pjd/-/sl WfP ¿ , ¡ DATE: b Ô~ tI1f/ vYt () j + d- = TOTAL PAG~;1' ?S_~ éJ--1[ j DATE: f.o <30Dq./ VI ~ '""< '\J I Production Scanning f~ . - . Q ., J Stage 1 PAGE COUNTFROM SCANNED FILE: ,"3~ L.cf1J-'!Jl./ r~ ~ PAGE COUNT MATCHES NUMBERIN SC, ANNING PREPARATION: " -.0, . YES - NO BY: BEVERLY ROBIN VINCENT SHERYL6)vINDY DATE:g ;}....10L t1 Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: - YES - NO BY: BEVERL Y ROBIN VINCENT SHERYL MARIA WINDY (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (il1('Í\,idl~;;1 P-~(j"" [.',1'~~(:¡,11 ,~frMri()I .l.<,(;,)t f)illrll:O/ppll~iad) RESCANNED B)'-: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY General Notes or Comments about this file: DATE: /sl DATE: /Sl Quality Checked idnlW\ 12/1 OI02Rev3NOTScanned. wpd RECEIVED AUG 2 9 2012 • STATE OF ALASKA 0 ALASKA OIL AND GAS CONSERVATION COMMISSION Ack 9LL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. 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. 8/2/2012 202 - 094 312 - 171 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 5/10/2002 50 029 - 20366 - 01 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 5/12/2002 PBU C -09A 885' FNL, 1223' FEL, Sec. 19, T11 N, R14E, UM 8. KB (ft above MSL): 62.50' 15. Field / Pool(s): Top of Productive Horizon: 3696' FNL, 480' FEL, Sec. 19, T11 N, R14E, UM GL (ft above MSL): 32.58' Prudhoe Bay / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): 4244' FNL, 1060' FEL, Sec. 19, T11 N, R14E, UM 10520' 9045' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 664145 y - 5960329 Zone ASP4 10560' 9042' ADL 028305 TPI: x 664960 y - 5957535 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x 664393 Y - 5956975 Zone ASP4 None 18. Directional Survey ❑ Yes ►'_ No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, GR, RES, MCNL, CCL 9595' 8905' 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" x 30" Insulated Conductor Surface 110' Surface 110' 36" 12.9 cu yds Permafrost Concrete 13 -3/8" 72# L -80 Surface 2660' Surface 2660' 17 -1/2" / 4147 cu ft Arctic Set II 9 -5/8" 47# L -80 Surface 9007' _Surface 8357' 12 -1/4" 1227 cu ft Class 'G', 130 cu ft Arctic Set 7" 29# L -80 8487' 9595' 7873' 8905' 8 -1/2" 396 cu ft Class 'G' 3 - 3/16" x 2 - 7/8" 6.2# / 6.16# L -80 9355' 10560' 8680' 9042' 3 -3/4" 79 cu ft Class 'G' 982' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open S DEPTH SET (MD +TVD of Top & Bottom; Perforation Size and Number): S IZE (MD) PACKER SET ( MD / TVD) 7 ", 26 #, L -80 8429' MD TVD MD TVD 4 -1/2 ", 12.6#, L -80 8461' 8429' / 7819' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9456' HES CIBP 9310' Set Whipstock 'i i t) AIjG e 0 Z.°lc- 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 0 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 R8DMS AUG 3 0 2012 r� 30 , z- Form 10 -407 Revised 12/2009 CO TINUED ON REVERSE , Submit Original Only - 29. GEOLOGIC MARKERS ( List all formations an arkers encountered): 30. FORMATION TESTS NAME TVD Well Tested. Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 2A 9720' 8998' None 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 th- . -going is nd correct to the best of my knowledge. ��cc,,, // Signed: Joe Lastufk: ) . a/ �— Title: Drilling Technologist Date: ; v, g,/ /2--' PBU C - 09A 202 - 094 312 - 171 Prepared By Name/Number: Joe Lastufka, 564 -4091 Well Number Permit No. /Approval No. Drilling Engineer: Matt Ross, 564 -5782 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 -09A, Well History (Pre Rig Sidetrack) Date Summary 05/18/12 DRIFT TUBING W/ 3 -1/2' DUMMY WRP TO 9,597' SLM (Top of millout window, no issues). 05/19/12 T /I /O = 2440/50/0. Temp =SI. TBG & IA FLs E -Line call -in). No AL. TBG FL @ 9740' (WRP, 350 bbls). IA FL @ 60', 2 bbls. SV,WV= Closed. SSV,MV =Open. IA,OA =OTG. NOVP. (2300 hrs). 05/21/12 (SLB ELINE SET HALLIBURTON CIBP / POWER CUTTER). INITIAL T /I /O = 2300/50/0 PSI LRS LOADED AND KILLED WELL W/ TOTAL 10 BBLS OF METH, 489 BBLS 1% KCL, 92 BBLS OF DIESEL. SSV WOULDN'T CLOSE AFTER KILLING WELL - CALLED IN GREASE CREW AND PRESSURE IT UP FROM TOP W/ 220 PSI FROM THE TOP - IT CLOSED, JOB PROCEEDED CIBP SET DEPTH = 9456'. POWERCUTTER HAS BEEN POST PONNED - 2128 UNIT HAS TO GO ON A RIG JOB TOMORROW MORNING. FINAL T /I /O = 0/0/0 PSI. 05/22/12 T /I /0= 22/62/11 Temp =S /I MIT TBG 2000 psi PASSED (CTD Prep). Pumped 32.8 bbls of 30* diesel down TBG to reach 2000 psi for MIT TBG 1st test 1st 15 min lost 26 psi 2nd 15 min lost 16 psi for a total of 42 psi in 30 min bleed TBG psi down dleed back aprox. 3 bbls Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp's= 490/83/12. 05/23/12 (SLB ELINE POWER CUTTER). INITIAL T /I /O = 200/50/0 PSI. RAN 2.50" SCP POWER CUTTER TO 9355', CUT LINER AT 9355' DEPTH CORRECTED TO SLB MCNL LOG DATED 16- JUNE -06. GOOD INDICATION OF FIRING. LEFT WELL SHUT -IN ON DEPARTURE, HAND OVER WITH DSO. FINAL T /I /O = 200/50/0 PSI. 05/24/12 T /I /0= 150/70/0 Temp =Sl MIT -T to 2000 PASSED (CTD Prep, post tbg cut) Pressured up IA for combo to 2000 psi with 2.1 bbls diesel Tbg did not track, incorrect procedure combo not needed bled psi back and rigged up to tbg for MIT - Tpressured up tbg with 3 bbls diesel Tbg lost 38 psi in 1st 15 min. lost 12 psi 2nd 15 min. for a total loss of 50 psi in 30 min test. Bleed back pressure —3 bbls Final WHP's 150/80/0 SV,VVV,Closed SSV,MV,IA,OA =Open Pad op notified on departure. 05/26/12 CTU #8 - 1.75" coil. Job Scope - Pull test cut liner to verify it is free. Circulate well out and FP. RU. MU fishing BHA. PT and RIH. Drill. Unable to latch liner w/ 4" GS w/ seal assy. POH. No marks to indicate a problem. Remove a wt bar and add centralization. 05/27/12 CTU #8 w/ 1.75" CT (CTV= 34.0). Objective - Verify jet cut liner is free for CTD prep. Continue RIH w/ fishing BHA #2 (GS spear w/ centralization). Unable to latch -not even a friction bite. POH. RIH BHA #3 (GS wo seal assy) and still unable to latch w/ not even a friction bite. POH. RIH w/ 2.5" JSN BHA #4. No weight indications seen while running through liner top. Jetted liner top at max rate. POH. RIH w/ tattle- tale BHA #5 w/ seal assy. Had pressure incr at 8375' and first wt loss at 8377' which match with recorded fish dimensions. Based on previous runs it appears that FN on deployment sub must be washed out or filled w/ deposits. RIH w/ BHA #6 seal assy + GS + sealed knuckle joint and had pressure increase at 8374', but not even a friction bite or indication of latching. 05/28/12 CTU #8 w/ 1.75" CT (CTV= 34.0). Objective - Verify jet cut liner is free for CTD prep. Continue POH w/ BHA #6. LD BHA w/ no marks or recovery. RIH w/ BHA #7 (3" releaseable spear on 4" GS) to wt loss at 8373' Attempt to set spear w/o success. POH. RIH w/ tattle -tale with shearable ball seat circ out liner top and verify liner was cut. Stabbed into 3" PBR. Sheared tool and gained a circulation path down liner and through the cut liner. Circulated out 1.5x bottoms up w/ 550 bbls slick KCI. Page 1 of 2 • . C -09A, Well History (Pre Rig Sidetrack) Date Summary 05/29/12 CTU #8 w/ 1.75" CT (CTV= 34.0). Objective - Verify jet cut liner is free for CTD prep. Finish RIH w/ BHA c„ #9. Set 3" spear in TOL at 8371' CTM. Pulled —1291 liner cleanly uphole —30' w/ 6k over. Set back down at same depth and released from 3" GS. (Note: need 3" GS to fish liner. Need 4" GS to release 3" spear from liner). POH. LD fishing BHA complete. RIH w/ nozzle BHA. FP wellbore from 2000' w/ 76 bbls diesel. 06/09/12 T /I /O =V /50/0. Conduct PJSM. P.T. down on SN 250 psi (passed) -3500 psi (passed), P.T. down on SSV / MV (used as barriers) 250 psi (passed)- 3500 psi (passed), P.T. down on MN 250 psi (passed) -3500 psi (passed), all valves passed bleed off test as well. Tested lubricator each time to 250 psi (passed) -3500 psi (passed).... Set 6" CIW J TWC #422 @ 102" w/1 -2' ext.; Torqued all tree flange nuts to spec. (see log); P.T. tree from TWC up, 250 psi low for 5 min. (passed) -5000 psi high for 5 min. (passed) charted and documented; Pulled 6" CIW TWC; P.T. tree cap upon completion to 500 psi; Pre Nordic 1. 06/11/12 T /I /O= SSV /80/0 Temp =Sl Repair leaking Wellhead. Found 2 LDS gland nuts on TBG head showing signs of leaking. Stung into test void (1900 psi.). Bled void to 0 psi. Tightened all LDS gland nuts on TBG head. Cleaned Wellhead. Pressured test void to 5000 psi. No leaks. Bled void to 0 psi. 07/18/12 T /I /O= 7 /20Nac. Temp = SI. Bleed WHP's to 0 psi. (Pre -CTD). TBG & IA FL's = near surface. Bled TP from 7 psi to 0 psi in 5 minutes. Bled IAP from 20 psi to 0 psi in 15 minutes. Monitor WHP's for 30 minutes. IAP increased 3 psi, bled IAP from 3 psi to 0 psi in 30 seconds, monitor for 30 minutes. IAP increased to 3 psi, No change in TP or OAP. Final WHP's = 0 /3Nac. SV & WV = C. MV & SSV = O. IA & OA = OTG. NOVP. 00:44. 07/20/12 T /I /O = 0 /0 /0 Conduct PJSM. Barriers= MV & SSV to RU Lubricator. Verified by applying 500 psi against SSV through tree cap. LTT passed. Barriers= MV & TWC to remove upper tree. Verified by applying 500 psi against both the MV & TWC independently through lubricator post 6" CIW J TWC installation. LTT Passed. Pulled the 6x7" OTIS BB SSV and installed a new CIW 6x7" mod fls with a baker C actuator. Torqued flanges to 1281 ftlbs. PT connections to 250/5k psi for 5 min each (PASS). Pulled TWC. installed and PT tree cap to 500 psi for 5 min (PASS). 07/21/12 T /I /O = SSV /30NAC. Temp = SI. WHPs (Pre CTD). No well house or flowline. Plywood over cellar. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 1600. 07/25/12 T /I /O = 60 /50Nac. Temp = SI. Bleed WHP's to 0 psi. (Pre -CTD). TBG & IA FL's = near surface. Bled TP from 60 psi to 0 psi in 30 minutes. Bled IAP from 50 psi to 0 psi in 60 minutes. To bleed trailer (gas /fluid). Monitor WHP's for 30 minutes. IAP increased 0+ psi, bled IAP from 0+ psi to 0 psi in 30 seconds, monitor for 30 minutes. IAP increased to 0+ psi, No change in TP or OAP. Final WHP's = 0 /0 +Nac. SV, WV, SSV = C. MV = O. IA, OA = OTG. NOVP. 1130. • 07/27/12 T /I /O = SSV /20Nac. TempSl. WHPs (Pre CTD). No flowline or well house. IAP increased 20 psi since bleed on 07/25/12. SV, WV, SSV, MV = C. IA, OA = OTG. NOVP. 09:45. 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Common Well Name: C -09 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3 -01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/28/2012 14:30 - 18:00 3.50 MOB P PRE MOVE TO C -PAD FROM PRICE PAD 18:00 - 20:00 2.00 MOB P PRE RIG ON SITE. POSITION RIG. CONDUCT CHANGEOUT AND HOLD PJSM FOR MOVING OVER WELL. SPOT RIG OVER WELL. RIG ACC'.FPTFn FOR OPERATIONS AT 2Q00 HRS. 20:00 - 00:00 4.00 RIGU P PRE PICK UP REEL AND SECURE IN REEL HOUSE. PRESSURE TEST AND CONDUCT FLOW TEST PER WELL PLAN TO REMOVE SWAB CAP. TEST OKAY, REMOVE CAP. BEGIN BOP NU. BEGIN RIGGING UP HARD LINE IN REEL. SPOT SATELLITE CAMP, WELDING SHACK, CUTTINGS BOX, INTEGRAL EQUIPMENT. 7/29/2012 00:00 - 06:00 6.00 RIGU P PRE NU BOP STACK, CONNECT CHOKE AND KILL LINES TO BOP STACK. COMPLETE INSTALLING HARD LINE IN REEL WHILE NU BOP. CONTINUE SPOTTING EQUIPMENT ON PAD. RU TIGER TANK AND HARD LINE, PRESSURE TEST. TAKE ON KCL. PREP REEL FOR GRAPPLE INSTALLATION TO PULL OVER. INSTALL LUBRICATOR EXTENSION TO BOP. 06:00 - 06:30 0.50 RIGU P PRE NOTIFY ALL PARTIES CONDUCTING SIMOPS ON PAD OF UPCOMING ALARM. CONDUCT RIG EVAC DRILL WITH CREW. CREW RESPONSE TIME 2 MIN 20 SEC. CONDUCT AAR. CONDUCT PRE -SPUD FOR WELL C -09B. 06:30 - 08:00 1.50 RIGU P PRE CREW CHANGE AND FINISH BOP NU 08:00 - 09:00 1.00 RIGU P PRE PU AND TIE OFF INJECTOR HOSES TO DERRICK 09:00 - 09:45 0.75 RIGU P PRE MU STUFFING BOX TO LUBRICATOR AND MU TO INJECTOR STRING OUT STABBING WINCH CABLE AND MU GRAPPLE PULL TEST GRAPPLE 09:45 - 10:00 0.25 RIGU P PRE PJSM TO STAB PIPE, MU QTS AND FLUID PACK REEL AND STACK FOR A COMPLETE TEST OF REEL IRON AND BOP STACK 10:00 - 11:30 1.50 RIGU P PRE PULL COIL TO INJECTOR 11:30 - 12:30 1.00 RIGU P PRE PIPE STABBED REMOVE GRAPPLE AND CABLE DRESS THE END OF THE COIL AND SEAL THE WIRE RU QTS 12:30 - 13:00 0.50 RIGU P PRE LINE UP KCL TO FILL COIL AND STACK 13:00 - 13:40 0.67 RIGU P PRE ONLINE FILLING COIL WITH KCL 13:02 SHUT DOWN TO TEST REEL IRON FOR LEAKS 13:08 NO LEAKS, CONTINUE LOADING COIL 13:40 - 14:10 0.50 RIGU P PRE KCL RETURNS AT THE SHACKER, LINER UP TO FLUID PACK ALL SURFACE LINES AND STACK FORA SHELL TEST 14:10 - 14:35 0.42 RIGU P PRE HOLDING LOW PT CHECKING ALL SURFACE LINES 14:35 - 14:45 0.17 RIGU P PRE GOOD SHELL AND REEL IRON TEST, CALL OUT STATE INSPECTOR TO WITNESS TEST Printed 8/27/2012 10:20:16AM / r ,/; � > i s�- „ i , r , %�'3 ' 'fi"4+ia://' y ".rr;� { s i te; r a, ,,�,n i / y-<., u x'f Y %a : �,f.' 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"i'' %' :>'''9, <',(. /N= -a "�' <d Common Well Name: C -09 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3 -01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:45 - 15:15 0.50 RIGU P PRE PERFORM RIG EVACUATION DRILL THE ALARM WAS SOUNDED AND EVERYONE MUSTERED WITHIN 3 MINUTES. NO DEFICIENCIES TO REPORT, GOOD DRILL 15:15 - 15:45 0.50 BOPSUR P PRE STATE INSPECTOR ON LOCATION HOLD PJSM TO START TESTING BOP'S 15:45 - 00:00 8.25 BOPSUR P PRE TEST BOPE. FUNCTION TEST BOP FROM DRILLER'S CONSOLE. FLOOD MUD GAS e SEPARATOR. CONDUCT DRAWDOWN TEST; SYSTEM PRESSURE OF 2950 PSI, SHUT IN • PRESSURE OF 2350 PSI, TIME TO 200 PSI 25 SECONDS, TIME TO FULL SYSTEM RECOVERY 80 SECONDS. TEST ALL ALARMS. CONCURRENT OPS: INSTALL GUARDS OVER OA / IA VALVES AND OVER SSV VALVE. - TEST WITNESSED BY AOGCC REP JOHN CRISP, TOOLPUSHER TYLER MCCONNELL 7/30/2012 00:00 - 06:00 6.00 BOPSUR P PRE BOP TEST. TROUBLE TESTING VALVES 2 AND 3. GREASE AND FUNCTION, RE -TEST OKAY. TROUBLE TESTING AGAINST VALVE #19. GREASE AND FUNCTION, STILL SEEING SLIGHT PRESSURE DROP. REMOVE AND RE -BUILD WHILE TESTING FLOOR SAFETY VALVES. RE -TEST VALVE #19, GOOD TEST. FUNCTION TEST BOP FROM COIL OPERATOR STATION. - TEST WITNESSED BY AOGCC REP JOHN CRISP, TOURPUSHER DAVE HILER 06:00 - 07:00 1.00 BOPSUR P PRE INNER REEL VALVE TESTED, RD INJECTOR AND TEST EQUIPMENT 07:00 - 08:30 1.50 FISH P DECOMP MU BTT CTC, PULL AND PRESSURE TEST HOLD PJSM TO PULL TEST INJECTOR FOR ANNUAL TEST AND CALIBRATION 08:30 - 10:30 2.00 FISH P DECOMP RU PULL PLATE TO CTC 10:30 - 11:00 0.50 FISH P DECOMP INJECTOR HEAD LOAD CELL CALIBRATED PJSM TO LOAD BTT TOOLS ON THE RIG 11:00 - 11:40 0.67 FISH P DECOMP PREP TO TEST NIGHT CAP TO OPEN UP TO THE WELL OPEN IA & OA VALVES TO SENSORS AND PUMP SSV OPEN SSV WONT OPEN, PT NIGHT CAP THEN OPEN VALVES TO WELL AND SEE IF ITS JUST PRESSURE LOCKED FROM TESTING BOP'S CALL GREASE CREW TO START HEADING THIS WAY JUST INCASE 11:40 - 12:10 0.50 FISH P DECOMP GOOD TEST ON NIGHT CAP, BLEED OFF AND MONITOR OPEN SWAB AND ITS PRESSURE LOCKED 12:10 - 12:20 0.17 FISH P DECOMP PRESSURE UP TO 2500PSI TO SEE IF WE CAN EQUALIZE THE VALVE 12:20 - 12:30 0.17 FISH P DECOMP SWAB IS OPEN, SSV IS OPEN, OPEN MASTER AND MONITOR FOR PRESSURE 12:30 - 12:35 0.08 FISH P DECOMP NO PRESSURE, LINE UP TO PUMP METHANOL ACROSS THE TOP TO ENSURE THE HOLE IS FULL Printed 8/27/2012 10:20:16AM '1 1 .; ` ‘ e•iV: :. "' ;' iV s i ', ,VICKV :0 7*.:' T7 c. ' f../147%p M N,4:-11,:// 00,*044 ;;),;;;,0,- ,,; 4 , Common Well Name: C-09 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3-01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:00AM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:35 - 12:45 0.17 FISH P DECOMP WELL TOOK 1.4 BBLS AND PRESSURE UP TO 100PSI, SHUT DOWN PUMP AND BLEED OFF PRESSURE. PUMP ACROSS THE TOP TO ENSURE THE HOLE IS FULL THEN SUT DOWN TO FLOW CHECK WELL 12:45 - 12:55 0.17 FISH P DECOMP HOLE IS FULL PUMPED 3.5 BBLS AND LOST —0.2 BBLS SHUT DOWN PUMP AND MONITOR WELL FOR 15 MIN AS PER WELL PLAN 12:55 - 13:10 0.25 FISH P DECOMP HOLD PJSM TO PU FISHING BHA 13:10 - 13:20 0.17 FISH P DECOMP CHECK TO MAKE SURE HOLE IS FULL AND IT IS. REMOVE NIGHT CAP AND CHECK FLUID LEVEL 'JO 13:20 - 14:00 0.67 FISH p DECOMP WELLBORE IS FULL, WE HAVE FLUID IN THE STACK, MU FISHING BHA (r:* 4 ( 3 14:00 - 14:20 0.33 FISH DECOMP MU FISHING BHA t 14:20 - 15:10 0.83 FISH P DECOMP RIH TO 2800' AND CIRC OUT FP 15:10 - 15:30 0.33 FISH P DECOMP CIRCULATE FP OUT 15:30 - 16:35 1.08 FISH P DECOMP GOOD KCL AT SURFACE, LINE UP TO THE MGS TO TAKE RETURNS BACK TO THE PITS 16:35 - 17:05 0.50 FISH p DECOMP STOP FOR CTS MECH TO ADJUST COUNTER-BALANCE VALVES ON INJECTOR CBV ADJUSTED CONTINUE RIH 17:05 - 17:10 0.08 FISH P DECOMP WEIGHT CHECKS BEFORE LATCHING ONTO FISH PU WT = 33K ELEC 34K ON MECH, RIH WT = 19K ELEC 20K MECH 17:10 - 21:45 4.58 FISH P PRODOP TAG FISH, STACK 5K DOWN AND PU. UP WT = 39K ELEC 40K MECH PU 20 AND CIRC 1.5 VOLUMES AS PER WELL PLAN. CONDUCT FLOW CHECK AFTER CIRCULATING 460 BBLS. NO FLOW. 21:45 - 00:00 2.25 FISH P PRODOP POH WITH FISH. 7/31/2012 00:00 - 00:30 0.50 FISH DECOMP POH WITH FISH (3-1/4" LINER ASSEMBLILTO 300', FLOW CHECK WELL. NO ISSUES. PJSM ON POPPING OFF AND LAYING DOWN LINER. 00:30 - 04:30 4.00 FISH DECOMP PULL FISH TO SURFACE. LD BHA. SECURE AND BREAK OUT 3" FISHING SPEAR ASSEMBLY WITH SEAL ASSEMBLY AND DEPLOYMENT SLEEVE. LAY DOWN SEAL ASSEMBLY, DEPLOYMENT SLEEVE, PUP JOINT, AND XN NIPPLE. CEMENT SHEATH ALL THE WAY TO THE DEPLOYMENT SLEEVE. LD 3-1/2" JOINT. CHANGE OUT DIES. LAY DOWN 1 JOINT OF LINER AND HAVE AAR TO DETERMINE IF EVERYONE AGREES THAT THE JOB IS BEING CONDUCTED PROPERLY. DECIDE TO MOVE PLACEMENT OF FARR TONGS. CONTINUE TO LAY DOWN TOTAL OF 30 JOINTS OF 3-1/4" LINER (3-3/16" CONNECTIONS). LD CUT JOINT, LENGTH 6.96'. 04:30 - 05:00 0.50 FISH P DECOMP CLEAR AND CLEAN RIG FLOOR OF EQUIPMENT AND CEMENT SCALE. RD ELEVATORS. RU INJECTOR TO PREPARE FOR UNDER REAMING BHA. Printed 8/27/2012 10:20:16AM erciedi,d 'crre%;,,%: ,,44;k44%;:eel,%pAto,,,% % ;", Common Well Name: C-09 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3-01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud DatefTime: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 06:00 1.00 FISH P DECOMP MQUIDERBEAMEEIBLEAMIX MILL, DB UNDER REAMER, 2-7/8" STRAIGHT MOTOR, CIRC SUB / DISCONNECT, JARS, DUAL BPV, XO, 2 JTS 2-3/8" PH6, XO, LOCKABLE SWIVEL, XO, COIL TUBING CONNECTOR. MU INJECTOR, PRESSURE TEST QUICK TEST SUB. 06:00 - 08:00 2.00 FISH P DECOMP RIH WITH UNDER REAMER BHA MONITORING RETURNS. 08:00 - 09:00 1.00 FISH P DECOMP STOP RIH WAITING FOR MUD 09:00 - 09:40 0.67 FISH P DECOMP PUMP CLEAN KCL SPACER FOR MUD SWAP 09:40 - 11:00 1.33 FISH P DECOMP PUMP A 35 BBL HI-VIS PILL FOR A CLEAN TRANSITION BETWEEN KCL AND NEW MUD 11:00 - 12:00 1.00 FISH P DECOMP ALL MUD ON LOCATION AND READY TO GO DOWN HOLE. CIRC 25 BBLS TO GET HI-VIS PILL TO THE MILL THEN RIH TO 8500' TO START UNDER REAMING 12:00 - 18:00 6.00 FISH P DECOMP UNDERREAM AT 30-FPH, CIRCULATING AT 2.68-BPM / 2480-PSI FROM 8500' 18:00 - 00:00 6.00 FISH P DECOMP CONDUCT CREW CHANGEOUT. CONTINUE WITH UNDER REAMING PER WELL PLAN AT 30 FPH. NO LARGE DEBRIS COMING ACROSS SHAKERS. 8/1/2012 00:00 - 06:00 6.00 CLEAN P DECOMP WORK UNDER REAMER FROM 8800' TO 9060' AT 2.65 BPM, 2480 PSI. NO MOTOR WORK SEEN TO THIS DEPTH. 06:00 - 14:30 8.50 CLEAN P DECOMP CONTINUE TO UNDER-REAM FROM 9060' AT 2.68-BPM / 2490-PSI. SEE MOTORWORK BEGINNING AT 9080' WITH INCREASE IN PRESSURE TO 2530-PSI. AFTER BOTTOMS UP SEE SLIGHT INCREASE IN CUTTINGS ACROSS SHAKERS - DARKER COLORED AND VERY FINE (SANDY) PARTICLE RETURNS. BLEED IA FROM 450-PSI TO 20-PSI - MOSTLY FLUID. BLEED OA FROM 480-PSI TO 50-PSI - MOSTLY FLUID. CHANGE OUT SENSOR ON IA BECAUSE SENSOR READING WAS LOWER THAN GAUGE READING. MOTOR WORK INCREASES TO 100-PSI PAST 9200'. PUMP 20-BBL HI VIS SWEEP AT 9270'. MINIMAL INCREASE IN FINE CUTTINGS WITH SWEEP BACK. CONTINUE TO UNDERREAM AHEAD TO TAG STUMP AT 9355.5' (UNCORRECTED). 14:30 - 15:30 1.00 CLEAN P DECOMP PU & REPEAT TAG WITH 1.5K-LBS DOWN AT 9355.5'. PU AND BACK REAM FROM STUMP TO 9300' AT 3.5-FPM. UNDERREAM FROM 9300' TO STUMP AT 3.5-FPM. REPEAT UP PASS - VERY CLEAN WITH LITTLE PRESSURE FLUCTUATION. IA / OA = 160-PSI / 180-PSI. Printed 8/27/2012 10:20:16AM r v4 It r`J " , < , . ,o G;.,; :' %; -.'v, >'. = °.;�, ..« / - ? %f^"s:?x'• %' r� / / / y&.`�G", �r Fryj;;,. is / . ,psi / ; r g / / mil' Yv r X4 2 ��� / !` / ,v - ,r % rr .: L a;.:.{y;- z ip, a • s, - ...�' G''".� �' �� r �, r '� � �" a ,i j £r� /a " '% 4 ; ;, ' 4 'lyk 7 .r,� , .r •%/ ✓:��, 'b , � ti .�� r� ,y%f'/ cr / i % � % ," " r � i- ;, 'r,.' >;; '3 r�r '' . ' , � ' i F ^�� r' s° �' i �.°�'/ aY „ ?r :y < ,/' < � >: :3 a a s: j 5 / .. ' ?it,l ^ 10 y r ��;�� !Ytf; .:Lf ,r v •tl r nr , Yr„ /.� .. /GY .'S�,S.a'..� , !,. /!!!! , Y'.z ,A5117/, �O.d°' / Common Well Name: C -09 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3 -01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 16:30 1.00 CLEAN P DECOMP POSITION BALL DROP. BEGIN PUMPING 40 -BBLS HI VIS SWEEP. DROP 5/8" BALL CHASING WITH REST OF SWEEP AT 2.7 -BPM / 2300 -PSI. DROP RATE TO .6 -BPM / 1400 -PSI WITH 36 -BBLS PUMPED. RECIPROCATE PIPE SLOWLY WHILE PUMPING BALL DOWN & POSITION NEAR STUMP WHEN SWEEP TURNS CORNER. SEE SHEAR WITH 48 -BBLS PUMPED AND 3800 -PSI. FINISH PUMPING SWEEP INTO ANNULUS. 16:30 - 20:00 3.50 CLEAN P DECOMP FLOW CHECK WELL - NO FLOW. POH, CHASING SWEEP AT 3.7 -BPM / 2850 -PSI. NO INCREASE IN CUTTINGS NOTED WITH SWEEP BACK. FLOW CHECK WITH BHA AT 350' BELOW BOP. PJSM ON LAYING DOWN BHA. FLOW CHECK GOOD. 20:00 - 20:30 0.50 CLEAN P DECOMP PULL BHA TO SURFACE. POP OFF, LAY DOWN BHA. 5/8" BALL RETRIEVED. MILL IN GAUGE AT 3.80' GO, 3.79" NO -GO. CUTTERS ON UNDER REAMER NOT DAMAGED OR SHOWING SIGNIFICANT WEAR. 20:30 - 21:00 0.50 EVAL P DECOMP CONDUCT FLOW CHECK ON TWO MECHANICAL BARRIERS (VALVES) IN ORDER TO PREPARE FOR COIL MANAGEMENT OPERATIONS. GOOD FLOW CHECK. 21:00 - 00:00 3.00 RIGU P DECOMP STAB ON WITH INJECTOR. REVERSE CIRCULATE WITH FRESH WATER TO PUMP E -LINE BACK FOR SLACK MANAGEMENT. CUT 300' OF COIL. CUT AND CLEAN COIL FOR INSTALLING COIL CONNECTOR. INSTALL CONNECTOR PRESSURE TEST AND PULL TEST CONNECTOR. BOTH GOOD. STAB BACK ON AND PUMP SLACK FORWARD. 8/2/2012 00:00 - 02:15 2.25 RIGU P DECOMP PREP E -LINE. HEAD UP WITH BAKER INTEQ UPPER QUICK CONNECT. TEST CONDUCTIVITY. MU LOWER QUICK CONNECT. STAB ON, PRESSURE TEST QUICK TEST SUB AND DUAL FLAPPER CHECK VALVES. GOOD TEST. BLEED PRESSURE OFF. 02:15 - 03:15 1.00 EVAL P DECOMP MONITOR WELL WHILE CONDUCTING PJSM ON MAKING UP DUMMY WHIPSTOCK BHA OPEN WELL TO CLOSED CHOKE. NO PRESSURE. OPEN CHOKE, NO FLOW. POP OFF, FLUID COLUMN STATIC. MAKE UP BHA: GAUGE RING CARRIER, WEIGHT PIPE, GAUGE RING CARRIER, XO, BLIND SUB, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO, CTC. PRESSURE TEST QUICK TEST SUB. CIRCULATE AT SURFACE TO CLEAR COIL OF FRESH WATER. Printed 8/27/2012 10:20:16AM ;f . w �, u - .m y mv 'r. y O ' .f% � .,. .� ' 9 ,� �5:zS`i,. i ✓. p� , a 1',4 1 k ' e /, .se ✓ wY „ (4:; y f , ,,... g„ ' / , ice... M /X/ �� � . � %' � 'J` �;�i� � L s y � z.`i r, :�" % h? i�/i,�'L'. x r k ,a � �} G �,,.: � r / ,"s / o r �, "' . '' ✓ / G / // . sqz y ,?> ; ,: ,. /, '3�'�����,� /:j-. �e ; %.s`!�. � � r/, z y � f f�y� � ..Y��'� /�'� �'/3 %.r �/ 9 % `'�, J`" /ytx "'''"' °��.,�'�. . p V ,,s 1% '..��° �. �., A i' j r�'rv. ,;G ,"Spa 'u .fr.., � . /� ?onxf,.r�n.r,ic..d,�, �` „Y,r a,� �s�.h'f'�:,�..,., /�% K�:�`,r'�a , �:. , .m. - „�°v3.f� �. i,�`; ���. �f, s4. i.����, ,o � / %i�'.eu'/� ✓.,.7 ... ,.�i �s, Alfa Common Common Well Name: C -09 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3 -01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:15 - 05:00 1.75 EVAL P DECOMP RIH WITH WHIPSTOCK DRIFT ASSEMBLY. CONDUCT KICK WHILE TRIPPING DRILL WITH CREW. SIMULATE PIT GAIN, RESPONSE TIME OF <1 MIN. SHUT DOWN PER STANDING ORDERS, CHECK FOR FLOW, INDICATE NO FLOW, RESUME OPERATIONS. CONTINUE TO RIH TO 9100'. 05:00 - 07:00 2.00 EVAL P DECOMP LOG TIE -IN TO PDC LOG FROM 9100' TO 9290'. APPLY -2' CORRECTION IA / OA / PVT = 70 -PSI / 10 -PSI / 320 -BBLS. 07:00 - 07:20 0.33 EVAL P DECOMP RIH: TO TAG LINER AT 9354.7' CORRECTED DEPTH. PON TO 8300'. 07:20 - 08:30 1.17 EVAL P DECOMP LOG CCL DOWN FROM 8300' AT 1200 -FPH TO JUST ABOVE LINER STUMP FOR DELINIATING LINER TOP PLACEMENT AND WHIPSTOCK SETTING DEPTH. AVG JT LENGTH = 39.5' AND SEE LOWERMOST COLLAR AT 9293'. THIS INDICATES COLLAR AT 9332.5' WHICH IS ACROSS WHIPSTOCK TRAY AT PLANNED SET DEPTH OF 9325'. CIRCULATE AT .9 -BPM / 1160 -PSI. LIGHTLY TAG LINER STUMP AT 9355'. FLOW CHECK WELL - NO FLOW. 08:30 - 10:00 1.50 EVAL P DECOMP POH WITH WHIPSTOCK DRIFT CIRCULATING AT 1 -BPM / 1130 -PSI. DISCUSS WHIPSTOCK SETTING DEPTH WITH ODE, DD, BTT REP & GEO. PLAN TO SET TOP OF WHIPSTOCK AT 9310'. BHI DEVELOP NEW DIRECTIONAL PLAN AND ODE COMPLETE MOC. IA / OA = 90 -PSI / 10 -PSI. 10:00 - 10:30 0.50 EVAL P DECOMP FLOW CHECK WELL AT 200' - NO FLOW. HOLD PJSM ON LD DUMMY WHIPSTOCK & MU WHIPSTOCK. DISCUSS POSITIONS OF PEOPLE, EQUIPMENT HANDLING AND BHA COMPONENTS. HIGHLIGHT NEW RATED LIFTING EYE FOR HANDLING WHIPSTOCK - GREAT IMPROVEMENT FROM BTT. IA / OA / PVT = 80 -PSI / 10-PSI/ 273 -BBLS. 10:30 - 11:00 0.50 EVAL P DECOMP UNSTAB INJECTOR AND SET BACK OVER CIRC HOLE. BLOW DOWN BHI TOOLSTRING & LD TO PIPE SHED. LD DUMMY WHIPSTOCK DRIFT. 11:00 - 11:30 0.50 STWHIP P WEXIT PU WHIPSTOCK & MU RUNNING TOOL. MU TO BHI COILTRAK BHA. BHA CONSISTS OF - 7” GEN 2 WHIPSTOCK, ADAPTER KIT, J HYDRAULIC SETTING TOOL, XO, XO, HOT , DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO, CTC. OAL = 80.80' 11:30 - 12:00 0.50 STWHIP P WEXIT MU COIL TO STRING & STAB INJECTOR ON WELL. TEST QTS TO 250 -PSI / 3500 -PSI FOR 5 -MIN PER TEST. GOOD TESTS. OPEN EDC. 12:00 - 13:45 1.75 STWHIP P WEXIT RIH WITH WHIPSTOCK, CIRCULATING THROUGH OPEN EDC AT .4 -BPM / 900 -PSI. IA / OA = 60 -PSI / 10 -PSI. Printed 8/27/2012 10:20:16AM - - -q ::I/V7z;r 6 W 7 4, e::', e** 41, '!;:;;Y:f44%C.11%""z:tiei;:40*(Aila0:4'14.*(,T!;I! 0'1 :1:;i11( 1 :j ?j AetgfkA?,:nztt%W'WW#SVMiei,t:I,% Common Well Name: C-09 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3-01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:45 - 14:15 0.50 STWHIP p WEXIT LOG TIE IN TO PDC LOG. APPLY -2' CORRECTION. NEW DIRECTIONAL PLAN RECEIVED FROM BHI WELL PLANNER. IA / OA = 70-PSI / 10-PSI. 14:15 - 15:15 1.00 STWHIP P WEXIT OBTAIN PU WEIGHT AT 9280' -- 37K-LBS. ORIENT TO WHIPSTOCK TO 30L (330-DEG TF). RIH TO 9327.5' (TOP OF WHIPSTOCK AT 9310'). REVIEW DIRECTIONAL PLAN TO ENSURE (-7- OBJECTIVES MET - NO ISSUES. ° 15:15 - 15:30 0.25 STWHIP P WEXIT RECEIVE AGREEMENT FROM ODE TO SET ti510 WHIPSTOCK PER PLAN #2. CLOSE EDC. P_FIEMELUELQ7.0TS1 & SEE WI-pps SHEAR SET. SET DOWN 2K-LBS TO CONFIRM SET. FLOW CHECK WELL - NO FLOW. 15:30 - 17:15 1.75 STWHIP P WEXIT POH WITH WHIPSTOCK RUNNING TOOLS. STOP AT 300' AND FLOW CHECK WELL - NO FLOW. 17:15 - 17:30 0.25 STWHIP P WEXIT HOLD PJSM ON LD WHIPSTOCK RUNNING TOOLS. DISCUSS INJECTOR HANDLING, IMPORTANCE OF COMMUNICATION, OFFLOADING UN-NECESSARY TOOLS. 17:30 - 19:00 1.50 STWHIP P WEXIT UNSTAB INJECTOR AND SET BACK OVER CIRC HOLE. BLOW DOWN BHI TOOLSTRING & LD WHIPSTOCK RUNNING BHA. CONDUCT CREW CHANGE OUT, OFFLOAD TOOLS FROM RIG FLOOR. PJSM ON MAKING UP MILLING BHA. 19:00 - 20:00 1.00 STWHIP P WEXIT MU MILLING BHA: 3,.80" WINDOW MILL, 3.78" STRING MILL, 2-7/8" MOTOR, XO, 2 JTS PH6, XO, BLIND SUB, DGS, DPS, EDC, P&C, WEAR SUB, LQC, UQC, XO, CTC. GAUGE MILLS: WINDOW MILL 3.80" GO, 3.79" NO-GO; STRING MILL 3.80" GO, 3.79" NO-GO. CONDUCT KICK WHILE MAKING UP MWD TOOLS WITH NEW FLOORHAND WORKING BHA. REACTED PER STANDING ORDERS. CONDUCTED WALK THROUGH AFTER DRILL TO EMPHASIZE CERTAIN ASPECTS OF MAKING UP SAFETY ti JOINT AND REINFORCING THE TIMING OF THE CLOSURE OF THE SAFETY VALVE IP COMPLETE MAKING UP BHA, STAB ON WITH INJECTOR. PRESSURE TEST QUICK TEST SUB. 20:00 - 22:30 2.50 STWHIP P WEXIT RIH WITH WINDOW MILLING ASSEMBLY. LOG TIE-IN WITH -2' CORRECTION. CONTINUE TO RIH. OBTAIN SLOW PUMP RATES ABOVE WHIPSTOCK. DOWN ON PUMPS AND CONTINUE TO RIH TO DRY TAG WHIPSTOCK. Nui TAG AT 9318' COIL TUBING DEPTH. PICK UP, PUW 36K. RUN BACK DOWN AND DRY TAG ( AGAIN AT 9316'. PICKUP, PUW 37K. COME ON WITH PUMPS TO 2.65 BPM, 2440 PSI, AND RUN BACK DOWN. TAG AT 9316'. BEGIN TIME MILLING. Printed 8/27/2012 10:20:16AM ,,,o % �;,c�:r� �:: fir;' k„ i...� xx , „/ s r "t 6„r mil, - ,o- N� ., ;..r A.. ,u�, "y>`:;gF5%` , p /, .r , /�"i�`,n- %��:, i;,v,'.�,. .y,,,r ,r /,,?,,,,>�.�,. r� <,7,�;��i "",` i �� ,„ . _4 r. ';✓ �, % � s i /,'; , %i . ,.,r !`.?e -1 > ,,,�,� � i ., � u�/ :,,i /v r , /.,,..s/ „� �j,.,,�c,.�� /: 2,�, ra�<?,s`.�,.,�+�w ,p, :4' �,,:.✓ 1 .7`''y /v- �r y �`v „s'.i' � y� '` /' i s:.. ; `v ^' , "fir / .r, ` ;�: o:v '< �.',�''. ',! ;�j,'/� , //; ... fi g, r.,� / , ���r .a /�? . yv , sr . 3" : , ;/ /,k ,.� /:; ' /f; /y; .�i;r / y 9"n, f .�, ,j l�'a -w /�.c"?„T'.`;' "''' „fs/r i ,+�Y; y ,.,// / ,v,: >, �� ti; ; "s , : i z: y /r a/° "' '' $ %' ,.^ a" ,,/ r f�. /S'/�/f '^ - / / /, // , ' . /':>r..�nir �. ,��i ; %i' % % x'. , Common Well Name: C -09 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/28/2012 End Date: 8/10/2012 X3 -01250 (2,181,168.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 6/25/1979 12:00:OOAM Rig Release: 8/16/2012 Rig Contractor: NORDIC CALISTA UWI: Active Datum: Kelly Bushing / Rotary Table @62.50ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) „ f 22:30 - 23:45 1.25 STWHIP P WEXIT TIME MILL WINDOW FOR FIRST FOOT AT 2.66 +1 BPM, 2425 PSI. WOB NEGLIGIBLE. G.- Mb 23:45 - 00:00 0.25 STWHIP P WEXIT BEGIN TO INCREASE WOB AND PRESSURE. 2.65 BPM, 2.5 -3 K WOB, 2600 -2700 PSI. 8/3/2012 00:00 - 02:30 2.50 STWHIP P WEXIT MILL WINDOW AT 2.68 BPM, 2700 -2800 PSI, 3.0 -4.2K WOB. MW IN AND OUT 8.5 PPG. INCREASE WOB TO CONTINUE MILLING AT 3.4 -3.7K WOB; SEEMED TO HAVE THE BEST ROP BUT HAD SIGNIFICANT AMOUNT OF IMPACT OF VIBRATION UPON THE SURVEYS. CONTINUE MILLING WITH DIFFERENTIATING WEIGHT ON BIT. 1.9 -2.6K WOB RESULTED IN 1.9 FPH ROP AND MINIMIZED VIBRATION IMPACT UPON TOOLS. 02:30 - 03:30 1.00 STWHIP P WEXIT BEGIN TIME MILLING LAST FOOT OF WINDOW AT 2.67 -2.70 BPM, 2480 -2670 PSI, .1 -.72K WOB. ESTIMATED WINDOW MILL EXIT AT 9324.0'. CONTINUE WITH TIME MILLING WITH STRING MILL IN WINDOW. ESTIMATE STRING MILL OUT OF WINDOW AND DRILLING INTO NEW OPEN FORMATION AT 9325'. 03:30 - 08:00 4.50 STWHIP P WEXIT DRILL INTO NEW OPEN HOLE WITH MILLING ASSEMBLY TO 9335'. RESET COUNTER FOR BOTTOMS UP SAMPLE. DRIFT THROUGH WINDOW THREE TIMES, PUMP HI-VIS PILL WHILE DRIFTING. GEO CONFIRMS 90% FORMATION SAND IN SAMPLE. SHUT DOWN PUMP AND DRY DRIFT WINDOW - NO ISSUES. FLOW CHECK WELL - NO FLOW. IA / OA / PVT = 190-PSI/ 50 -PSI / 309 -BBLS. 08:00 - 10:30 2.50 STWHIP P WEXIT FLOW CHECK WELL - NO FLOW. OPEN EDC. POH WITH WINDOW MILLING BHA, CIRCULATING AT 3.8 -BPM / 2950 -PSI, TO 300' NO NOTABLE CHANGE IN CUTTINGS WITH SWEEP. 10:30 - 11:00 0.50 STWHIP P WEXIT AT 300', FLOW CHECK WELL - NO FLOW. CLOSE EDC. HOLD PJSM ON LD BHA. DISCUSS ORDER OF OPERATIONS, BEAVERSLIDE USAGE, WELL CONTROL CONSIDERATIONS AND IMPORTANCE OF COMMUNICATION. IA / OA / PVT = 180 -PSI / 150 -PSI / 268 -BBLS. 11:00 - 11:30 0.50 STWHIP P WEXIT UNSTAB INJECTOR AND SET BACK OVER CIRC HOLE. BLOW DOWN BHI TOOLSTRING. LD WINDOW MILLING BHA. INSPECT & GAUGE MILLS - NORMAL WEAR PATTERS & WINDOW MILL = 3.8" GO / 3.79" NO GO. STRING MILL = 3.79" GO / 3.78" NO GO 11:30 - 12:00 0.50 DRILL P PROD1 MU BUILD /LATERAL DRILLING BHA. BHA CONSISTS OF 3 -3/4" X 4 -1/4" HYC HELIOS BICENTER, 1.3 -DEG 3 -1/8" ULS MOTOR, HOT, USMPR, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO, CTC. OAL = 85.85' PU INJECTOR, MU COIL TO BHA AND STAB ON WELL. Printed 8/27/2012 10:20:16AM . WELLHEAD = 6 � 0 C -09A SAp NOTES: WELL ANGLE > —70° @ 9741'. ACTUATOR= OTIS KB. ELEV = 62.48' BF. ELEV = 33.7' KOP = 2800' Max Angle = 97° @ 10560' 120" CONDUCTOR 1 110' ® 1982' -- 17" SSSV OTIS LANDING NIP, D= 5.962" 1 Datum MD = 9550' DatumTVD= 8800' SS 2601' H9-5/8" DV PKR 13 -3/8" CSG, 72 #, L -80 BTRS, D = 12.347" 1 2660' i -8373' CTMD 1- BAIT SUB (05/29/12) -3' GS TO FISH / Minimum ID = 2.377" @ 9693' 4" GS TO RELEASE 3" SPEAR FROM LNR 3 -3/16" X 2 -718" XO ci,' 1 8387' H3 -1/2" BKR DEPLOY SLV, D = 3.00" 1 8396' —13 -1/2" HES XN NIP, D= 2.75" 17" TBG, 26#, L -80 AB -LI-4S, .0383 bpi, ID= 6.276" H — 8400' 8406' — 17" FBRASSY, D =? 13 -1/2" LNR, 8.81 #, L -80 STL, .0076 bpf, ID = 2.992" H 8427' 1 , 842T 1�3 i/2 X 3-3/16" XO, D = 2.786" ►�� 8429' H9-5/8" X 7" GUI3 PKR, ID= 3.833" 1 e 8430' I — { 7" X 4 -1/2" XO, D = 3.958" 4 -1/2" TBG, 12.6 #. L -80, .0152 bpf, ID = 3.958' —1 8461' CNEM CUT TBG (05/03/02) „" PuJLI C' 1 TOP OF 7" LNR H 8487' 1 0 — l { 9 -5 /8" CSG, 47 #, L -80 BTRS, D = 8.681" —1 9007' 4 - 9355' — JET CUT LNR (05/23/12) 1 ✓ `' 9456' J-13-3/16" HES CbP (05/21/12) 1 V / 9533' 1 7" MARKER JONT r MLLOUT W 'DOW (C - 09A) 9594' - 9603' I TOP OF WHIPSTOCK (05/03/02) H 9593' 1 1 9693' — 3116 X 2 -7/8" XO, D = 2.377" PBTD — 9865' ►'O'1'1'1'1'1'1 9740' -- (11/19/11)1 9999(49 1 p , D = 6.184" — 7" LNR, 29 #, L -80 BTRS, .0371 bpf, ...Of**. 99 10' 14.40 . )11...4 1 1111 �� 10100' — 2.23" WFD CBP ••••••••' ` (12113108) Not PERFORATION SUMMARY .9.9.9.9.9.9 REF LOG: MCNL ON 05/13/02 / / ANGLE AT TOP PERF: 53° @ 9692' '3 -3116" LNR, 6.2#, L -80 TCII, —1 9693' Note: Refer to Production DB for historical pert data .0076 bpf, ID = 2.80 � M. SIZE SPF INTERVAL Opn/Sqz DATE PBTD H 10525' "' 1.56' 4 9692 -9702 C 11/18/11 2" 6 9835 - 9895 C 06 /17/06 2" 6 9958 - 9983 C 12/14/08 2 -7 /8" LNR, 6.16 #, L -80 STL, —1 10560' 1 2' 4 10152 - 10450 C 05/14/02 .0055 bpf, ID = 2.38" DATE REV BY COMMENTS ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/79 ? ORIGINAL COMPLETION 06/07/12 MH /JMD SET BAIT SUB (05/29/12) WELL: C-09A 05/14/02 N3S CTD SIDETRACK ! 06/17/12 DBM/ PJC BAfT SUB CORRECTION PERMIT No: ` 2020940 ' 12/12/08 RLM /PJC DRAWING CORRECTIONS API No: 50-029 - 20366 -01 01/12/09 RMH /SV SETCIBP /ADPERF (12/13/08) SEC 19, T11N, R14E, 886' SNL & 1223' WEL 12/16/11 SRD/ PJC WRP/ PERFS (11/18 - 19/11) 05/25/12 RWM/JMD SETCIBP/CUT LNR (05/21- 23/12) BP Exploration (Alaska) • • ,; q SEAN PARNELL, GOVERNOR ate j ' L r a 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 BP Exploration (Alaska), Inc. 6/ 01 _ d 9 P.O. Box 196612 Anchorage, AK 99519 -6612 , ..... Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C -09A Sundry Number: 312 -171 Dear Mr. McMullen: x 7012 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, / 0 ) ,,, e ,„, 4 „,..._ Cathy � Foerster Chair DATED this eday of May, 2012. Encl. STATE OF ALASKA o f 5I 7 RECEIVED ALA* OIL AND GAS CONSERVATION COMISION MAY 0 3 201 APPLICATION FOR SUNDRY APPROVAL 2 20 AAC 25.280 AOGCC 1. Type of Request: 1 ❑ 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 202 - 094 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20366 - 01 - 00 . 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU C -09A ` Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028305• Prudhoe Bay / Prudhoe Bay • 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): 10560' ,. 9042' • 10520' 9045' 10100', 9740' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2660' 13 -3/8" 2660' 2660' 4930 2670 Intermediate 9007' 9 -5/8" 9007' 8357' 6870 4760 Production Liner 1108' 7" 8487' - 9595' 7873' - 8905' 8160 7020 Liner 2173' 3 - 1/2" x 3 - 3/16" x 2 - 7/8" 8387' - 10560' 7780' - 9042' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9692' - 10450' 8983' - 9038' 7 ", 26# / 4-1/2", 12.6# L -80 8461' Packers and SSSV Type: 9 -5/8" x 7" GUIB Packer Packers and SSSV 8429' / 7819' 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: June 15, 2012 it � ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Ga ` +� ` ❑ GINJ ❑ GSTOR ❑ Pjbandoned Commission Representative: ❑ WAG ❑ SPLUG Susn /2........, 4 4 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Matt Ross, 564-5782 Printed Name John McMullen Title Engineering Team Leader /' AT Os Fog _Tohw Prepared By Name/Number: Signature / 4 , Phone 564 - 4711 Date 5/34. Joe Lastufka, 564 -4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �, �,�� , Sundry Number: ❑ Plug Integrity ABOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 74 3.SCO P 3 oe / (c73 n Other: 1c Al mon )'l p / 4 c �- p�0'G - r.J' ��l ZCU .. •. �' • G � Subsequent Form Required: / 0" 4 / d 7 P 2 , APPROVED BY � 6 -/ Approved By: COMMISSIONER THE COMMISSION Date - . R1G1N L Form 10 403 Revised 01/ 01 �BDM S MAY 0 9 2012 �� _ Su bmit In Duplicate s \ • • To: Alaska Oil & Gas Conservation Commission From: Matthew Ross by CTD Engineer Date: May 3, 2012 Re: C -09B Sundry Approval Sundry approval is requested to plug the C -09A perforations as part of drilling the C- I 09B coiled tubing sidetrack. History of C -09A. C -09A is a May 2002 CST completed in Zn 2A. Initial production rates were lower than expected for Zn 2A. The gas rates quickly climbed, and the GOR stabilized only two months. A Borax/MCNL log run in September 2002 which did not identify any channels in the lateral. With one large perforation interval, options were extremely limited. 60' of Zn 2A perfs were shot near the landing point in June 2006. In December 2008 a CIBP was set to shut off the long original pelf set (10152' -450') and 25' of additional Zn 2A was shot near the landing point. C -09A flowed nearly fulltime until mid 2010 when it began to cycle. A WRP was set in November 2011 to isolate all open perfs, and 10' of Zn 2A was shot in the heel. Unfortunately, this didn't improve production. C -09A is currently cycling with degrading production and ontime. Reason for sidetrack. C -09A is no longer a competitive producer, and there are no remaining wellwork options. The proposed sidetrack will access reserves in a -40 acre v target Z2A in southern C -pad. Proposed plan for C -09B is to drill a through tubing sidetrack with the SLB /Nordic Coiled Tubing Drilling rig on or around July 10 2012. The existing perforations will be isolated by a CIBP set in the 3- 3/16" and the primary cement job for the liner. The sidetrack, C -09B, will exit the existing 7" liner, kick off in Z4, and land in Z2A. This sidetrack will be completed with a 3 -1/2" x 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. cola?!, 1 < 1 ea' w-e f/ U(irq S vc f r �/ 5 -5- re' 60 Nisu /5 /3 &OR 1A/4 rn i �'4 �t t. f Oof , s f c k '4 11/ xf /s %B 970' y `' w e l l s Gr e , i i The - 2 0 I - 0 1 2 A a s t i k i five, 4 s 1 e q ' g k V G ( ' # os g ' �-e// 6h r -P_ P TJ -vet/ {6- r fad nT 04A -/f/A1 Tho S #0110 9 /IAA, j t l P4sr-o1 4 ecG' /e' -fi T,' e' v-f »')' /co/ • th 21Z Pre Rig Work: (scheduled to begin June 15 20 12) 1. E Set 3- 3/16" CIBP at —9,500' MD using CCL to locate mid joint, & PT to 2,000 psi. '! 2. E Chemical cut 3- 3/16" tubing at 9,355' (free point at 9,370' MD). 3. C Pull test 3- 3/16" liner with 4" GS Spear. Freeze protect well to 2,000' MD. 4. V PT MV, SV, WV. 5. 0 Bleed wellhead, production, flow, and GL lines down to zero and blind flange. 6. 0 Remove wellhouse, level pad. Rig Work: (scheduled to begin July 10 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. P €� 2. RIH above deployment sleeve, swap well to 1% 8.4 ppg KCI. 3. Pull 3- 3/16" liner stub ( -963') from 8,387' MD. 4. Dummy WS Drift to 9,355'. 5. Set 4 -' /z" x 7" TT whipstock at 9,325' MD. (Tag stump, PU 1 - and set). 6. Mill 3.80" window at 9.325' and 10' of rathole. Swap the well to PowerVis. 7. Drill Build /Lateral: 4.25" OH, 2,325' (12 deg /100 planned) with resistivity. 8. Run open hole caliper log for swell packer analysis. 9. Run 3 - 1/2" x 3 -1/4" x 2 -7/8" L -80 liner leaving TOL at 8,385' MD. +1 10. Pump primary cement leaving TOC at 8,750' MD, 40 bbls of 15.8 ppg liner cmt planned. iluw 1 11. Perform liner cleanout with mill, motor and MCNL/GR /CCL log. 12. Test liner lap to 2,400 psi. 13. Perforate liner per asset instructions (- 200'). 14. Freeze protect well to 2500' TVD 15. Set BPV, RDMO. Post -Rig Work: 1. Re- install wellhouse, flowline and pull BPV. 2. Set liner top packer if needed with slickline & test to 2,400psi. 3. Test separator. Matthew Ross CTD Engineer 564 -5782 CC: Well File Sondra Stewman/Terrie Hubble TREE = 6 -3/8" OCT I WELLHEAD = OCT • SAONOTES: ACTUATOR = OTIS C-09A . KB. ELEV = 62.48' BF. ELEV 33.7' KOP = 2800' Max Angle = 97 @ 10560' 120" CONDUCTOR H 110' I I 1982' I SSSV OTIS LANDING NIP, ID = 5.962" I Datum MD = 9550' Datum TVD = 8800' SS 2601' H9-5/8" DV PKR I ■ 113 -3/8" CSG, 72 #, L -80 BTRS, ID = 12.347" I-1 2660' Minimum ID = 2.377" @ 9693' 3- 3116" X 2 -7/8" XO 8387' H3-1/2" BKR DEPLOY SLV, ID = 3.00" I I 8396' 1-13-1/2" HES XN NIP, ID = 2.75" I I7 TBG, 26 #, L -80 AB- IJ -4S, .0383 bpf, ID = 6.276" H -8400' .. 1--______ . 8406' H 7" PBR ASSY, ID = ?I 13-1/2" LNR, 8.81 #, L -80 STL, .0076 bpf, ID = 2.992" H 8427' I ■ I 8427' _1-13-1/2" X 3- 3/16" XO, ID = 2.786" I X e 11 8429' H 9 -5/8" X 7" GUIB PKR, ID = 3.833" I 8430' 1-17" X 4-1/2" X0, ID = 3.958" I 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" —1 8461' h CHEM CUT TBG (05/03/02) \ ti TOP OF 7" LNR I-1 8487' ( / " CSG, 47#, L-80 BTRS, ID = .6 1" 9 5 8 80 8 8 H 9007' 1 • 1 1 9533' H 7" MARKER JOINT 1 MILLOUT WINDOW (C -09A) 9594' - 9603' TOP F WHIPSTOCK (05/03/02) H 9593' 1 9693' H 3- 3/16" X 2 -7/8" XO, ID = 2.377"1 PBTD H 9865' 1'1V'1'1V'1'1 ; 9740' J I WRP ( 11 /19/11) I lit � 1 1 1 1 1 1 1 1 t1 1 1 1 1 , 17" LNR, 29 #, L -80 BTRS, .0371 bpf, ID = 6.184" I 9910' 1 1 11� 0 1 1, / 1 1 1 1 � 40 ••>�11 Gt0e 10100' — 2 .23 "WFDCIBP w ■ iii Np (12/13/08) PERFORATION SUMMARY 4,4. �1.4,0 REF LOG: MCNL ON 05/13/02 1/ ANGLE AT TOP PERF: 53° @ 9695' 3- 3/16" LNR, 6.2 #, L -80 TCII, -1 9693' I Note: Refer to Production DB for historical pert data .0076 bpf, ID = 2.80" =`, SIZE SPF INTERVAL Opn /Sqz DATE I PBTD I 10525' ••■■■■■ 1.56" 4 9692 - 9702 O 11/18/11 2" 6 9835 - 9895 O 06/17/06 2 -7/8" LNR, 6.16 #, L -80 STL, —I 10560' • 2" 6 9958 - 9983 O 12/14/08 2" 4 10152 - 10450 C 05/14/02 .0055 bpf, ID = 2.38" DATE RE/ BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/79 ? ORIGINAL COMPLETION 12/12/08 RLM/PJC DRAWING CORRECTIONS WELL: C-09A 05/14/02 N3S CTD SIDETRACK 01/12/09 RMH/SV SET CIBP /ADPERF (12/13/08) PERMIT No: 2020940 09/14/03 CMO/TLP REF LOG ADDITION 12/16/11 SRD/ PJC WRP/ PERFS (11/18 - 19/11) API No: 50- 029 - 20366 -01 06/17/06 DAV /PJC PERFORATIONS SEC 19, T11N, R14E, 886' SNL & 1223' WEL 04/29/07 JLJ/TLH 3 -1/2" XXN PLUG SET (04/19/07) 05/12/07 BSE/PAG PULL 3 -1/2" XXN PLUG @ 8396' BP Exploration (Alaska) . TREE = 6 -3/8" OCT WELLHEAD = OCT • SAO NOTES: C _0 9 B ACTUATOR = OTIS KB. ELEV = 62.48' proposed CTD sidetrack • BF. ELEV = 33.7' KOP= 2800' Max Angle = I7 @ 10560' 20" CONDUCTOR H 110' O 1982' — 17" SSSV OTIS LANDING NIP, ID = 5.962" Datum MD = 9550' Datum TVD = 8800' SS 2601' H 9 -5/8" DV PKR 13 -3/8" CSG, 72 #, L -80 BTRS, ID = 12.347" —1 2660' I 1 Minim, 2.377" @ 10500' 3 -1/4" X 2 -7/8" XO 22° - 8385 H 3 -1 /2" BKR DEPLOY SLV, ID = 3.00" i - 8400 —1&1/2" HES XN NIP, ID = 2.75" 17" TBG, 26 #, L -80 AB- IJ -4S, .0383 bpf, ID = 6.276" H_ - 8400' 8406' - - 1 7" PBR ASSY, ID = ? 13-1/2" LNR, 8.81#, L -80 STL, .0076 bpf, ID = 2.992" — f J — i 3-1/2" X 3-1/4" XO 8429' —19-5/8" X 7" GUIB PKR, ID = 3.833" 8430' H 7" X 4 -1 /2" XO, ID = 3.958" 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 8461' CHEM CUT TBG (05/03/02) ti ITOP OF 7" LNR —1 8487' — Top of cement at -8750' 9 -5/8" CSG, 47 #, L -80 BTRS, ID = 8.681" H 9007' 3 -1/4" x 2 -7/8" XO @ 10,500' TSGR = 9,136' MD 21 0 \__L-______z/ 4 -1/2" x 7" TT whipstock © 9,325' 2 -7/8" TD @ 11,650' • 9533' I--{ MARKER JOINT 3- 3/16" CIBP to abandon perfs @ - 9,450' TOP OF WHIPSTOCK (05/03/02) H 9593' 9693' H3 X 2 -7/8" XO, ID = 2.377" MILLOUT WINDOW (C -09A) 9594' - 9603' hillikk.. 1 ►'�9'i'�'�'�'1�/ 9740' WRP (11 /19/11) I PBTD I — 9865' �������� 7" LNR, 29 #, L -80 BTRS, .0371 bpf, ID = 6.184" H 9910' 1 • � • � • ■ ∎∎• � • � • � • 00)0*. ` 10100' — 2.23 " WFDCIBP iiit i� (12/13/08) PERFORATION SUMMARY .j�j��� .0.44. REF LOG: MCNL ON 05/13/02 lir ANGLE AT TOP PERF: 53° @ 9695' 3- 3/16" LNR, 6.2 #, L -80 TCII, H 9693' 1 Note: Refer to Production DB for historical pert data 0076 bpf, ID = 2.80" �= SIZE SPF INTERVAL Opn /Sqz DATE PBTD 10525' ■■• 1.56" 4 9692 - 9702 O 11/18/11 2" 6 9835 - 9895 O 06/17/06 2" 6 9958 9983 O 12/14/08 2 -7/8" LNR, 6.16#, L -80 STL, 10560' 2" 4 10152 - 10450 05/14/02 .0055 bpf, ID = 2.38" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/79 ? ORIGINAL COMPLETION 12/12/08 RLM/PJC DRAWING CORRECTIONS WELL: C-098 05/14/02 N3S CTD SIDETRACK 01/12/09 RMH/SV SET CIBP /ADPERF (12/13/08) PERMIT No: '020940 09/14/03 CMO /TLP REF LOG ADDITION 12/16/11 SRD/ PJC WRP/ PERFS (11/18- 19/11) API No: 50- 029 - 20366 -01 06/17/06 DAV /PJC PERFORATIONS '12 WJH proposed CTD sidetrack SEC 19, T11 N, R14E, 886' SNL & 1223' VVEL 04/29/07 JLJ/TLH 3 -1/2" XXN PLUG SET (04/19/07) 05/12/07 BSE/PAG PULL 3 -1/2" XXN PLUG @ 8396' BP Exploration (Alaska] • NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM • V12 V14 Ilk 7 IgA .1118" 5000 psi BOP's ID • 7.06" V15 V11 17 1/18" moo psi, RX Transducers ® nIIII 1 •OR BO 1 V V2 I V7 V 16 —Bi 4. GASSE' • Note. typical BOP 41.1 arrangement for 28R" .1 coiled tubing drilling '` I 71/18" 5000 psi, RXIB 111 V17 HCR I IC 4---- IK OK ';.. To Poor Boy Gas Buster ........110" V18 V79 I zvl(••sooe P•i. Rx -z/ • I 3.00 "6000 psi 11CR I � ■ ■ 11 r � 3- 1/18' 3000 VALVE PSi CHECK I 1 1 Mr - Manual Choke NA ......1 � 7 vu Cameron Fov Gate X 6000 psi I it l ir — MEOH /Diesel ® t— P Line CoFlex Hose = - 114 Turn Halco 10WOG To Production Tree or Cross Over • 4 • T - 11.. a transducers CoFlex Hose N11 0 0 0112 To Coiled Tubing Bleed Off — — Inner Reel Valve 0/13 Cem Line In Ground ent Level Tie -in I N10 s =< -1 -J CV3 CV2 T Stand Pipe -- Ali _^— _ ".. _ _ _ _ _ _ I.' Manual Choke ... _--_ - T' - -- —_ � -'— _ � _ Pressure Transducers - - = I -I I Motion 0 f 1 DV,7 � = MVP CV1 �� w Choke ■ N8 1 I Tiger Tank ••• Mud Pump II In F O 8 iC4 _ silk = i Baker MP 6MP2 IOW ® Q-- 0 CV14 to Pits 1 Rig Floor t Mud Pump #1 4 CV16 Reverse di - ' ∎.• 1:2) _�- Cir CT while OOH II alM O q 0 • To Manifold CV15 1- Jun -2010 4 Rawer.. rir...Amine gee / Cr While mils CoFleo 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 . 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). ;.. 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 202 - ° DATE: 2- May -12 Stephanie Pacillo TRANS#: 6100 ;y Data Delivery Services Technician Makana K Bender ScbiumbergerOilfield Services v% ` ' Natural Resources Technician II Data & Consulting Services t'' J sh :a Oil & Gas Conservation C , _ m?..... i o _ . �,a 2525 Gambell St, Ste. 400 � 7 - 'S); _ : 1- F - - - - - Anchorage, AK 99503 #� MAY 2 2 2012 it Office: (907) 273 -1770 W , ., WEL SERVICE OH RES ERV CNL MECH LOG DESCRIPTI ON DATE B/W COLOR ELECTRONIC 0 _.. . NAME ORDER*, DIST , DIST LIST OW LOGGED PRINTS ' . : ' �Q 04 -350 BX69 -00010 - X HILT MICROLOG 8- Nov -11 1 1 04 -350 BX69 -00010 X SONIC SCANNER 8- Nov -11 1 1 04 -350 BX69 -00010 X _MAST- ABC -CBL _ 6- Nov -11 1 1 04 -350 BX69 -00010 X HNGS -ABC 6- Nov -11 1 1 04 -350 BX69 -00010 X ELEMENTAL CAPTURE SPECTi 8- Nov -11 1 1 04 -350 BX69 -00010 X HIGH RES LATERLOG ARRAY 8- Nov -11 1 1 04 -350 BX69 -00010 X _ FULLBORE MICRO IMAGER 8- Nov -11 1 1 04 -350 BX69 -00010 X SCMT 17- Feb -12 1 1 04 -350 BYS4 -00006 X USIT 16- Nov -11 1 1 C -09A BX69 -00032 X SCMT 14- Apr -12 _ 1 1 06 -07 C2EW -00004 X PRODUCTION PROFILE _ 7- Apr -12 1 1 W -30 BINC -00100 X PRODUCTION PROFILE 1- Apr -12 1 1 04 -23A BBSK -00091 X (PROF ` 26- Aug -11 1 1 S -110A BBSK -00109 X USIT 13- Feb -12 1 1 ID M -23 BBSK -00111 X - CROSSFLOW LOG 3- Apr -12 1 1 L -214A BAUG -00116 X MEMORY INJECTION PROFILE 6- Apr -12 1 1 L -210 BAUJ -00115 X _ MEMORY INJECTION PROFILE 5- Apr -12 1 1 04 -350 BX69 -00010 X HNGS 8- Nov -11 1 1 X X Please return a signed copy to: Please return a signed copy to: BP PDC LR2 -1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd Anchorage AK 99503 Anchorage AK 99508 TE OF ALASKA • ALASKA OIL ANDS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations III Stimulate El Other ❑ Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development la Exploratory ❑ • 202 -0940 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 , 50- 029 - 20366 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028305 • PBU C -09A 10. Field /Pool(s): • PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10560 feet Plugs (measured) 9739, 10100 feet true vertical 9041.51 feet Junk (measured) None feet Effective Depth measured 10520 feet Packer (measured) 2601 8429 feet true vertical 9044.67 feet (true vertical) 2601 7819 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 91.5# H -40 35 - 110 35 - 110 1490 470 Surface 2626' 13 -3/8" 72# L -80 34 - 2660 34 - 2660 4930 2670 Intermediate 8974' 9 -5/8" 47# L -80 33 - 9007 33 - 8357 6870 4760 Production 1107' 7" 29# L -80 8487 - 9594 7873 - 8904 8160 7020 Liner 40' 3 -1/2" 8.81# L -80 8387 - 8427 7780 - 7817 10160 10530 Liner 1266' 3- 3/16" 6.2# L -80 8427 - 9693 7817 - 8984 Liner 867' 2 -7/8" 6.16# L -80 9693 - 10560 8984 - 9042 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - True Vertical depth: _ — — — Tubing: (size, grade, measured and true vertical depth) 7" 26# L -80 31 - 8429 31 - 7819 4 -1/2" 12.6# L -80 8429 - 8461 7919 - 7848 Packers and SSSV (type, measured and true vertical depth) 9 -5/8" DV Packer 2601 2601 7" Guiberson Polar Packer 7819 RFCEP 12. Stimulation or cement squeeze summary: R �" ;� ?t Intervals L Intervals treated (measured): r a Eons. CorevrissWWf Treatment descriptions including volumes used and final pressure: al 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 546 33,011 33 939 Subsequent to operation: 641 32,213 73 966 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory El Development 0 - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ID Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSPO SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na r = •.e Lastu Title Petrotechnical Data Technologist Signatu Phone 564 -4091 Date 12/13/2011 /L •/G •6/ Form 10 -404 Revised 10/2010 RBDMS DEC 16 2011 Submit Original Only C -09A 202 -094 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C -09A 5/14/02 PER 10,152. 10,450. 9,028.25 9,038.14 C -09A 6/17/06 APF 9,835. 9,895. 9,029.51 9,032.3 C -09A 12/13/08 BPS 10,100. 10,152. 9,029.64 9,028.25 C -09A 12/13/08 PER 9,973. 9,983. 9,030.51 9,030.14 C -09A 12/14/08 PER 9,958. 9,973. 9,031.04 9,030.51 C-09A 11/18/11 APF 9,692. 9,702. 8,982.93 8,988.68 C-09A 11/19/11 BPS 9,739. 10,100. 9,005.51 9,029.64 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE • MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE 1111 • • C -09A DESCRIPTION OF WORK COMPLE NRWO OPERATIONS EVENT SUMMARY 11/18/2011'*** WELL SHUT -IN ON ARRIVAL * ** (E -LINE ADPERF / SET WRP) INITIAL TWO = 2400/100/0 PSI !GUN INFO: 1.56" 1606 POWERJET HMX 4SPF, 10', TIE- IN TO SLB MCNL 08- i SEP -2002 CCL TO TOP SHOT = 3.3' PFRFC)RATED INTERVAL = 9692' -9702' FINAL TWO = 2500/100/0 PSI ***WELL SHUT -IN UPON DEPARTURE * ** 1i/19/2011 ' T/1/0=2300/100/0 Temp =SI Assist E -line setting WRP (ADPERFS) Standby to assist E -line. Pumping not required, no fluids pumped. RDMO. FWHP's= 2300/100/0. E -line in control of well at departure. 11/19/2011 * ** WELL SHUT -IN ON ARRIVAL * ** (E -LINE JOB CONTINUED FROM 11/18/11) INITIAL T /I /O = 2400/100/0 PSI WEATHERFORD 2.25" WRP PLUG SET AT 9740', TIE -IN TO SLB MCNL 08 -SEP- ,2002 FINAL T /I /O = 2400/100/0 PSI * ** WELL SHUT -IN UPON DEPARTURE ** *(JOB COMPLETE) FLUIDS PUMPED BBLS 2 DIESEL 2 TOTAL WELLHEAD = 6-3/8" OCT SAFETY NOTES: 0 I OCT ACTUATOR = OTIS 4I b - O 9A KB. ELEV = 62.48' BF. ELEV = 33.7' KOP = 2800' Max Angle = 97 @ 10560' 120" CONDUCTOR H 110. M 1 1 1982' H7" SSSV OTIS LANDING NIP, ID = 5.962" 1 O Datum MD = 9559' Datum TVD = 8800 SS 2601' H9-5/8" DV PKR1 1 13-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 1-1 2660' Minimum ID = 2.377" @ 9693' 3-3/16" X 2-7/8" XO 8387' H3-1/2" BKR DEPLOY SLV, D = 3.00" 1 • I 1 8396' H31/2" HES XN NIP, ID = 2.75" 1 1 17" TBG, 26#, L-80 AB-U-4S, .0383 bpf, ID = 6.276" H — 8400' — 1 8406' H7" PBR ASSY, ID = 71 13-1/2" LNR, 8.81#, L-80 STL, .0076 bpf, ID = 2.992" 1-1 8427' 1 , , ----1 8427' H3-1/2" X 3-3/16" X0, ID = 2.786" 1 .3 1 8429' H9-5/8" X 7" GUIB PKR, ID = 3.833" 1 ■ ...." --1 8430' 1 X 4-1/2" X0, ID = 3.958" 1 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" —1 8461' 1............... CHEM CUT TBG (05/03/02) ".• .... I TOP OF 7" LNR 1-1 8487' 1 — s I 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" H 9007' 1 • i■ 1 1 9533' H7" MARKER Jana I MILLOUT WINDOW (C-09A) 9594' - 9603' 1TOP OF WHIPSTOCK (05/03/02) H 9593' 1 9693' 1 X 2-7/8" XO, ID = 2.377" ■AVAN4 PBTD 1 9865' ■••0 044**** 10100' — 12.23" WFD CIBP (12/13/08) 1 1.0004 1 7" LNR, 29#, L BTRS, .0371 bpf, 0= 6.184" 1 - 1 9910' rAWOW■ 1 .0.0.....at PERFORATION SUMMARY 4 11 4 0 Ar REF LOG: MCNL ON 05/13/02 3-3/16" LNR, 6.2#, L-80 TCII, — 9693' 21■.. ANGLE AT TOP PERF: 83 @ 9835' .0076 bpf, ID = 2.80" Nimil.. Note: Refer to Production DB for historical perf data 1 PBTD 1 10525' 'N1127 SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9835 - 9895 0 06/17/06 2-7/8" LNR, 6.16#, L-80 STL, — 10560' 2" 6 9958 - 9983 0 12/14/08 .0055 bpf, ID = 2.38" 2" 4 10152 - 10450 C 05/14/02 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/12/79 ? ORIGINAL COMPLETION 12/12/08 RLM/PJC DRAWING CORRECTIONS WELL: C-09A 05/14/02 N3S CTD SIDETRACK 01/12/09 RMH/SV SET CIBP/ADPERF (12/13/08) PERMIT No: 020940 09/14/03 CMO/TLP REF LOG ADDITION API No: 50-029-20366-01 06/17/06 DAV/PJC PERFORATIONS SEC 19, T11N, R14E, 886' SNL & 1223' WEL 04/29/07 JLJ/TLH 3-1/2" XXN PLUG SET (04/19/07) 05/12/07 BSEPAG PULL 3-1/2" XXN PLUG @ 8396' BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 ,A0i,Mt0 7 . RECEIVED/ D/ _flf Mr. Tom Maunder *AB ii( & 6 r" Alaska Oil and Gas Conservation Commission •',�ct:ar� 333 West 7 Avenue Anchorage, Alaska 99501 6/9- Subject: Corrosion Inhibitor Treatments of GPB C -Pad O/, Dear Mr. Maunder, jj 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 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 _ ~ V~~~ ~f~Jl T~4f~S11~1/TEAL ._ , . 4 _-_._, - - ----~ ProActive Diagnostic Services, Inc. Ta: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hoie/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTV 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. Petratechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 26 ~-O~; Ca ~~ 3G/ and j~3 -pc~g 1-343 I~1Fctnre'fliagp~astic S~hvi~es, Inc. , . At~n~ Rotaept ~A. whey 130 West International Ai rt Road ~, ` ~ i ; . <. Anchorage, AK 99518 Fax: (907) 245-8952 1 j Coil Flag 12-Dec-08 C-09A 2j Leak Detection - WLD 12-Dec-08 Y-16 Signed Print Name: EDE 1 Color Log / EDE Date 50-029-20366-01 50-029-20932-00 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL : ~d~~a~chsarSg~rtaera~orvlog.as~ WEBSITE : ~nrvEN.r~asrra~ryleel.~~rn C:\Documenls and Settings\Owna\Desktop\Transmit_BP.docx ` ~ • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON REPORT OF SUNDRY WELL OPERATIONS /,s?-/~p 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate ~ - Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development - Exploratory 2o2-o9ao 3. Address: P.O. Box 196612 StratigraphiC 1~~ Service 6. API Number: Anchorage, AK 99519-6612 50-029-20366-01-00' 7. KB Elevation (ft): 9. Well Name and Number: 62.5 KB PBU C-09A 8. Property Designation: 10. Field/Pool(s): , ADLO-028305 ,. PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10560 ~ feet Plugs (measured) 10100' 12-13-08 true vertical 9041.51 - feet Junk (measured) None Effective Depth measured 10520 feet true vertical 9044.67 - feet Casing Length Size MD TVD Burst Collapse Conductor 75 20"91.5# H-35411003 35 - 110 35 - 110 1490 470 Surface 2626 13-3/8" 72# L-80 34 - 2660 34 - 2660 4930 2670 Production 8974 9-5/8" 47# L-80 33 - 9007 33 - 8357 6870 4760 Liner 1108 7" 29# L-80 8487 - 9595 7873 - 8905 8160 7020 Liner 40 3-1/2" 8.81# L-80 8387 - 8427 7780 - 7817 10160 10530 Liner 1266 3-3/16" 6.2# L-80 8427 - 9693 7817 - 8984 8520 7660 Liner 867 2-7/8" 6.16# L-80 9693 - 10560 8984 - 9042 10570 11160 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR80 31 -8461 0 0 - Packers and SSSV (type and measured depth) 9-5/8" DV PKR 2601 9-5/8" GUIB PACKER 8429 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~T t~ ~ '~ ~~~~~ I~~ ~ ~t ~~ 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: 628 31852 40 1113 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development r ' Service f Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ - Gas r WAG ~ GINJ ~ WINJ ~ WDSPL 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 12/15/2008 -- -- ~-- - _, ~ I)t;- ,. su icy ~ ~~ C-09A 202-094 PERF OTTOC_NMFNT L~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-09A 5/14/02 PER 10,152. 10,450. 9,028.25 9,038.14 C-09A 6/17/06 APF 9,835. 9,895. 9,029.51 9,032.3 C-09A 12/13/08 BPS 10,100. 10,108. 9,029.64 9,029.47 C-09A 12/13/08 PER 9,973. 9,983. 9,030.51 9,030.14 C-09A 12/14/08 PER 9,958. 9,973. 9,031.04 9,030.51 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • ~~ i ~ C-09A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 12/11/2008'CTU # 6 1.75" CT, Scope; memory log/ adperf/ set CIBP. Rig up, simops, PJSM. *"''continued on WSR 12-12-08**" 12/12/2008~CTU #6 w/ 1.75" OD CT, Scope; drift/log/adperf/CIBP. MIRU. Perform weekly BOPE test. Pump 1.25" OD gauge ball -ball did not drift through coil, ball only made --13 wraps before stopping progression through coil. Reverse ball out of reel and recover ball in standing iron after 2 bbls away. Load 1.25" OD guage ball and reverse ball into coil. Ball travels through majority of coil before stopping progression through coil at approximately same place. Pump ball back to nozzle with 33 bbls, recover ball at nozzle. Drift entire reel with 7/8" OD ball, recover ball at nozzle. Confer with office, decide to complete this job then go back to the yard to remove damaged section from coil. MU and RIH with 2.25" OD DJN. Drift with 2.25" OD DJN, taa at 10332' ctmd; RIH w/ PDS memory gamma ray, ccl, pressure tools inside 2.2" carrier. ***continued on WSR 12-13-08"** 12/13/2008~CTU #6 w/ 1.75" OD CT. Scope; memory log/ CIBP/ adperf. **Continued from WSR 12-12-08*" cont RIH w/ PDS memory GR, CCL, pressure tools. Log from 10250' @ 40 fpm, paint flag 10050' and log up to 9650'. Pull to surface, confirm good data, make +17' correction to SLB MCNL 16-June-2006. RIH w/ 223" W-ford CIBP and set 10100' corrected de th (ref: SLB MCNL 16-June-2006). Pull to surface. MU and RIH with 2.0" OD x 10' perforating gun. Shoot 9973 to 9983. pooh. All shots fired. RIH w/ 2" x 15' pert gun. ***Continued on WSR 12-14-08*** 12/14/2008 CTU # 6 1.75" CT Scope; Adperf "''Continued from WSR 12-13- 08"* Continue RIH w/ 2' x 15' pert gun. Tag CIBP and correct depth. Pull up to target depth 9958-9973. Saw indication of guns firing. pooh. all shots fired. (see pert data section) Left well flowing. **job complete"* FLUIDS PUMPED BBLS 33 60/40 METH 33 TOTAL REC OCT I 0 2006 Sdllum~erger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth dö';; -09<1 ~ Oil l~ (ìa.,¡¡ Cons, NO. 3982 Aoohl:irage Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 it 141~~ Field: Prudhoe Bay Well Job# Loa DescriDtion Date BL Color CD 3-29/J-32 11414759 SBHP SURVEY 09/04/06 1 L4-10 11285941 MEM PROD PROFILE 09/15/06 1 L2-21A 11421023 LDL 09/11/06 1 C-18A 11285934 MEM PROD & INJECTION 07/29/06 1 Y-24 N/A INJECTION PROFILE 09/03/06 1 Z-31 11414379 INJECTION PROFILE 09/04/06 1 S-27B 11285940 MEM PROD PROFILE 09/14/06 1 P-13 11414277 INJECTION PROFILE 09/03/06 1 X-33 11421024 LDL 09/12/06 1 Z-19A N/A MDT 09/08/06 1 A-17 11414381 USIT 09/07/06 1 X-01 11422961 USIT 09/09/06 1 H-04A 11285942 SCMT 09/17/06 1 15-39A 11212888 SCMT 09/16/06 1 C-09A 11209608 MCNL 06/16/06 1 1 C-18A 11285934 MCNL 07/29/06 1 1 Z-14B 40013765 OH EDIT OF MWD/LWD 07/31/06 1 1 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth ~t.A~fi'\!fI} ~\;,'. 1, ?n fiR ""'" ¿ ~.~.~-- 1 0/06/06 . . I . R~¿ r)~ RECEIVED STATE OF ALASKA .- ALASKA OIL AND GAS CONSERVATION COMMISSION SEP 2 2 2006 REPORT OF SUNDRY WELL OPERA TION§a Oil & Gas Cons. Commission 1. Operations Performed: AnchoEPe Abandon 0 Repair WellO PluQ PerforationsO Stimulate 0 Other Alter CasingD Pull TubingD Perforate New PoolD WaiverD Time ExtensionD Change Approved Program 0 Operation ShutdownD Perforate IKI Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development [!] ExploratoryD 202·0940 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519·6612 StratigraphicD ServiceD 50·029-20366·01-00 7. KB Elevation (ft): 9. Well Name and Number: 62.50 C-09A 8. Property Designation: 10. Field/Pool(s): ADL-028305 Prudhoe Bay Field 1 Prudhoe Bay Pool 11. Present Well Condition Summary: Total Depth measured 10560 feet true vertical 9042.0 feet Plugs (measured) None Effective Depth measured 10525 feet Junk (measured) None true vertical 9044.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 75 20" 91.5# H-40 35 - 110 35.0 - 110.0 1490 470 SURFACE 2626 13-3/8" 72# L-80 34 - 2660 34.0 - 2660.0 4930 2670 PRODUCTION 8974 9·5/8" 47# L-80 33 . 9007 33.0 - 8357.0 6870 4760 LINER 1108 7" 29# L-80 8487 - 9595 7873.0 - 8905.0 8160 7020 LINER 40 3-1/2" 8.81# L·80 8387 - 8427 7780.0 - 7817.0 10160 10530 LINER 1266 3·3/16" 6.2# L-80 8427 - 9693 7817 .0 - 8984.0 8520 7660 LINER 867 2-7/8" 6.16# L-80 9693 - 10560 8984.0 . 9042.0 10570 11160 Perforation depth: SCANNED SEP 2 6' 2005 Measured depth: 9835-9895, 10152-10450 True vertical depth: 9030-9032, 9028·9038 TubinQ ( size. Qrade. and measured depth): 4-112" 12.6# 13Cr80 @ 31 - 8429 Packers & SSSV (type & measured depth): 9-5/8" DV Packer @ 2601 9-5/8" GUIB Packer @ 8429 7" SSSV Otis Landing Nip @ 1982 12. Stimulation or cement squeeze summary: Intervals treated (measured): iRI3DMS 8Ft SEP 2 {) 2006 Treatment descriptions including volumes used and final pressure: 13 Reoresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: SI _e. --- _.. 0 Subsequent to operation: 906 37,933 31 .-. 953 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilŒJ GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayne R. Schnorr Title Petroleum Engineer Signature A.?I-....,^ ¿¡? '¿r¡ -~ A I Phone 564-5174 Date 9/18/06 Form 10-404 Revise ur 1\Jll\lI\L . . , C~~ DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 07/10/2006 TestEvent --- BOPD: 855 BWPD: 35 MCFPD: 36,382 AL Rate: 06/18/2006 POOH, lay down gun #3. Blowdown reel. RIH wi N2 @ 400 scflm to 1000', 2000', 3000', 4000' & 5000', Pumped - 2100 gals N2 total. Monitor well for - 2 hrs with out N2. WHT = 108, WHP = 275 psi upon departure. Well turned over to PCC & pad operator. 06/17/2006 MU/RIH wi PDS GRlCCL in carrier for tie-in log. Log from TO to 9500'. Coil flag @ 9750'. Tie into CNL dated 9/8/2002. TO = 10343' md. MUlRIH wi guns 1, 2 & 3. Perforated interval from 9835' - 9895' wi 2" guns. POOH. 06/16/2006 Run drift wi 2.25" JSN. Tag high @ 10361' (ctm). Hard top tag, can't jet into it. POOH. Standby for mem logger. MUlRIH wi MCNL in carrier. Fluid pack well wi 503 bbl KCL. Reduce rate to 1.6 bpm, swap to diesel. Run 2 MCNL passes from TO @ 10356' to 9000' @ 60 fpm. On 2nd pass flag CT @ 9750'. POOH. Confirm good data. 06/15/2006 CTU #9 w/1. 75" CT. MIRU CTU #9. Perform weekly BOP test. MU Baker MHA and 2.25" JSN. Perform partial kill w/1 %KCL. RIH wi JSN. 06/07/2006 *** WELL SI ON ARRIVAL *** (pre ctu men I adperf) DRIFTED W/11' X 2" DUMMY GUN, STOPPED @ 9682' SLM ( 38 DEG. DOGLEG). *** PAD OP NOTIFIED, WELL LEFT SI *** FLUIDS PUMPED BBLS 28 Methanol Water 277 Diesel 1131 1 % KCL Water 2100 gallons N2 1436 TOTAL Page 1 I TREE = WELLHEAD = ACTUATOR = : S. ELEV = SF, ELEV = KOP= Max Angle - Datum MD = Datum TVD = 6-3/8" OCT OCT OTIS 62.48' 33.7' 2800' 97 @ 10560' 9550' 8800' SS C-09A 1982' 2601' 13-3/8" CSG, 72#, L-80, 10 = 12.347" I Minimum ID = 2.38" @ 9693' 3-3/16" X 2-7/8" XO I 7" TBG, 26#, L-80, .0383 bpf, 10 = 6.276" 4-112" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" CHEM CUT TBG (05/03/02) 3-1/2" LNR. 8.81#, L-80, .0087 bpf. 10 = 2,99" I TOP OF 7" LNR 8427' 8387' 8396' 8406' 8429' 8430' 9-5/8" CSG, 47#, N-80, 10 = 8.681" I I PBTO I 7" LNR, 29#, L-80. .0371 bpf, 10 - 6.184" I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, 10 = 2.80" 9865' ÆRFORA TION SUMMARY REF LOG: MCNL ON 05/13/02 ANGLEAT TOP ÆRF: 83 @ 9835' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 9835 - 9895 0 06/17/06 2" 4 10152 - 10450 0 05/14/02 2-7/8" LNR, 6.16#, L-80, .0055 bpf, 10 = 2.38" DA TE REV BY COMMENTS 10/12179 ORIGINAL COMPLETION 05/14/02 JLMIKA CTD SIDETRACK 09/14/03 CMO/TLP REF LOG AODrrlON 06/17/06 DAV/PJC ÆRFORA TIONS DA TE REV BY COMMENTS I SAFETY NOTES: -17" SSSV OTIS LANDING NIP, 10 = 5.962" - 9-5/8" OV A<R I - 3-1/2" BKR DEA..OYMENT SLY, 10 = 3.00" -13-1/2" HES XN NIP, 10 = 2.75" I - 7" PBRASSY, TOP I - 9-5/8" X 7" GUIB A<R, 10 = 3.833" I - 7" X 4-1/2" XOI - 3-112" X 3-3/16" XO, 10 = 2.80" I I MILLOUTWINDOW 9594 - 9601 9590' HTOPOF WHIPSTOCK WI RA TAG I 9693' H3-1/16" X 2-718" XO, ID = 2.38" , 10525' I --i 10560' I PRUDHOE BA Y UNrr WELL: C-09A ÆRMrr No: "2020940 API No: 50-029-20366-01 SEC 19, T11 N, R14E, 886' SNL & 1223' WEL BP Exploration (Alaska) . . , '," !:r·~.;··· ......~ .,:~" '.+ .¡o. : MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicbe\CvrPgs _ Inserts\Microfilm _ MaIker.doc ) S t) v+-~~- DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020940 Well Name/No. PRUDHOE BAY UNIT C-09A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20366-01-00 MD 10560 -- TVD 9042"" Completion Date 5/14/2002 <,,' Completion Status 1-01L -.------- ---~ ._--_._---~- REQUIRED INFORMATION Mud Log No Samples No ~---~---~ ------------.--- DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ~D- -C- ---------r11045 See Notes Log Log Run Scale Media No 1 to 2 ¡ Rpt : Log ¡-tog DirectionalSurvøy . Neutron Pressure ~~cti(maISurvey 25 Blu 25 Blu 25 Blu 25 Blu 2 Blu 25 Blu 2 Blu 25 Blu 25 Blu 2 Blu 2 Blu 1 to 2 ciftD i ¡ Log 58'- C D Production "1'''''380 Neutron . Log ¡ tog '1-og :,.Log : i keg (rog '.t6g I ¿,kóg .~ I nduction/Resistivity Spinner Temperature Temperature 1 to 2 I nduction/Resistiyîtý Spinner Pressure Neutron C '1-14 66 Neutron Well CoreslSamples Information: Name Interval Start Stop Received Sent 5pt.'vl fo~) ~l- Current Status 1-01L UIC N Directional Survey No (data taken from Logs Portion of Master Well Data Maint) Interval OH / Start Stop CH Received Comments 9585 10557 Open 9/13/2002 LDWG open hole edit of Anadrills MWD and Mad data -......,..../ 0 1 0560 Open 5/17/2002 8250 10510 Case 6/21/2002 9045 10515 Case 10/1/2002 0 10560 Open 5/17/2002 9045 10515 Case 10/1/2002 9065 1 0500 Case 12/10/2002 9580 10558 Open 9/13/2002 9045 10515 Case 12/10/2002 9045 10515 Case 10/1/2002 9045 10515 Case 12/10/2002 9580 10558 Open 9/13/2002 9045 10515 Case 10/1/2002 9045 10515 Case 12/1 012002 9045 10515 Case 12/10/2002 8250 10510 Case 6/21/2002 .~ Sample Set Number Comments DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020940 Well Name/No. PRUDHOE BAY UNIT C-09A Operator BP EXPLORATION (ALASKA) INC MD 10560 TVD 9042 Completion Date 5/14/2002 Completion Status 1-01L Current Status 1-01L UIC N Well Cored? ADDITIONAL INFORMATION Y/~ Daily History Received? fu/N ¿j/N Chips Received? Analysis Received? -----.------ Comments: -- ------ ------ ------- 'Y"'t-N--' Formation Tops ~. )~ Date: Compliance Reviewed By: API No. 50-029-20366-01-00 ~ J 1JVWLÀ.~ '1 ._~""- Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well C-09A F-08 J-09A d.Od.-oqt..J } -¡ Lj-Q 11 rQ1-00¡9 Job# Log Description Date 22459 MCNL 22461 RST 22470 MCNL 09/08/02 09/11/02 09/26/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: REr;Eï\V'~ ,~.--". V .. ~l) DEe; "I, 0 ?nC.-'S} '-.,; J 1- AJask j';~; ; -, - ~a u, & Gas G"ns r' w. . . ¡.¡ . LOu:mlSSion Anchorage Blueline NO. 2577 Company: 12/04/02 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Re¿~ CD '--~/ ~- (L~J Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well GNI-01 Jti7, d '3 'ð D.S.16-25 19d -05/ NK-42 / 'i Y-I ng D.S. 9-01 l 7 ß -- n7fp P2-32 I <j :J.., '3 ~ C-09A q~_n ql.../ D.S. 7-30 I -- 0 I 9 X-23 4-00' D-24 J 5-dCf'1 D.S. 14-23 J -oRì D.S.14-32 I g5- J ð ~ Job# TEMP/PRESS SURVEY PROD PROFILE/DEFT GLS PROD PROFILE/DEFT GLS MEM PROD PROFILE LDL INJECTION PROFILE LDL 22383 RST -SIGMA 22384 RST -SIGMA 09/26/02 NO. 2444 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Sepia Prints CD 09/11/02 1 09/09/02 1 09/10/02 1 09/10/02 1 09/01/02 1 09/08/02 1 09/06/02 1 09/02102 1 09/10/02 1 07/09/02 1 07/20/02 1 Log Description PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: RECE'VED OCT 0 1 2002 Ala8k8 art 1& ü8I Cons. COIIDI.aDl AndøIge ~ .,-,," Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage. AK 99503-5711 ATTN: Beth ReceiV~~ ) Sc~lulBblPgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ,.-..... Well C-09A do d-QqL/ C-09A ( C-09A ...v D.S.14-02B I q 3-~no D.S. 14-05A q ~ -00 I H-18 J ~à- ~J Ï) .~ BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 22260 22260 22260 22379 22380 Log Description Date OH EDIT MWD & MAD DATA MD VISION RESISTIVITY TVD VISION RESISTIVITY RST-SIGMA RST-SIGMA LEAK DETECTION 05/12/02 05/12/02 05/12/02 07/04/02 07/06/02 09/04/02 RECEIVED SEP 1 3 2002 Alaska 0;': & Gas Cons. Commission Anchorage Blueline 09/11/02 NO. 2409 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Wee pie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints CD Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Receive&~ Sc~lunJblpuer Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth ,---~ Well Job # . C-D9A ~Q~-O qLJ D.S.1-28 J Xlr,-09 ~ . A-38L1 PB1 ~f)~-n'ilJ ø A-38L 1 PB1 ø A-38L 1 PB1 , A-38L 1 I A-38L 1 I A-38L 1 Log Descñption Date 22259 MCNL (PDC) 22225 RST-SIGMA 05/13/02 04/24/02 22261 GR & ROP5 DATA 22261 MD SLlMPULSE-GR 22261 TVD SLlMPULSE-GR 22262 SP ARC DATA 22262 MD VISION RESISTIVITY 22262 TVD VISION RESISTIVITY 04/27/02 04/27/02 04/27/02 05/07/02 05/07/02 05/07/02 ~ r---. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED JI !\! 2 1 ')no? vi ¡ I Lv - Alaska Oil & Gas Cons. CorrIIJ1Ision Anchorage Blueline 06/12/02 NO. 2149 Company: State of Alaska Alaska Oil & Gas Cons Comm Aftn: Lisa Weeple 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Pñnts CD Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 AlTN: Sherrie Receìve~0ilao~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 202-094 3. Address 8. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20366-01 4. Location of well at surface f"ëõMijC0ïóNl ,,\O\.'WA,_~~~.~' 9. Unit or Lease Name 885' SNL, 1223' WEL, SEC. 19, T11 N, R14E, UM DATE ... I' ,"'t.()CA~t Prudhoe Bay Unit At to,P of produ~tive interval 13,;;'liJ' 0'2 I '~~" . ,,¡;~ 3~~~0~~àe~~0 WEl, SEC. 19, T11 N, R14E, UM ~ VEFU, ~IED ~, f,'," ,,', ,,'-, "",.. .;",':~, 1 O. Well Number 4244' SNl, 1060' WEl, SEC. 19, T11N, R14E, UM ¡, ¿~",~,J ~9.~, 0" ''',',~~~,,~, C-09A 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Seri~rNò:. , 11. Fþ~~~~~ ~~~I Field / Prudhoe Bay Pool KBE = 62.5' ADl 028305 12. Date Spudded 13. Date T.D. Reached 14. Date ComPJ'~usp., or Aband. 5/10/2002 5/12/2002 5f1.G;2002 þð 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10560 9042 FT 10520 9045 FT 181 Yes 0 No 22. Type Electric or Other logs Run MWD, GR, RES, Memory CNL, CCl Classification of Service Well 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 1982' MD 1900' (Approx.) 7" 3-1/2" x 3-3/16" x 2.7/8" WT. PER FT. Insulated 72# 47# 29# 8.81# /6.2# 6.16# GRADE Conductor L-80 L-80 L-80 L-80 CASING, liNER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE CEMENTING RECORD Surface 110' 36" 12.9 cu yds Permafrost Concrete Surface 2660' 17-1/2" 4147 cu ft Arcticset II Surface 9007' 12-1/4" 1227 cu ft Class 'G', 130 cu ft AS 8487' 9595' 8-1/2" 396 cu ft Class 'G' 8373' 10560' 3-3/4" 79 cu ft Class 'G' AMOUNT PULLED 23. CASING SIZE 20" X 30" 13-3/8" 9-5/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 10152' - 10450' 9028' - 9038' 25. TUBING RECORD SIZE DEPTH SET (MD) 7",26#, l-80 8429' 4-1/2", 12.6#, l-80 8461' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH PACKER SET (MD) 8429' MD TVD 27. Date First Production May 19, 2002 Date of Test Hours Tested 6/11/2002 4 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 820 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL-BBL GAs-McF 20,402 GAs-McF WATER-BBL 32 WATER-BBL CHOKE SIZE 95.53° OIL GRAVITY-API (CORR) 26.8 GAS-OIL RATIO 24,870 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water.RtCl: IV' E D No core samples were taken. 28. ¡II'! .f f. r¡nl"? U'¡\i ¡Ii /" ¡. 'I.., ¡ \I ~t '-...\./_. Form 10-407 Rev. 07-01-80 () ~\,.,.,/ ~ 1'\ 6 n L ~ 1.\ :,: 1\ r :, \ t /,.,\ u ~ \J I \ Alaska Oil & Gas Cons. L;OlHlIII~S Of¡ Ar.cho fa i) P '1 ij nMS B F l JUN I 9 $~mit In Duplicate ~ F ) ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 2A 9720' 89971 RECEI\IED j ¡ ¡ \! ..! , 11,' () n t~.'!" , ~ fi ¡" , , '., uJ l' I ""k t..Uld.. AJaska on & Ga8 Cons. GonmliSSiŒ: Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certif.Y that the for:9°in~ is t~ui. ad1::lct to the best of my knowledge Signed Terne Hubble /f~ ~ Title Technical Assistant C-09A 202-094 Well Number Permit No. / Approval No. Date oto.{q.O~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). 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 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ntJPLI CATE ') ) BP EXPLORATION Operations Summary Report Page 1 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-09 C-09A REENTER+COMPLETE NABORS NABORS 3S Start: 5/8/2002 Rig Release: 5/15/2002 Rig Number: Spud Date: 6/25/1979 End: 5/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/812002 00:00 - 20:00 20.00 RIGU P PRE MIRU. Accept rig 15:30 5/8/02. NU BOPE. Continue to RU. 20:00 - 00:00 4.00 BOPSURP DECOMP Test BOPs. test witness waived by John Crisp AOGCC. 5/9/2002 00:00 - 04:30 4.50 BOPSUR P DECOMP Test BOP's. 04:30 - 05:00 0.50 BOPSUR P DECOMP RU lubricator to pull TWC. 380 psi on wellhead. 05:00 - 05:30 0.50 KILL P DECOMP Bleed off pressure. 05:30 - 06:00 0.50 KILL P DECOMP PU cementing nozzle, 2 joint PH-6,disconnect. 06:00 - 06:30 0.50 KILL P DECOMP Safety meeting. Pressure has built back to 200 psi. 06:30 - 07:30 1.00 KILL P DECOMP Bleed pressure. Fill hole. 80 bbls to catch pressure, then 3.0 BPM and 70 psi. 07:30 - 08:30 1.00 PXA P DECOMP MU cementing BHA 08:30 - 11 :00 2.50 PXA P DECOMP RIH circulating with nozzle. At 4000', started getting some gas in. Circulate to tiger tank on choke. 11 :00 - 11 :30 0.50 PXA P DECOMP Tag whipstock pinch point 9598' CTM. Correct to 9593'. Stack 5k. Check losses. 3.0 BPM in and barely a trickle back. MMout is acting goofy, but visibly returns are slight. 11 :30 - 12:00 0.50 PXA P DECOMP Safety meeting with cementers. 12:00 - 14:15 2.25 PXA P DECOMP While pumping across top to keep hole full (2.5 BPM in and 0.5 PBM out), mix and load 21 bbls 13.8 ppg bentornite cement into coil: 5 bbls neat, 10 bbls with 16 ppb agrregate, 6 bbls neat. Switch Nabors to coil and bullhead cement to perfs at 3.0 BPM. Slight bump in WHP with lead of aggregate at perfs. With 14 bbls (of 21 bbls total) squeezed behind pipe, WHP only at 100 psi. Bleed to zero and lay in remaining cement 1: 1 at FOC. Pull to safety. Squeeze to 200 psi -- held. Squeeze to 400 psi -- held. Squeeze to 1000 psi -- held for a couple minutes, then broke to 800 psi, stabilized for a few seconds, broke to 600 psi, stabilized, then broke to 300 psi -- held here. Only have 1 - 2 bbls of cement above perfs to play with. Call it good. Wash down to pinch point with bio water. 14:15 - 16:30 2.25 PXA P DECOMP POOH. Getting one for one all the way out. 16:30 - 17:00 0.50 PXA P DECOMP LD nozzle. 17:00 - 18:00 1.00 STWHIP P WEXIT Rehead. Pull and PT. MU motor, string mill, and diamond whipstock mill. 18:00 - 19:10 1.17 STWHIP P WEXIT RIH. 19:10-00:00 4.83 STWHIP P WEXIT UP wt 45,000 FS 2.7 bpm = 1200psi. Tag whipstock pinch point at 9595'. Mill to 9598.2' 5/10/2002 00:00 - 05:00 5.00 STWHIP P WEXIT Continue to time mill 2.8/2.8 bpm 1700 -1900 psi. Mill to 9605'. FS 1200psi. Cuttting indicate we milled thru collar. Milling fluid 2#/bbl Bio. 05:00 - 05: 13 0.22 STWHIP P WEXIT Back ream thru window. Pulled 26K over at 9,588'. Subsequent passes cleaned up. 05: 13 - 08:00 2.78 STWHIP P WEXIT Mill formation 9602.5' to 9612'. Swap well to Flo-Pro. Ream and backream window clean. Dry tag clean. Window 9,595' to 9,602.5' corrected. 08:00 - 09:00 1.00 STWHIP P WEXIT Overpull with stall at 9585' up (about 9589' down). About same spot as before. Work area. Seeing a little motor work here. Cleaned it up. Pump 30 bbls of -150k LSRV pill. 09:00 - 12:00 3.00 STWHIP P WEXIT POOH. 12:00 - 12:30 0.50 STWHIP P WEXIT LD BHA. Mills in gage, generally normal wear. 12:30 - 13:30 1.00 DRILL P PROD1 MU drilling BHA (BHA #3): M09 bit, 2.77 deg motor, TORC orienter. 13:30 -15:15 1.75 DRILL P PROD1 RIH. Shallow test good. 15:15 -15:45 0.50 DRILL P PROD1 Log tie-in at 9390' double gamma spike. Correct depth (-1'). Printed: 5/20/2002 3:15:48 PM ') ) BP EXPLORATION Operations Summary Report Page 2of4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-09 C-09A REENTER+COMPLETE NABORS NABORS 3S Start: 5/8/2002 Rig Release: 5/15/2002 Rig Number: Spud Date: 6/25/1979 End: 5/19/2002 Hours Task GÖclé NRT Dèscri ptiÒriof(JpérafiÖns 5/10/2002 15:45 - 18:00 2.25 DRILL P PROD1 18:00 - 19:25 1.42 DRILL P PROD1 19:25-21:16 1.85 DRILL P PROD1 21 :16 - 00:00 2.73 DRILL N DFAL PROD1 5/11/2002 00:00 - 00:20 0.33 DRILL N DPRB PROD1 00:20 - 01 :45 1.42 DRILL N DPRB PROD1 01 :45 - 04:00 2.25 DRILL N DPRB PROD1 04:00 - 04:30 0.50 DRILL N DPRB PROD1 04:30 - 05:30 1.00 DRILL N DFAL PROD1 05:30 - 08:00 2.50 DRILL P PROD1 08:00 - 08:45 0.75 DRILL P PROD1 08:45 - 11 :30 2.75 DRILL P PROD1 11:30-12:15 0.75 DRILL P PROD1 12:15 -13:00 0.75 DRILL N DFAL PROD1 13:00 -14:30 1.50 DRILL P PROD1 14:30 - 15:00 0.50 DRILL P PROD1 15:00 - 15:30 0.50 DRILL P PROD1 15:30-16:00 0.50 DRILL P PROD1 16:00 - 17:45 1.75 DRILL P PROD1 17:45-18:10 0.42 DRILL P PROD1 18:10 -18:30 0.33 DRILL P PROD1 18:30 - 19:29 0.98 DRILL P PROD1 19:29 - 22:24 2.92 DRILL P PROD1 22:24 - 23:30 1.10 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 5/12/2002 00:00 - 00:45 0.75 DRILL P PROD1 00:45 - 01:40 0.92 DRILL P PROD1 01 :40 - 02:26 0.77 DRILL P PROD1 02:26 - 02:43 0.28 DRILL P PROD1 02:43 - 03: 15 0.53 DRILL P PROD1 03:15 - 03:23 0.13 DRILL P PROD1 03:23 - 03:55 0.53 DRILL P PROD1 03:55 - 05:00 1.08 DRILL P PROD1 05:00 - 06:00 1.00 DRILL P PROD1 RIH clean thru window with 10R TF. Tag TD 9625' (why so deep?). Drill 2.6/2400 with high right TF. RA coming in at 9613' (vs 9600' expected based on whipstock setting records). Drill to 9669'. Depths got reset -- should be OK, but tie-in again to make sure.Correction -13.5'. Directionally drilled to 9712' 2.8/2.8 bpm 2800 psi 2640 psiFS PU 44000 SP 20000. Stopped drilling possible motor failure. Cannot stall, Clean pick-ups,Cannot get any motor work. POH POH Change out BHA #3. Bit balling. PU BHA#4 with resistivity. RIH. Shallow hole test at 3500 OK. RIH to 9425 Tie-in log. No Correction. Orient TORC wanted to continuously rotate. Numerous stop commands issued. Finally it stopped. Drill to 9824'. Stacking. Wiper to window. Pull heavy and stall 9605'. Btm of window? Drill to 10000'. Wiper to window. Orient. TORC not wanting to stop continuous rotation. Finally took stop command but struggle getting it to take a TF command. Drill to 10115'. Pump 15 bbl high vis pill. Stacking. Wiper to window. Pump another 15 bbl pill. Log tie-in. Correct depth (+4'). RIH. Hole clean. Drill. Slow from the start. Hit bottom hard and push negative weight. Can't get motor work. Acts like that white clay again balling the bit. Keep working bit. Cleaned up. Continue drilling. Drill to 10190'. Tough here again. Work bit. PUH. Can't get past 10118' (previous tough spot). Work past without pumps. Continue drilling from 10190' to 10,207' 2.7/2.7 bpm 2600psi FS= 2450 psi PU 51,000 Stacking continues to be problem. We seem to be able to wipe out the tight spots but get additional ones with the new hole. Increasing Kia Gard to 8#/bbl and lubtex t03%. Wiper trip 528'. Directionally drill to 10,301'. Stacking continues to be a problem. Wiper trip 625'. Directionally drill to 10,350'. Stacking. PU for survey. Directionally drill 2.7/2.7 bpm 2640 psi. to 13,388'. Stacking Wiper trip 758' Directionally drilling 2.7/2.7 bpm 2528 psi. to.1 0444 Stacking Survey Directionally drill @ 2.8/2.8 2640 psi. Drilled to 10460. Stacking Wiper trip Directionally drill to 10486' .Stacking Wiper trip. 867' Directionally drill to 10,515. @2.7/2.7 bpm 2500psi FS=2400 Printed: 5/20/2002 3: 15:48 PM ) ") BP EXPLORATION QperationsSummary Report Page 3 of 4 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-09 C-09A REENTER+COMPLETE NABORS NABORS 3S Start: 5/8/2002 Rig Release: 5/15/2002 Rig Number: Spud Date: 6/25/1979 End: 5/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 5/12/2002 05:00 - 06:00 1.00 DRILL P PROD1 psi. 06:00 - 08:00 2.00 DRILL P PROD1 Wiper trip. RIH. Starting at about 10120', RIH weight started dropping off considerably. By 10350', 5k RIH. By 10400', negative wt. Tough getting deeper. This is not a shale problem, but probably a hole configuration and tubign size issue. Eventually worked pipe to bottom, negative wt the rest of the way -- with a lot of cycling pipe and pumps. Unable to drill. Mix another drum of Lubetex in a 30 bbl pill (total of 7% lubetex). Pump it. Huge improvement in weight transfer. 08:00 - 08:45 0.75 DRILL P PROD1 Drill with about 10k positive weight and good ROP to 10550'. With pill out of open hole, lost all weight transfer and progress. 08:45 - 11 :00 2.25 DRILL P PROD1 Call for more Lubetex. Will do requested MAD pass now (for resistivity invasion profile), then decide if we want to drill further. Log up at 500 FPH, 2.8 BPM, 2500 psi CTP. 11:00-11:30 0.50 DRILL P PROD1 Pull to tie-in point. Log tie-in at 9392' GR spike. Correct depth (+9'). 11:30 -12:15 0.75 DRILL P PROD1 RIH. Some stacking off bottom, but better slide to bottom than before. Tag corrected TD 10560'. Asset content with calling this good -- objectives met. 12:15-16:15 4.00 DRILL P PROD1 POOH laying in new mud with 7% lubetex in open hole. POOH slowly at 3.0 BPM. 16:15 - 16:45 0.50 DRILL P PROD1 LD drilling BHA. 16:45 - 17:15 0.50 CASE P COMP Rehead with Baker CTC. Pull and PT. 17:15 - 18:00 0.75 CASE P COMP Move inj to back deck. RU to run liner. 18:00 - 18:15 0.25 CASE P COMP Crew change safety meeting. 18:15-22:15 4.00 CASE P COMP PU liner 22:15 - 22:40 0.42 CASE P COMP PU injector head and strip on to well. 22:40 - 00:00 1.33 CASE P COMP RIH with liner. 5/13/2002 00:00 - 00:20 0.33 CASE P COMP RIH 00:20 - 00:58 0.63 CASE P COMP Drop 5/8" ball and chase with 2%KCL. Landed at 43.7 bbl calculated 52.6 bbl. Released with 3400 psi. PU weight 36000 after release 53000 before release. 00:58 - 03:30 2.53 CASE P COMP Change well over to 2% KCL. 03:30 - 04:08 0.63 CEMT P COMP PJSM for cement job. 04:08 - 04:12 0.07 CEMT P COMP Pump 14.1 bbl cement. 04:12 - 04:20 0.13 CEMT P COMP Load dart and confirm launch. 04:20 - 05:12 0.87 CEMT P COMP Displace dart. Land and shear liner wiper plug with2900 psi @ 52.2 bbl (calculated 52.6bbl.) Bumped plug with 65.7 bbl.1bbl early. Pressure test floats1900 psi. Bleed off pressure pull off liner. 05:12 - 07:45 2.55 CEMT P COMP POH chasing bio pill out of hole. 07:45 - 08:30 0.75 CEMT P COMP LD CTLRT. 08:30 - 09:30 1.00 EVAL P COMP RU for memory CNUGR/CCL logging run in a flow thru carrirer and on 2-1/8" motor and 2.3 diamond mill. 09:30 - 10:00 0.50 EVAL P COMP Safety meeting. 10:00 - 14:30 4.50 EVAL P COMP MU logging tools, motor, mill. MU 70 jts of CSH. MU MHA. Stab inj. 14:30 - 15:30 1.00 EVAL P COMP RIH with logging tools. 15:30 - 17:00 1.50 EVAL P COMP Log down from 8250' at 30 FPM, 0.3 BPM, 1400 psi CTP. Tag and stall 1 0,480' CTM. PU. RIH at 1.5 BPM. Motor work for about 10', then clean. RIH and tag PBTD 10528' CTM. Repeat tags with and without pumps. No stall but no progress Printed: 5120/2002 3:15:48 PM ) ') BP EXPLORATION Operations Summary Report Page 4 of 4 Legal Well Name: C-09 Common Well Name: C-09A Spud Date: 6/25/1979 Event Name: REENTER+COMPLETE Start: 5/8/2002 End: 5/19/2002 Contractor Name: NABORS Rig Release: 5/15/2002 Rig Name: NABORS 3S Rig Number: Hours Task Code NPT Phase Description of Operations 5/13/2002 15:30 - 17:00 1.50 EVAL P COMP milling -- must be on LWP. 17:00 - 18:30 1.50 EVAL P COMP Log up at 30 FPM, laying in 20 bbl mud pill (5 buckets Flo-Vis in 20 bbls 2% KCL water -- about 120k - 150k LSRV). 18:30 - 19:45 1.25 EVAL P COMP POOH. 19:45 - 20:30 0.75 EVAL P COMP PJSM and strip off well. 20:30 - 21 :45 1.25 EVAL P COMP PJSM and stand back CS Hydril tubing. 21 :45 - 22:30 0.75 EVAL P COMP LD radio active source and logging tools 22:30 - 23:45 1.25 EVAL P COMP Process log data 23:45 - 00:00 0.25 EVAL P COMP Test liner lap to 2000 psi. 30 min OK 5/14/2002 00:00 - 00:15 0.25 EVAL P COMP Complete liner lap test 2000 psi for 30 min. Good Test. 00:15 - 09:15 9.00 PERF N COMP Standby while processing log data and waiting on perforators who are completing a job on Y pad. Load guns on pipe rack. 09:15 - 09:30 0.25 PERF P COMP Safety meeting -- perforating. 09:30 - 12:00 2.50 PERF P COMP MU 14 guns. MU 35 stds CSH. 12:00 - 13:45 1.75 PERF P COMP RIH. Tag 10,530' CTM. Correct -10' to 10520' (from CNL/GR/CCL). PUH hole to shooting depth. 13:45-14:30 0.75 PERF P COMP Circulate 5/8" ball to seat 2.5/3650. Slow down at 35 bbls (volume to seat = 56 bbls) to 1.4/1200. At 48 bbls, saw slight drop in CTP and 3,000 Ib increase in weight. Guns probably fired. Never saw ball land on seat and pressure up. This is only the second time SWS has seen this -- the first time was our last perf job (W-10a). Perforate 10152' - 10450'. 14:30 - 16:00 1.50 PERF P COMP POOH filling across top. 16:00 - 19:45 3.75 PERF P COMP LD CSH in singles. 19:45 - 20:00 0.25 PERF P COMP PJSM to Lay down guns. 20:00 - 22:00 2.00 PERF P COMP LD guns. All shots fired. 22:00 - 23:00 1.00 RIGD P COMP FP to 2000' wlmethanol. OOH 23:00 - 00:00 1.00 RIGD P COMP SetBPV 5/15/2002 00:00 - 01 :00 1.00 RIGD COMP Blow down coil with N2. 01 :00 - 04:00 3.00 RIGD COMP Rigging down. Rig released at 04:00 Printed: 5/20/2002 3:15:48 PM ANADRILL SCHLUMBERGER Survey report Client...................: BP Exploration (Alaska) Inc. Field. . . . . . . . . . . . . . . . . . . .: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: C-09A API number..... . . . . . . . . . .: 50-029-20366-01 Engineer. . . . . . . . . . . . . . . . .: M. Brown RIG: . . . . . . . . . . . . . . . . . . . . .: Nabors 3S / SLB Unit # 4 STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: MEAN SEA LEVEL Depth reference..........: GR Tie In @ 9392 ft GL above permanent.......: 0.00 ft KB above permanent.......: N/A-GR Tie In DF above permanent.......: N/A-GR Tie In ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- La tit ude ( + N / S -) . . . . . . . . . : - 999 . 2 5 f t Departure (+E/W-)........: -999.25 ft Azimuth from rotary table to target: 222.12 degrees [(c)2002 Anadrill IDEAL ID6_1C_10J 12-May-2002 14:26:19 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey. ......: MD of last survey... .....: Page 1 of 2 10-May-02 12-May-02 19 9500.00 ft 10560.00 ft - ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date............: 09-May-2002 Magnetic field strength..: 1150.12 RCNT Magnetic dec (+E/W-).....: 26.36 degrees Magnetic dip.............: 80.81 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G..............: R..............: Dip. . . . . . . . . . . . : of G...........: of R...........: of Dip.... . . . . . : Criteria --------- 1002.68 mGal 1150.12 RCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 RCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.36 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.36 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........: No degree: 0.00 --' ANADRILL SCHLUMBERGER Survey Report 12-May-2002 14:26:19 Page 2 of 2 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 9500.00 20.00 178.50 0.00 8753.11 1489.03 -2702.19 768.31 2809.29 164.13 0.00 TIP 2 9590.00 19.44 178.78 90.00 8837.83 1511.07 -2732.55 769.03 2838.70 164.28 0.63 MWD 3 9611.33 23.45 182.00 21.33 8857.68 1516.90 -2740.34 768.96 2846.19 164.33 19.59 MWD 4 9663.04 42.30 191.33 51.71 8900.94 1539.94 -2767.95 765.14 2871.76 164.55 37.65 SP 6-axis 5 9715.44 61.73 197.43 52.40 8933.06 1576.42 -2807.66 754.66 2907.32 164.96 38.17 MWD 6 9740.87 68.80 196.14 25.43 8943.69 1597.28 -2829.76 748.01 2926.96 165.19 28.19 SP 7 9815.57 79.58 202.36 74.70 8964.04 1663.40 -2897.45 724.27 2986.60 165.97 16.49 SP "~ 8 9875.45 89.50 214.41 59.88 8969.75 1721.14 -2949.70 695.97 3030.69 166.72 25.99 SP 9 9944.80 91.78 227.66 69.35 8968.97 1790.31 -3001.89 650.55 3071.57 167.77 19.38 SP 6-axis 10 9999.00 92.36 226.89 54.20 8967.02 1844.26 -3038.64 610.76 3099.41 168.64 1.78 MWD 11 10050.50 88.18 217.19 51.50 8966.77 1895.68 -3076.83 576.32 3130.34 169.39 20.51 MWD 12 10115.60 91.83 213.24 65.10 8966.77 1960.29 -3130.00 538.80 3176.03 170.23 8.25 SP 13 10206.07 90.55 235.56 90.47 8964.88 2050.09 -3194.21 475.91 3229.47 171.53 24.71 SP 14 10299.85 93.05 261.26 93.78 8961.88 2133.43 -3228.42 389.50 3251.83 173.12 27.52 SP 15 10390.50 81.33 246.51 90.65 8966.35 2210.03 -3253.38 302.89 3267.45 174.68 20.75 SP 16 10469.50 80.56 231.47 79.00 8978.86 2284.46 -3293.45 236.22 3301.91 175.90 18.82 MWD 17 10493.42 85.93 225.79 23.92 8981.68 2308.04 -3309.14 218.41 3316.34 176.22 32.55 SP 18 10523.00 92.43 222.00 29.58 8982.10 2337.58 -3330.44 197.92 3336.31 176.60 25.43 proj 19 10560.00 97.02 213.94 37.00 8979.05 2374.32 -3359.47 175.25 3364.04 177.01 25.00 proj TD [(c)2002 Anadrill IDEAL ID6_1C_10J "-" õ C-09A Schlumberuer Survey Report - Geodetic Report Date: 14-May-2002 Survey I DLS Computation Method: Minimum Curvature I Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 222.060° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 fl Structure I Slot: C-PAD I C-09 TVD Reference Datum: KB Well: C-09 TVD Reference Elevation: 62.500 ft relative to MSL Borehole: C-09A UWI/API#: 500292036601 Magnetic Declination: +26.355° Survey Name I Date: C-09A I May 14, 2002 Total Field Strength: 57505.578 nT Tort I AHD I DDII ERD ratio: 293.421 ° /3778.33 ft /6.112/ 0.418 Magnetic Dip: 80.807° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: May 14, 2002 -/ Location Lat/Long: N 701752.611, W 1484014.351 Magnetic Declination Model: BGGM 2001 Location Grid N/E YIX: N 5960329.000 ftUS, E 664145.000 ftU~ North Reference: True North Grid Convergence Angle: + 1.25155048° Total Corr Mag North -> True North: +26.355° Grid Scale Factor: 0.99993061 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/-S E/-W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 0.00 0.00 0.00 0.00 0.00 0.00 0.00 5960329.00 664145.00 N 701752.611 W 1484014.351 100.00 0.33 304.40 100.00 0.04 0.16 -0.24 0.33 5960329.16 664144.76 N 701752.612 W 1484014.358 200.00 0.22 231 .19 200.00 0.27 0.21 -0.62 0.34 5960329.19 664144.37 N 701752.613 W 14840 14.369 300.00 0.27 218.50 300.00 0.69 -0.10 -0.92 0.07 5960328.88 664144.08 N 70 1752.610 W 1484014.378 400.00 0.20 199.10 400.00 1.09 -0.45 -1.12 0.11 5960328.53 664143.89 N 70 17 52.606 W 148 40 14.384 500.00 0.40 208.29 500.00 1.59 -0.92 -1.35 0.21 5960328.05 664143.67 N 70 17 52.602 W 1484014.390 600.00 0.67 227,29 599.99 2.51 -1.63 -1.94 0.32 5960327.33 664143.09 N 70 17 52.595 W 148 40 14.408 700.00 0.63 220.19 699.98 3.64 -2.44 -2.73 0.09 5960326.50 664142.33 N 70 1752.587 W 1484014.431 800.00 0.38 208.29 799.98 4.51 -3.15 -3.24 0.27 5960325.78 664141.83 N 70 17 52.580 W 148 40 14.446 ~' 900.00 0.18 209.00 899.98 4.99 -3.58 -3.47 0.20 5960325.34 664141.61 N 70 17 52.575 W 148 40 14.452 1000.00 0.02 175.11 999.98 5.15 -3.74 -3.55 0.16 5960325.19 664141.54 N 70 17 52.574 W 1484014.455 1100.00 0.08 99.70 1099.98 5.13 -3.77 -3.48 0.08 5960325.16 664141.61 N 70 1752.574 W 1484014.452 1200.00 0.15 68.90 1199.98 4.97 -3.73 -3.29 0.09 5960325.20 664141.80 N 701752.574 W 1484014.447 1300.00 0.08 86.40 1299.98 4.80 -3.68 -3.09 0.08 5960325.25 664141.99 N 701752.575 W 1484014.441 1400.00 0.02 176.70 1399.98 4.77 -3.69 -3.02 0.08 5960325.24 664142.06 N 701752.574 W 1484014.439 1500.00 0.32 292.30 1499.98 4.87 -3.60 -3.28 0.33 5960325.32 664141.80 N 70 17 52.575 W 148 40 14.447 1600.00 0.57 8.00 1599.98 4.56 -3.01 -3.47 0.58 5960325.92 664141.60 N 70 1752.581 W 1484014.452 1700.00 0.52 1,39 1699.97 3.80 -2.06 -3.39 0.08 5960326.87 664141.66 N 70 17 52.590 W 148 40 14.450 C-09A ASP Final Survey.xls Page 1 of 4 5/15/2002-11 : 11 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec Nt-S EI-W DLS Northing Easting Latitude Longitude (ft) (°) (") . (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 1800.00 0.50 359.11 1799.97 3.14 -1.17 -3.39 0.03 5960327.76 664141.64 N 70 17 52.599 W 148 40 14.450 1900.00 0.38 13.60 1899.96 2.53 -0.41 -3.31 0.16 5960328.52 664141.70 N 70 17 52.607 W 148 40 14.448 2000.00 0.38 54.70 1999.96 1.91 0.10 -2.97 0.27 5960329.04 664142.03 N 701752.612 W 1484014.438 2100.00 0.27 61.59 2099.96 1.36 0.41 -2.49 0.12 5960329.35 664142.50 N 701752.615 W 1484014.424 2200.00 0.47 181.60 2199.96 1.45 0.11 -2.29 0.65 5960329.06 664142.71 N 701752.612 W 1484014.418 2300.00 0.77 176.70 2299.95 2.24 -0.97 -2.26 0.30 5960327.98 664142.76 N 701752.601 W 1484014.417 2400.00 0.88 179.20 2399.94 3.27 :2.41 -2.22 .0.12 5960326.54 664142.84 N 701752.587 W 1484014.416 2500.00 0.80 182.89 2499.93 4.38 -3.88 -2.24 0.10 5960325.08 664142.85 N 701752.573 W 148 4014.416 2600.00 0.72 181.39 2599.92 5.40 -5.20 -2.29 0.08 5960323.75 664142.82 N 70 1752.560 W 1484014.418 ~ 2700.00 0.75 176.20 2699.92 6.33 -6.48 -2.26 0.07 5960322.47 664142.88 N 701752.547 W 148 4014.417 2800.00 1.10 188.69 2799.90 7.59 -8.08 -2.36 0.40 5960320.87 664142.81 N 701752.531 W 148 4014.420 2900.00 4.30 151.61 2899.78 9.64 -12.33 -0.73 3.49 5960316.66 664144.54 N 70 17 52.489 W 148 40 14.372 3000.00 6.90 155.70 2999.30 13.31 -21.11 3.53 2.63 5960307.98 664148.99 N 70 17 52.403 W 148 40 14.248 3100.00 8.83 148.70 3098.35 17.91 -33.14 9.99 2.15 5960296.09 664155.71 N 70 17 52.285 W 148 40 14.060 3200.00 10.15 147,50 3196.98 22.46 -47.13 18.71 1.33 5960282.29 664164.74 N 701752.147 W 148 4013.806 3300.00 11.25 151 .00 3295.24 27.97 -63.09 28.18 1.28 5960266.54 664174.54 N 701751.990 W 1484013.530 3400.00 12.38 153.50 3393.13 35.05 -81 .22 37.69 1.24 5960248.63 664184.45 N 701751,812 W 1484013.253 3500.00 15.07 155.70 3490.26 44.19 -102.67 47.82 2.74 5960227.41 664195.05 N 70 1751.601 W 1484012.957 3600.00 16.75 157.90 3586.43 55.68 -127.87 58.59 1.78 5960202.45 664206.37 N 70 1751.353 W 1484012.643 3700.00 18.45 159.40 3681.74 69.23 -156.03 69.58 1.76 5960174.54 664217.97 N 701751.076 W 148 4012.323 3800.00 20.30 159.00 3776.08 84.36 -187.04 81.37 1.85 5960143.79 664230.43 N 70 1750.771 W 1484011.979 3900.00 22.12 159.81 3869.30 100.99 -220.91 94.09 1.84 5960110.21 664243.88 N 701750.438 W 148 40 11.609 4000.00 23.37 160.90 3961.52 119.32 -257.32 107.07 1.32 5960074.09 664257.66 N 701750.080 W 1484011.230 4100.00 23.78 162.40 4053.18 139.07 -295.28 119.66 0.73 5960036.42 664271.07 N 70 1749.707 W 1484010.863 4200.00 23.95 162.61 4144.63 159.57 -333.87 131.82 0.19 5959998.11 664284.07 N 70 17 49.327 W 148 40 10.509 ~ 4300.00 23.88 163.20 4236.04 180.36 -372.62 143.74 0.25 5959959.64 664296.83 N701748.946 W1484010.161 4400.00 23.98 163.81 4327.45 201.52 -411.51 155.25 0.27 5959921.01 664309.1 9 N 70 17 48.564 W 148 40 9.826 4500.00 24.02 164.20 4418.80 223.04 -450.61 166.46 0.16 5959882.17 664321.25 N 701748.179 W 148409.499 4600.00 24.35 164.90 4510.02 245.04 -490.10 177.37 0.44 5959842.93 664333.02 N 701747.791 W 148409.181 4700.00 25.73 166.70 4600.62 268.56 -531.13 187.74 1.58 5959802.14 664344.28 N 701747.387 W 148 40 8.879 4800.00 27.32 168.11 4690.10 294.41 -574.71 197.46 1.71 5959758.78 664354.95 N 70 1746.958 W 148408.596 4900.00 27.87 168.00 4778.72 321 .63 -620.03 207.05 0.55 5959713.69 664365.53 N 70 1746.513 W 148 40 8.316 5000.00 29.42 167.61 4866.48 349.63 -666.88 217.18 1.56 5959667.07 664376.68 N 701746.052 W 148 40 8.021 5100.00 30.72 167.90 4953.02 378.87 -715.85 227.80 1.31 5959618.35 664388.37 N 70 17 45.570 W 148 407.711 5200.00 31.60 168.40 5038.59 409.35 -766.49 238.43 0.92 5959567.96 664400.09 N 70 1745.072 W 148407.402 C-09A ASP Final Survey.xls Page 2 of 4 5/15/2002-11 : 11 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec NI-S EI-W DLS Northing Easting Latitude Longitude (ft) (°) n (ft) (ft) (ft) (ft) (0/100ft) (ftUS) (ftUS) 5300.00 32.33 168.11 5123.43 440.61 -818.32 249.20 0.75 5959516.38 664412.00 N 70 17 44.563 W 148 407.088 5400.00 32.98 169.00 5207.62 472.71 -871 .20 259.91 0.81 5959463.74 664423.85 N 70 17 44.042 W 148 40 6.776 5500.00 33.63 169.31 5291.19 505.82 -925.13 270.24 0.67 5959410.06 664435.36 N 701743.512 W 148406.475 5600.00 34.55 170.90 5374.01 540.37 -980.34 279.86 1.28 5959355.07 664446,18 N 70 1742.969 W 148 40 6.194 5700.00 35.45 172.40 5455.93 576.93 -1037.09 288.18 1.25 5959298.53 664455.74 N 70 17 42.411 W 148405.952 5800.00 35.67 173.00 5537.28 614.80 -1094.77 295.57 0.41 5959241.02 664464.39 N 70 17 41.844 W 148405.737 5900.00 35.00 168.11 5618,87 650.79 -1151 .79 305.03 2.91 5959184.23 664475.09 N 701741.283 W 148405.461 6000.00 33.32 161.31 5701.65 681 .11 -1205.89 319.75 4.17 5959130.46 664490.99 N 70 1740.751 W 148405.032 6100.00 33.55 160.70 5785.10 707.77 -1257.99 337.68 0.41 5959078.77 664510.05 N 701740.238 W 148 40 4.509 6200.00 33.65 160.31 5868.39 734.13 -1310.16 356.15 0.24 5959027.03 664529.65 N 701739,725 W 148403.971 .--- 6300.00 33.72 160.81 5951.60 760.59 -1362.46 374.61 0.29 5958975.15 664549.25 N 701739.211 W 148 40 3.433 6400.00 34.08 160.90 6034.60 787.46 -1415.15 392.90 0.36 5958922.87 664568.69 N 70 17 38.693 W 148 40 2.900 6500.00 34.13 160.70 6117.40 814.42 -1468.10 411.34 0.12 5958870.34 664588.28 N 701738.172 W 148402.363 6600.00 33.80 160.90 6200.34 841.28 -1520.86 429.71 0.35 5958818.00 664607.80 N 70 1737.653 W 148401.827 6700.00 33.38 160.61 6283.64 867.85 -1573.09 447.95 0.45 5958766.18 664627.17 N 70 17 37.139 W 148401.296 6800.00 32.92 160.70 6367.37 894.02 -1624.69 466.06 0.46 5958714.99 664646.40 N 701736.632 W 148400.768 6900.00 32.17 160.70 6451.66 919.80 -1675.46 483.84 0.75 5958664.63 664665.29 N 701736.133 W 148 40 0.250 7000.00 31.40 161.11 6536.67 945.21 -1725.23 501.08 0.80 5958615.24 664683.60 N 70 17 35.643 W 148 39 59.748 7100.00 30.55 161.50 6622.40 970.36 -1773.98 517.58 0.87 5958566.87 664701.16 N 701735.164 W 148 39 59.267 7200.00 29.87 161.61 6708.82 995.13 -1821.72 533.50 0.68 5958519.50 664718.12 N 701734.694 W 148 39 58.803 7300.00 29.10 161.81 6795.87 1019.48 -1868.45 548.94 0.78 5958473.12 664734.58 N 70 17 34.234 W 148 39 58.353 7400.00 28.60 161.70 6883.46 1043.38 -1914.27 564.05 0.50 5958427.64 664750.68 N 701733.784 W 1483957.913 7500.00 27.98 161.90 6971.51 1066.89 -1959.30 578.85 0.63 5958382.95 664766.47 N 70 1733.341 W 148 39 57.482 7600.00 27.27 161.70 7060.11 1089.89 -2003.34 593.33 0.72 5958339.24 664781.90 N 70 1732,908 W 148 39 57.060 7700.00 26.22 162.00 7149.41 1112.25 -2046.11 607.35 1.06 5958296.79 664796.85 N 70 17 32.487 W 148 39 56.652 7800.00 25.20 162.90 7239.51 1134.19 -2087.46 620.44 1.09 5958255.73 664810.84 N 70 1732.080 W 148 39 56.270 ~i 7900.00 24.33 163.40 7330.32 1155.81 -2127.55 632.59 0.89 5958215.92 664823.86 N 701731.686 W 148 39 55.916 8000.00 23.13 164.81 7421.86 1177.16 -2166.25 643.62 1.33 5958177.48 664835.73 N 70 17 31.306 W 148 39 55.595 8100.00 22.30 165.81 7514.10 1198.32 -2203.60 653.42 0.92 5958140.35 664846.34 N 70 1730.938 W 148 39 55.310 8200.00 22.12 163.61 7606.69 1218.71 -2240.06 663.38 0.85 5958104.12 664857.1 0 N 70 17 30.580 W 148 39 55.019 8300.00 22.10 158.90 7699.34 1237.06 -2275.67 675.46 1.77 5958068.78 664869.96 N 70 17 30.229 W 148 39 54.667 8400.00 22.40 159.11 7791.89 1254.22 -2311.02 689.03 0.31 5958033.74 664884.29 N 70 17 29.882 W 148 39 54.272 8500.00 21.60 159.70 7884.61 1271.42 -2346.09 702.21 0.83 5957998.97 664898.23 N 70 1729.537 W 148 39 53.888 8600.00 21.47 160.50 7977.63 1288.68 -2380.60 714.71 0.32 5957964.74 664911.48 N 701729.197 W 148 39 53.524 8700.00 21.30 162.20 8070.75 1306.51 -2415.15 726.37 0.64 5957930.46 664923.89 N 701728.858 W 1483953.184 C-09A ASP Final Survey.xls Page 3 of 4 5/15/2002-11 : 11 AM Grid Coordinates Geographic Coordinates Station ID MD loci Azim TVD VSec N/.S E/.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1000) (ftUS) (ftUS) 8800.00 21.53 163.81 8163.84 1325.29 -2450.06 737.04 0.63 5957895.79 664935.32 N 701728.514 W 148 39 52.874 8900.00 21 .45 165.00 8256.89 1344.89 -2485.35 746.88 0.44 5957860.74 664945.93 N 701728.167 W 148 39 52.587 9000.00 21.37 166.70 8349.99 1365.18 -2520.74 755.81 0.63 5957825.55 664955.63 N 701727.819 W 148 39 52.327 9100.00 22.28 175.00 8442.85 1388.46 -2557.36 761.65 3.21 5957789.06 664962.27 N 701727.459 W 148 39 52.156 9200.00 22.03 177.50 8535.46 1414.74 -2594.99 764.12 0.98 5957751.51 664965.56 N 701727.089 W 1483952.085 9300.00 21.13 177.61 8628.45 1440.97 -2631.73 765.69 0.90 5957714.81 664967.93 N 701726.727 W 148 39 52.039 9400.00 20.72 177.70 8721.86 1466.48 -2667.42 767.15 0.41 5957679.16 664970.17 N 701726.376 W 148 39 51.996 9500.00 20.00 178.50 8815.61 1491 .52 -2702.19 768.31 0.77 5957644.43 664972.09 N 701726.035 W 1483951.963 9590.00 19.44 178.78 8900.33 1513.58 -2732.55 769.03 0.63 5957614.10 664973.48 N 701725.736 W 148 39 51.942 9611.33 23.45 182.00 8920.18 1519.42 -2740.34 768.96 19.59 5957606.30 664973.57 N 70 1725.659 W 148 39 51.944 ~' 9663.04 42.30 191.33 8963.44 1542.47 -2767.95 765.15 37.65 5957578.62 664970.36 N 70 17 25.388 W 148 39 52.055 9715.44 61.73 197.43 8995.56 1578.97 -2807.66 754.66 38.17 5957538.69 664960.75 N 70 1724.997 W 148 39 52.361 9740.87 68.80 196.14 9006.1 9 1599.84 -2829.76 748.01 28.18 5957516.45 664954.58 N 70 17 24.780 W 148 39 52.555 9815.57 79.58 202.36 9026.53 1666.00 -2897.44 724.26 16.50 5957448.27 664932.32 N 701724.114 W 148 39 53.247 9875.45 89.50 214.41 9032.24 1723.75 -2949.70 695.96 25.97 5957395.42 664905.17 N 70 1723.600 W 148 39 54.072 9944.80 91.78 227.66 9031.46 1792.93 -3001.89 650.54 19.38 5957342.25 664860.90 N 70 17 23.087 W 148 39 55.395 9999.00 92.36 226.89 9029.51 1846.87 -3038.64 610.75 1.78 5957304.65 664821.93 N 70 1722.726 W 148 39 56.555 10050.50 88.18 217.19 9029.26 1898.29 -3076.83 576.32 20.51 5957265.71 664788.34 N 701722.350 W 1483957.558 10115.60 91.83 213.24 9029.26 1962.91 -3130.00 538.79 8.26 5957211.74 664751.98 N 70 17 21.827 W 148 39 58.652 10206.07 90.55 235.56 9027.35 2052.71 -3194.21 475.90 24.71 5957146.18 664690.52 N 701721.196 W 148 40 0.484 10299.85 93.05 261.26 9024.36 2136.00 -3228.42 389.49 27.52 5957110.09 664604.88 N 701720.859 W 148403.002 10390.50 81.33 246.51 9028.82 2212.55 -3253.38 302.88 20.74 5957083.24 664518.84 N 701720.614 W 148 40 5.526 10469.50 80.56 231.47 9041.32 2286.96 -3293.44 236.21 18.82 5957041.74 664453.07 N 70 17 20.220 W 148407.469 10493.42 85.93 225.79 9044.14 2310.54 -3309.14 218.40 32.55 5957025.66 664435.61 N 70 1720.066 W 148407.987 10523.00 92.43 222.00 9044.56 2340.08 -3330.43 197.91 25.43 5957003.92 664415.59 N 701719.856 W 148 40 8.584 ~ 10560.09 97.02 213.94 9041.51 2376,82 -3359.47 175.24 25.00 5956974.40 664393.56 N 701719.571 W 148409.245 C-09A ASP Final Survey.xls Page 4 of 4 5/15/2002-11: 11 AM .) ) MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Wee pie Well No C-09A Date Dispatched: 14-May-02 Installation/Rig Nabors 3S / SLB CTU # 4 Dispatched By: Nate Rose Data No Of Prints No of Floppies Su rveys aDc3... oC: LJ 2 RECEIVEr tt~Y 1 7 2002 AlaakaOiJ & 3asQ)ns.Commision ~dlorage Received By: ~l~Q~ Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrose1 @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1 , Dec '97 ) '\ ¡' ~~]~E : F !Æ~!Æ~~~!Æ AlASKA. OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 333 W. ]TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501.3539 PHONE (907) 279-1433 FAX (907) 276-7542 Mary Endacott . CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit C-09A BP Exploration (Alaska), Inc. Permit No: 202-094 Sur Loc: 885' SNL, 1223' WEL, Sec. 19, TIIN, RI4E, UM Btmhole Loc. 1033' NSL, 1067' WEL, Sec, 19, TI1N, RI4E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit C-09A. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, ~~;a~ Chair BY ORDER OF THE COMMISSION DATED this.iiJ& day of April, 2002 jjc/EncIosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1 a. Type of work 0 Drill II Redrill 0 Re-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 885' SNL, 1223' WEL, SEC. 19, T11 N, R14E, UM At top of productive interval 1885' NSL, 479' WEL, SEC. 19, T11 N, R14E, UM At total depth 1033' NSL, 1067' WEL, SEC. 19, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well i ADL 028310,1033' MD No Close Approach ./ 16. To be completed for deviated wells Kick Off Depth 9590' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casino Weioht Grade Couplino 3-3/4" 3-1/2" x 3.3116" 8.81# /6.2# L-80 ST-L x 2-7/8" 6.16# ALASKA L..2 AND ~:~T~g:S~~::;;ON COMMk,J'ON PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 $tratigraphic ~st II Development Oil 0 Service 0 Development Gas Gf'Single Zone I) 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 62.5' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028305 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / C-09A 9. Approximate spud date 05/10/02 / Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 10575' MD / 8965' TVDss 0 17, Anticipated pressure {see 20 AAC 25.035 (e) (2)} 93 Maximum surface 2244 psig, At total depth (TVD) 8800' / 3300 psig Setting Depth Top Bottom Quantitv of Cement Lenoth MD TVD MD TVD (include staoe data) 2195' 8380' 7780' 10575' 8965' 84 cu ft Class 'G' ~C:¡A- ifl ¿C¡/Ð2- Å-"-( b. '"' 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 9910 feet 9204 feet 9865 feet 9161 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 110' 20" x 30" 2660' 13-3/8" 9007' 9-5/8" 1423' 7" 12.9 cu yds Permafrost 4148 cu ft Arcticset II 1227 cu ft Class 'G', 130 cu ft AS 110' 2660' 9007' 110' 2660' 8356' 396 cu ft Class 'G' ~".. 11::: E: ~ 8487' - 9910' r" ~"'~~. It~ I ¡I L" i"," 7873' - 9204' Perforation depth: measured i\ /¡, ,) ..:. t)nr:? .... -' I.......... L.., 20. Attachments 9677' - 9682', 9698' - 9739' Sqzd: 9614' - 9625, 9635' - 9682' true vertical 8983' - 8987', 9002, - 9041' Sqzd: 8923' - 8933', 8943' - 8987' II Filing Fee 0 Property Plat II BOP Sketch 0 Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 0 20 AAC 25.050 Requirements Contact Engineer Name/Number: Mary Endacott, 564-4388 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that th~ fore~oin9Js ftryj ~~~j~. d. o,rr;c;,to/Je best of my k. n~~le.dge . r/ ~ It Signed MaryEndacott '-1J1JdC el1lf/t{ífPfÆ Title CT Dnlllng Engineer Date 4¡ 23/0cl Commission UsèOnly . ~RProval DatEJ\ () See cover letter L-t ' ~ U . li 0\ for other requirements Mud Log Required 0 Yes II No Directional Survey Required ~Yes 0 No D4K D5K D10K D15K ~5Kpsif~ " ~ I: I; ¡ ¡ :.~~ ,<I .l ì ~ Permit Numbe, r ~" I API Number "2-CJ 7- -0 I r 50- 029-20366-01 Conditions of Approval: Samples Required 0 Yes [iiNo Hydrogen Sulfide Measures [;i Yes 1J No Required Working Pressure for BOPE 0 2K 0 3K Other: Onglnal Signed By Cammy Oecbsli T~aylQf lrl: f, ) ¡ (~.. [. [",~f './. ~ db.', mmissioner ) l \ U !. J' ~ I j,-r '"",' Ii ~ \,,,,, , II "".~ t.,- by order of the commission Date L . /ì / .. /} f . /\( ¿? !) t7"- Submit In Triplicate Approved By Form 10-401 Rev. 12-01-85 ") BPX C-09A Sidetrack ) Summary of Operations: A CTD sidetrack of production well C-09 will be drilled. Specific prep work, (Phase 1) and drilling, (Phase 2) operations are detailed below. Prep will begin April 30, drilling is scheduled to begin May 10, 2002. ,/ Phase 1: Screen & Prep Well: Screen - MIT-IA. PPPOT-tbg hanger seals. MIT-OA and pressure test tree valves. . Mill XN to 3.80" / . Dummy drift, set 4%" x 7" through tubing whipstock at 959Ù'MD (8837 TVDSS), oriented at 26° TF. . Downsqueeze 15bbls cement in open perfs. ...,..-.-- Phase 2: Drill and Complete CrD sidetrack 23/8" coil will be used to drill an -1000 ft, 3%" open hole sidetrack, (as per attached plan) from a window cut through 7" liner. The sidetrack will be completed with 2,200 ft of solid, cemented & perforated, 3%" x 3 3/16" x 2-7/8" liner. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6ppg) Disposal: I . No annular injection on this well. / . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 3%" x 3 3/16" x 2 7/8", L-80, liner will be run from 8380'md (~780' TVDss) to TD at 10,575'. The completion will be cemented in place with approximately 15 bbls (annular volume +40% excess in OH) of 15.8 ppg class G cement. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . Real time MWD & Gamma Ray logs will be run while drilling the open hole section. . Memory resistivity is contingent on cuttings quality. . A memory CNUGR/CCL will be run inside liner prior to perforating. Hazards . . H2S is minimal on C Pad. Max recorded on the pad was 1 Oppm. / . The planned well exits the mother well at or near a fault in which no losses were experienced. A fault tipout zone of a small fault will be crossed, in which the mother well experienced no losses as well. Reservoir Pressure Reservoir pressure is estimate~to be 3,300 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,244 psi. TREE = WELLHEAD= ACTUA TOR= .. .. . KB. ELBI = BF. 8..BI = 'Rop=. . 'Wax A ngïe = 'O':itum rvÐ= Datum TV Ö= ... 6-318" OCT OCT OTIS 62.48 33.7' 2800' .36 @ 5800' ...... 9550' 8800' SS ) ') C-09 8 I ~ ~ 1982' H 7' SSSV OTIS LA NDING NIP, ID = 5.962" I 2601' H 9-518" rN R<R I :8: 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2660' ¡-JI Minimum ID = 3.725" @ 8499' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR H 8489' ~ t: 8406' H 7' FBRASSY, TOP I 8429' - 9-518" X 7" GUB R<R, ID = 3.833" 8430' - 7' x 4-1/2" XO I 8468' H 4-112" OTIS X NIP, ID = 3.813" I .. I 8499' H 4-112" OTISXNNIP, ID= 3.725" I / \. 8531' - TUBING TAIL WLB3 I 8535' - ELM) TT LOGGED 07/05/92 I I 7" TBG, 26#, L-80, 0.0383 bpf, ID = 6.276" - 8430' I TOP OF 4-1/2" TBG - 8430' I 4-1/2"TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" H 8531' 9-518" CSG, 47#, N-80, ID = 8.681" 1-1 9007' ---.41 ~ PERFORATION SUMMð. RY REF LOG: BHCS on 07/11/79 ANGLEATTOPÆRF: 19 @9614' N:>te: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz )ð, TE 3-1/8" 4 9614-9625 S 11105/87 3-1/8" 4 9635 -9682 S 11105/87 3-318" 6 9677-9682 0 06124/97 3-1/8" 4 9698 -9739 . 0 11121/87 )ð, TE 10/12/79 01/30/01 03108101 05121/01 -1 9533' H MARKER JOINT I I PBTD H 9865' 7" Lt\R, 29#, L-80, 0.0371 bpf, ID = 6.184" H 9910' ~ RBI BY OOI'vtv1BJTS ORlGINA L COMPLETON SIS-1s1 CONVERTEDTO CAN\! AS SIS-LG FINAL RN'KAK CORRECTIONS )ð, TE REV BY COMtv'ENlS FRUŒlOE BÞ. Y Ut\IT W8..L: C-09 PERMIT No: 79-0260 API No: 50-029-20366-00 Sec. 19,T11N,R14E BP Exploration (Alaska) TREE = 6-3/8" OCT WELLHEAD= OCT ACTUÄ'TOR;"'" """"""""w,w'''OTïS 'Ktf"'ï~LBi;'''''''''''''''''''''''.'''''''''''''''''''''''62~48' "BwF:"EI8r;-M---~""-'^W,,,ww-'3"~r7'i "R'op';""""""""""""""""""'''''''''''''''"'''''''''''''''''''''''',,''''' ""''''''''28'0'6'i' "MãX'"Ãiî'gle"^;;'--"_~"^W"M:r6,,@wŠ8ÕÕ; 'Öaturn"MÖ";""""'"''''''''''''''''''''''''''''''''''''''''""9"550; '5ãtíJm rVï5;-'"-^"~ .. . . aäõo'.s"s C-t,~A Proposed C,(D Sidetrack 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-i 2660' Minimum ID = 3..1/2" OTIS XN NIPPLE I PROPOSED TOP OF 3 3/16" X 2 7/8" LNR l-i 8445' I 7" TBG, 26#, L-80, 0.0383 bpf, 10 = 6.276" l-i 8430' 1 TOP OF 7" LNR l-i 8489' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" l-i 8531' . 1982' l-i 7" SSSV OTIS LANDING NIP, 10 = 5.962" I ~ ~ ~ ---1 2601' l-i 9-5/8" DV PKR 1 ~ , ~ 8450' I". '. ~- ~--1 I I-iXN nipple 8406' l-i 7" PBRASSY, TOP I 8429' l-i 9-5/8" X 7" GUIB PKR, 10 = 3.833" 1 8430' l-i 7" x 4-1/2" XO I ~ {- 8468' l-i 4-1/2" OTIS X NIP, 10 = 3.813" I 8499' l-i 4-1/2" OTIS XN NIP, 10 = 3.725" I 8531' l-i TUBING TAIL WLEG I 9-5/8" CSG, 47#, N-80, 10 = 8.681" l-i 9007' 1----.4 ÆRFORA TION SUMMARY REF LOG: BHCS on 07/11/79 ANGLEAT TOP PERF: 19 @ 9614' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-1/8" 4 9614-9625 S 11/05/87 3-1/8" 4 9635 -9682 S 11/05/87 3-3/8" 6 9677 -9682 0 06/24/97 3-1/8" 4 9698 -9739 0 11/21/87 17" LNR, 29#, L-80, BTC, 0.0371 bpf, 10 = 6.184" l-i 9910' DATE 10/12/79 01/30/01 03/08/01 05/21/01 03/19/02 REV BY COMMENTS ORIGINAL COMPLETION SIS-lsl CONVERTED TO CANVAS SIS-LG FINAL RN/KAK CORRECTIONS MSE PROPOSED SIDETRACK ~ 9300' l-i Proposed top of cernent 1/ ~HH::::,::~ossover II : ~:, I ..... 13 3/1~".x 27/8" L80 So[;d Uner H 10575'1 / .>öööOõô& 1 PBTD l-i 9865' ~ 1 TO 1-1 9910' DA TE REV BY COMMENTS PRUDHOE BA Y UNIT WELL: C-09 ÆRMIT No: 79-0260 API No: 50-029-20366-00 Sec. 19, T11N,R14E BP Exploration (Alaska) r--------- BP Amoco 0", b,- -,-p WELLPATH KTAlLS "../Q C-O'A 50028202..01 P.,....t W.U,.th~ TJ.o..MO: C-<l8 1580.00 Nordic 1 11 ,0' '/251187' 00,00 52.5Oft ~~ ~:::~ lUll' R.,. Dat.m: v.s-:.~.: O.l1~ 222.00. REFERENCE INFORMATION Co-ordinate (NÆ) Reference: Well Centre: C-09, True North V~~~~! ~:::;:~~: ~r:~'& ro~~oÕ~)el Measured Depth Reference: 11 : 09 6125/1979 00:00 62,50 Calculation Method: Minimum Curvature aEC'nONDETAlL8 t«).II DL-. Tfec. v&ec Target 1 8soo.oo 20.00 11...&0 875).1t .2102.2" 7eA.S8 0.00 0.00 1......00 2 UIO.OO '8.44 ue.n 8837.'3 .2732..60 78e.tO 0.83 ~58 151801 3 MOLOO 21.07 180.87 68l4.n -213.". 7".it ~. : tæ:~~: 5:: ill::! 55 :5:!i 5U :::~ioo::: 1......r.~.:.~ë 1~:~3I5b,20,5".:...~.'81' 7 IOZ17.78 IO.M 251.'" ..87.23 -nGe." 404.8. 8 10515.00 10.11 21''''''' &885.03 .3.)81.sa 148.43 -2850 - - . .5 -2900 æ := :& -2950 - MD Allllol:8t1on '713.11 1100.00 TIP '127.12 1110.00 KOP ""'72 1101.00 1 "71.00 '122.71 2 "72.20 'IU.7I 2 .H..80 10047.7. .. '"7.2J 10217.7. . "'5.0:1 1017'.00 TD - ' C 8650-=--' ~ 8700-~ It) - - .c 8750.=- . ... - a. - u 8800- a ëi 8850- ~ CJ :e 8900~' u- > 8950- - u ë 900~ ... ' 9050 -- ~ffr ~~ iii~ ll1~ ~ +' -3000 @-3050 J 0 - ~ -3100 . :c -3150 ... :s 0 -3200 en -3250 8450''=':' - 8500- . - - - -, - - ----- . ------~- - - - ---- ------.--- - 8550--=- -- - -------- 8600 :: , - - - - -- - - ---.-~ r----~ -~- ---- .----~--~--~ , , ---~._-- - ~--------------- 91 00----- 9150--::- : -,....-----. 9200- ---- _.. BAILs L~TEQ LEGEND C-OO (C-OO) - Plan#3 C-Q9A - Plan #3 T ^M ¿ Stre~;~~~~~&~~~ Contact Information' Dip Angle: 80.80° Direct: (907) 2ô7-6613 Date: 3I19/2002 E-mail: brij.potniS@inteQcom Model: BGGM2001 Baker Hughes INTEQ: (907) 2ô7-6600 Plan: Plan #3 (C-09/Plan#3 C-09A) Azimuths to True North Magnetic North: 26.39° , ~~ Created By: Brij Potnis Date: 3/19/2002 -2650 --- -2700 - -2750 - -2800 - -3300 -3350 -3400 -3450 500 550 West(-)/East(+) [50ft/in] - Vertical Section at 222.00° [50ft/in] 3/19/2002 10:-18 AM ) ) 7",."111.,. II. ........ INJ"[' RQ bp BP Baker Hughes INTEQ Planning Report Company: ~ield : Site: Well: Wellpath: Field: BPÀmoco Prudhoø.Bay PBCPåd C-09 Plan#3 G-09A Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date:3119/200~. .. . TiD1~: 10:4$:08 . .. CO-O~dlnåt~(l~E)~eferençe:' Well;Ç-Q9,TfueNOrth 'Yert~~al(TVQ)~efe~~~ç~: $Y'i'te01:Me~rI Se~Le\,el ... Section(V~)Ref~rence: .' . . ,W~U(0.,OON,0.09§,~?2.00Äii) Sll~eyÇalcuh,ti~nl\let~od: . lYIinimurnCul".lature. Db: Page: 1 Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2001 PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5957218.72 ft 662550.03 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 22.367 N 148 41 2.797 W True 1 .24 deg C-09 C-09 Well Position: Well: Slot Name: 09 +N/-S 3075.29 ft Northing: 5960329.00 ft +E/-W 1661.96 ft Easting: 664145.00 ft Position Uncertainty: 0.00 ft Latitude: Longitude: 70 17 52.611 N 148 40 14.351 W Wellpath: Plan#3 C-09A 500292036601 Current Datum: 11 : 096/25/1979 00:00 Magnetic Data: 3/19/2002 Field Strength: 57503 nT Vertical Section: Depth From (TVD) 1t 0.00 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W 1t 0.00 C-09 9590.00 ft Mean Sea Level 26.39 deg 80.80 deg Direction deg 222.00 Height 62.50 ft Targets lVJ)lp ~ap. .:;-".;-.. Latitudc.-,,-> <rt" .. Longitude.,....> Name Description TVD +N/.;S +E/-W N()rtb~ng . Easting Deg Min ....... Se~ D~gMinSec Dip. Dir. 1t ft ft ft ft C-09A Polygon 0.00 -3514.30 193.31 5956820.00 664415.00 70 17 18.048 N 148 40 8.719 W -Polygon 1 0.00 -3514.30 193.31 5956820.00 664415.00 70 17 18.048 N 148 40 8.719 W -Polygon 2 0.00 -3031.38 758.92 5957315.12 664969.89 70 17 22.797 N 148 39 52.238 W -Polygon 3 0.00 -2872.95 602.30 5957470.09 664809.86 70 17 24.355 N 148 39 56.801 W -Polygon 4 0.00 -3355.87 36.69 5956974.96 664254.97 70 17 19.606 N 148 40 13.282 W C-09A T3.3 8965.00 -3374.00 181.37 5956960.00 664400.00 70 17 19.428 N 148 40 9.067 W C-09A T3.2 8969.00 -3062.57 578.29 5957280.00 664790.00 70 17 22.490 N 148 39 57.501 W C-09A T3.1 8975.00 -2894.79 681.99 5957450.00 664890.00 70 17 24.140 N 148 39 54.479 W Annotation MD TVD ft ft 9500.00 8753.11 TIP 9590.00 8837.83 KOP 9608.00 8854.72 1 9832.78 8975.00 2 9932.78 8972.30 3 10047.78 8968.80 4 10287.78 8967.23 5 10575.00 8965.03 TO ) BP ) .Jr: bp Baker Hughes INTEQ Planning Report 1~"'tEQ Company: BPAmoco Date: 3119/2002 Time: 10:49:08 Page: 2 Field: Prudhoe Bay co-ordinate(NE} Reference: Well:Ç-09, True North Site: PB C Pad Vertical (TVD}Reference: Sy~tem:Mea.n SeaLevel Well: C-09 Section (VS) Reference: Well (0.OON,0.00E.222.00Azi) Wellpath: Plan#3 C-09A Survey CalculationMetho<l: Minimum Curvature Db: Oracle Plan: Plan #3 Date Composed: 3/19/2002 Version: 1 Principal: Yes Tied-to: From: Definitive Path Plan Section Information MD Incl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 9500.00 20.00 178.50 8753.11 -2702.24 768.38 0.00 0.00 0.00 0.00 9590.00 19.44 178.78 8837.83 -2732.60 769.10 0.63 -0.62 0.31 170.56 9608.00 21.07 180.97 8854.72 -2738.83 769.11 10.00 9.07 12.19 26.00 9832.78 90.00 200.00 8975.00 -2906.29 724.24 31.20 30.66 8.46 20.28 9932.78 93.08 211.60 8972.30 -2996.13 680.81 12.00 3.08 11.60 75.00 10047.78 90.39 225.14 8968.80 -3086.02 609.62 12.00 -2.34 11.78 101.00 10287.78 90.34 253.94 8967.23 -3206.39 404.91 12.00 -0.02 12.00 90.00 10575.00 90.51 219.48 8965.03 -3361.66 168.43 12.00 0.06 -12.00 -89.60 Survey MD Incl Aiim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft degl1 OOft deg 9500.00 20.00 178.50 8753.11 -2702.24 768.38 5957644.38 664972.16 1494.00 0.00 0.00 TIP 9525.00 19.84 178.58 8776.61 -2710.75 768.60 5957635.87 664972.57 1500.19 0.63 170.56 MWD 9550.00 19.69 178.65 8800.14 -2719.20 768.80 5957627.42 664972.96 1506.33 0.63 170.48 MWD 9575.00 19.53 178.73 8823.69 -2727.59 769.00 5957619.04 664973.33 1512.44 0.63 170.41 MWD 9590.00 19.44 178.78 8837.83 -2732.60 769.10 5957614.04 664973.55 1516.08 0.63 170.34 KOP 9600.00 20.34 180.04 8847.24 -2736.00 769.14 5957610.64 664973.66 1518.59 10.00 26.00 MWD 9608.00 21.07 180.97 8854.72 -2738.83 769.11 5957607.82 664973.69 1520.71 10.00./" 24.81 1 9625.00 26.11 185.15 8870.29 -2745.61 768.72 5957601.02 664973.45 1526.01 31.20 20.28 MWD 9650.00 33.66 189.13 8891.96 -2757.95 767.13 5957588.65 664972.13 1536.25 31.20 16.45 MWD 9675.00 41.29 191.78 8911.78 -2772.89 764.34 5957573.66 664969.67 1549.21 31.20 13.00 MWD 9700.00 48.97 193.72 8929.41 -2790.15 760.42 5957556.32 664966.12 1564.67 31.20 10.89 MWD 9725.00 56.67 195.26 8944.51 -2809.41 755.42 5957536.95 664961.55 1582.33 31.20 9.51 MWD 9750.00 64.39 196.55 8956.80 -2830.33 749.45 5957515.91 664956.04 1601.86 31.20 8.58 MWD 9771.66 71.08 197.53 8965.00 -2849.48 743.58 5957496.64 664950.58 1620.02 31.20 7.94 C-09A T3 9775.00 72.12 197.68 8966.05 -2852.50 742.62 5957493.60 664949.69 1622.91 31.20 7.57 MWD 9785.52 75.37 198.12 8969.00 -2862.11 739.52 5957483.92 664946.80 1632.13 31.20 7.52 C-09A T3 9800.00 79.85 198.71 8972.10 -2875.52 735.05 5957470.42 664942.63 1645.09 31.20 7.40 MWD 9825.00 87.59 199.70 8974.84 -2898.97 726.88 5957446.80 664934.97 1667.98 31.20 7.27 MWD 9832.78 90.00 200.00 8975.00 -2906.29 724.24 5957439.42 664932.49 1675.19 31.20 7.17 2 9850.00 90.53 202.00 8974.92 -2922.36 718.07 5957423.22 664926.67 1691.26 12.00 75.00 MWD 9875.00 91.31 204.89 8974.52 -2945.29 708.12 5957400.08 664917.23 1714.95 12.00 75.01 MWD 9900.00 92.08 207.79 8973.78 -2967.69 697.04 5957377.45 664906.64 1739.01 12.00 75.06 MWD 9925.00 92.85 210.70 8972.70 -2989.48 684.84 5957355.40 664894.92 1763.37 12.00 75.14 MWD 9932.78 93.08 211.60 8972.30 -2996.13 680.81 5957348.66 664891.04 1771.00 12.00 75.27 3 9950.00 92.69 213.63 8971.43 -3010.61 671.55 5957333.98 664882.09 1787.97 12.00 101.00 MWD 9975.00 92.11 216.58 8970.39 -3031.04 657.18 5957313.24 664868.18 1812.76 12.00 101.10 MWD 10000.00 91.52 219.52 8969.59 -3050.72 641.78 5957293.24 664853.22 1837.69 12.00 101.23 MWD 10025.00 90.93 222.46 8969.06 -3069.58 625.39 5957274.02 664837.24 1862.68 12.00 101.32 MWD 10047.78 90.39 225.14 8968.80 -3086.02 609.62 5957257.24 664821.84 1885.44 12.00 101.38 4 10050.00 90.39 225.41 8968.78 -3087.58 608.05 5957255.65 664820.29 1887.66 12.00 90.00 MWD 10075.00 90.39 228.41 8968.61 -3104.66 589.79 5957238.18 664802.42 1912.56 12.00 90.00 MWD 10100.00 90.39 231 .41 8968.44 -3120.75 570.67 5957221.67 664783.65 1937.32 12.00 90.02 MWD 10125.00 90.39 234.41 8968.27 -3135.83 550.73 5957206.17 664764.05 1961.86 12.00 90.04 MWD 10150.00 90.38 237.41 8968.11 -3149.84 530.03 5957191.71 664743.66 1986.13 12.00 90.06 MWD 10175.00 90.38 240.41 8967.94 -3162.75 508.62 5957178.34 664722.54 2010.04 12.00 90.08 MWD 10200.00 90.37 243.41 8967.78 -3174.52 486.57 5957166.09 664700.75 2033.55 12.00 90.10 MWD 10225.00 90.36 246.41 8967.62 -3185.12 463.93 5957155.00 664678.35 2056.57 12.00 90.12 MWD 10250.00 90.36 249.41 8967.46 -3194.52 440.77 5957145.10 664655.40 2079.06 12.00 90.14 MWD 10275.00 90.35 252.41 8967.31 -3202.69 417.15 5957136.41 664631.97 2100.94 12.00 90.16 MWD ) BP ) , 'lie bp Baker Hughes INTEQ Planning Report IN'''[EQ Company: BP Amoco Da~e.: ..... ...3/19/2002 Time: ,.10:49:08 Page: 3 Field: Prudhoe. Bay Co..ordinate(NE). Refertmçe: Well:C~09, True NQrth Site: PB C Pad Vertical (TVD) Reference: Sy~tem: .MeanS~a. Leval Well: C-09 Section(VS) Reference: Well.(0.00N,0.00E,222.00Azi) Wellpath: Plan#3. C-09A Suryey .Ü"culationM~thod: Minimum Curvature Db: Oracle Survey MD Incl Azim SSTVD N/S' .I!:IW MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/100ft deg 10287.78 90.34 253.94 8967.23 -3206.39 404.91 5957132.44 664619.82 2111.87 12.00 90.18 5 10300.00 90.35 252.48 8967.16 -3209.92 393.22 5957128.66 664608.20 2122.32 12.00 270.40 MWD 10325.00 90.37 249.48 8967.00 -3218.07 369.59 5957120.00 664584.76 2144.19 12.00 270.39 MWD 10350.00 90.39 246.48 8966.83 -3227.44 346.41 5957110.12 664561.79 2166.66 12.00 270.37 MWD 10375.00 90.41 243.48 8966.66 -3238.01 323.76 5957099.06 664539.38 2189.67 12.00 270.35 MWD 10400.00 90.43 240.48 8966.48 -3249.75 301.70 5957086.84 664517.58 2213.16 12.00 270.33 MWO 10425.00 90.44 237.48 8966.29 -3262.64 280.27 5957073.49 664496.45 2237.07 12.00 270.31 MWD 10450.00 90.46 234.48 8966.09 -3276.62 259.56 5957059.06 664476.04 2261.33 12.00 270.29 MWO 10475.00 90.47 231.48 8965.89 -3291.67 239.60 5957043.58 664456.42 2285.87 12.00 270.26 MWD 10500.00 90.48 228.48 8965.68 -3307.75 220.46 5957027.09 664437.63 2310.62 12.00 270.24 MWO 10525.00 90.49 225.48 8965.47 -3324.80 202.18 5957009.64 664419.73 2335.52 12.00 270.21 MWD 10550.00 90.50 222.48 8965.25 -3342.79 184.82 5956991.28 664402.78 2360.50 12.00 270.19 MWD 10575.00 90.51 219.48 8965.03 -3361.66 168.43 5956972.06 664386.80 2385.50 12.00 270.16 TO Well # ) ) Date All Measurements are from top of Riser 4/22/2002 24. T from top of floor to rig mats 21.81 of room under floor to rig mats "'- Q) en (L Flanae to Flanae Heiahts 7" otis x-o .70. top of bag BAG 2.80. bUm of bag middle of slips Blind/Shears ""''''."""", TOTs ~/ 1.90. ...- .... 2-3/8" pipe/slips ........ middle of pipes .., .., ,... ~. ~. Mud Cross Mud Cross 1.70. middle of flow cross -- '-- 3-1/2" pipe/slips ........ .................. middle of blind/shears TOTs / 1.90. ..... .., 2-3/8 X 3.5 Var. pipe .., .., middle of pipe/slips .............. middle of master - Tubing spool adapter .. Lock down screws Tubing Spool Rig mats ~~"----r;-:-""""'":,,,,""...r- o,"'''¡o ',... ,. "_00 _0.- 0"0"'.' --~ 0 ".. ., 0 H 206300 DATE 03/14/02 CHECK NO. 00206300 DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS iOO.OO VENDOR DISCOUNT At ASKAOIlA NET 00 031202 CK03i202J PYMT COMMENTS: HANDL':NG INST: Pernit to Drill ~ee S/H - Terrie Hubble X4628 iOO.OO H ~-oqfJ , :0 ~'" , . --- :. f'-;",,,,:.f--'- ~; : . ' : ~ : . : ; ,:". .:. ' THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ 100 00 100 no BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519.6612 FIRST NATIONAL BANK OF ASHLAND AN AFFlUATE OF NATIONAL CITY BANK CLEVElAND. OHIO No. H 206300 CONSOLIDATED COMMERCIAL ACCOUNT 56-389 412 00206300 PAY ONE HUNDRED & 00/10°************************************* US DOLLAR DATE /03/14/02 AMOUNT $100.00 ---' To The ORDER Of ALASKA OIL AND GAS CONSERVATION COMMISSION 333..WEST 7TH AVENUE SUITE 100 ANCHORAGE NOT VALID AFTER 120 DAYS AI-<. 99501 Ç(c-Jß~~~'L( --- III 20 b :i 0 0 III I: 0 ~ ~ 2 0 :i 8 ~ 51: 0 0 8 ... ~ ~ g III ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETIERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME !ða ê-oc¡;:¡ CHECK 1 STANDARD LEITER DEVELOPMENT 1/ DEVELO~IVJ"/,.MENT. ,,/ REDRILL ¡/ . EXPLORATION INJECTION WELL INJECTION WELL REDRlLL CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) , ANNUL~, ~OSAL NO ANNULAR DISPOSAL <--.J YES ANNULAR DISPOSAL THIS WELL' "CLUE" Tbe permit is for a Dew weUbore segment of existing well ~ Permit No, ,API No. . " Production should continue to be reported as a functioD of the original API number stated above. . In accordance with ~O AAC 25.005(1), all r~ords, data and logs acquired for tbe pilot bole. must be dearly . differentiated in both name (nameoD permit plus PH) and API number (SO -70/80) from , records, data and logs acquired for wel~ (na,me on permit). Annular disposal has ~ot been requested... Annular Disposal. of drilling wastes will not be approved. . . Annular Disposal of drilling wastes will not be approved. . . DISPOSAL INTO OTHER Please note tbat an disposal of fluids generated... . ANNULUS L--> YES + SPACING EXCEPTION Templates are located m drive\jody\templates Enclosed is the approved application for permit to drill the above referenced well. Tbe permit is approved .sùbject to full compliance with 20 AAC 25.055. Approval to peñorate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Companv Name) will assume tbe liability of any protest to tbe spacing exception tbat may occur. WELL PERMIT CHECKLIST COMPANY ~P;G WELL NAME!?ß.¿( t? -0 9J!'f PROGRAM: Exp - Dev ~edrll ¿.../'Serv - Wellbore seg - Ann. disposal para req- FIELD & POOL ~ ¥O /S-Ö INIT CLASS --::::J7t:¡/ ;'lJ/L.. GEOL AREA 15'/'1') UNIT# 0/1 &5êJ ON/OFF SHORE rJ;¡ ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . 3. Unique well name and number. .. . . . . . . . . . . . . . . . 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . N 6. Well located proper distance from other wells.. . . . . . . . . N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . N 10. Operator has appropriate bond in force. . . . . . . . . . . . . N 11. Permit can be issued withQut conservation order. . . . . . . . N AP~ DA T~ / . 12. Permit ca~ be issued without administrativ~ approval.. . . . . N ~ V t.(. ¿...,. D2-13. Can permit be approved before 15-day walt.. . . . . . . . . . Y N ENGINEERING 14. Conductor string provided. . . . . . . . . . . . . . . . . . . '¥--N- 15. Surface casing protects all known USOWs. . . . . . . . . . . ¥-N- ¡J / i- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . -v-N- 'or- 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ N. -ì- 18. CMT will cover all known productive horizons. . . . . . . . . . N Ade b ¿Lev /...( epr R ç c:. . 19. Casing designs adequate for C, T, B & permafrost. . . . . . . Z'J N , 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . D¿' N c;T D u 21. If a re-drill, has a 10-403 for abandonment been approved. .. '* 'f.-. N 22. Adequate wellbore separation proposed.. . . . . . . . . . . . t't) N 23. If diverter 'required, does it meet regulations. . . . . . . . . . f. ¡oJ /k 24. Drilling fluid program .schematic & equip list adequate. . . . . N 25. BOPEs, do they meet regúlation . . . . . . . . . . . . . . . . "N. I ¡ . . t f\ APP.R. ,D,ATJ;/ 26. BOPE press rating appropriate; test to 35"00 psig. ,.. N 5; ~ ~ c ru f--e <; . IU£ I,) :: 1 Z i/'-I I L/ . ~91\ ¡.f 2C{ 01.- 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N tt':\ '-II 28. Work will occur without operation shutdown. . . . . . . . . . . ' N - - mfa.{ 1')",-0').. 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . @ N tu? j¿et.PuJ. GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. . . . . Xø- ~.") ¿;d ~," { 11 -,~~I /~ -' c,~.."Llþ ~¡¿ 31. Data presented on potential overpressure zones. . . . . . . ~ (/ 32. Seismic anal~~is of shallo~ gas zones. . . . . . . . . . . . " )JrA N AP~ OA T~ / 33. Seabed condition survey (If off-shore). . . . . . . . . . ..:./" Y N .~.p 'I. Z'f .Ol-34. Contact name/phone for weekly progress reports [exp/Ql'ff'fory only] Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; Y N (0) will not damage producing formation or impair recovery from a Y N pool; and '(E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: TEM$!~ ~" WGA itJl:¡it ( { - \ APPR DATE ~ ~ ¡lo!- ~Ów?sl=eJ. \NC1.".~\n~.c Comments/Instructions: RPC- SF~-;z!b- COT DTSOt/~jo<- JMHu. G: \geology\templates \checklist. doc
