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Home My WebLink About203-010 Comments about this file Quality Checked I I 1111111 I /5/ II I BY: Helen Maria Date: II 1111 ReScanned I I 111111 I I /5/ 1111111 " I Scanning is complete at this point unless rescanning is required. BY: Stage 1 BY: Stage 1 Helen Maria Page Count Hele~Maria) _ NO in stage If 1 Matches Number page(s) discrepancies were found in Scanning Preparation Date: (Count does include cover sheet) ~ YEt NO Date: 1f17! ()ç /5/ YES NO mp Page Count from Scanned File: 6& Production Scanning Scanning Preparation BY: Helen ~~) I a ~ =~TAL PAGES (tou~t ~o m~t ~Iude cover Datey 7/ tJ.S"" /5/ IIIIII x 30 = 3CJ + BY: Project Proofing Helen ¡1V1aria ) C Maria L,. BY: Helen o Other::. /~ l- Date: if ~l?6 II Date: , I '1/7/05 I 5z she t) I/VtP II wt·fJ II /51 /5/ II I II II W{;¡P NOTES: o Logs of various kinds o Other: o Poor Quality Originals OVERSIZED (Non-Scannable) o Maps: o Other Items Scannable by a Large Scanner o Greyscale Items DIGITAL DATA ~kettes. No o Other, No/Type: o Color Items ~ RESCAN Organizing (done) o Two-sided I I III III 1111 OVERSIZED (Scannable) o Rescan Needed I I I III I I III 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. .1 Q:3 - () t 0 Well History File Identifier XHVZE Image Project ') Well History File Cover Page ) • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other 0 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 Abend.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 6/28/2012 203 -010. 312 - 147 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 2/16/2003 50- 029 - 20121 -01-00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 2/19/2003 PBU C -01A • 3763' FSL, 881' FEL, Sec. 19, T11 N, R14E, UM 8. KB (ft above MSL): 63.84' • 15. Field / Pool(s): Top of Productive Horizon: 3755' FSL, 651' FEL, Sec. 19, T11 N, R14E, UM GL (ft above MSL): 34.9' Prudhoe Bay Field / Prudhoe Bay • Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 2770' FSL, 152' FEL, Sec. 19, T11 N, R14E, UM 8797' 8769' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 664503 • y- 5959706' Zone- ASP4 10059' • 9023' • ADL 028305 ' TPI: x- 664732 y- 5959702 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 665257 y 5958728 Zone- ASP4 None 18. Directional Surve y ❑ Yes 0 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, DIR, GR, RES, ABI, DEN, NEU 8554' 8541' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 30" Stove Pipe Surface 98' Surface 98' 36" 297 sx Cement 18 -5/8" 109.35#196.5# K -55 Surface 2508' Surface 2508' 24" 6850 sx Permafrost I I 13 - 3/8" x 9 - 5/8" 68# / 47# N -80 Surface 8015' Surface 8005 12 -1/4" 1720 sx Class 'G', 2900 sx PF II 9 -5/8" 40# L -80 Surface 2015' Surface 2015' Tieback 620 sx Class 'G' 7" 29# N -80 7462' 8554' 7454' 8541' 8-1/2" 500 sx Class 'G' 4 -1/2" 12.6# L -80 8407' 10059' 8395' 9023' 6" 187 sx Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open SET (MD +TVD of Top & Bottom; Perforation Size and Number): .SIZE DEPTH (MD) PACKER SET ( MD / TVD ) 4 -1/2 ", 12.6 #, 13Cr80 / L - 8412' 8201' / 8191' MD TVD MD TVD 8355' / 8344' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECEIVED INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 8900' Set Cast Iron Bridge Plug JUL 2 4 2012 8797' Set Whipstock 2 AOGCC 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production N/A Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ►_. No Sidewall Core(s) Acquired? ❑ Yes ® No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None e i RBDMS JUL 2 1012qk Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE V VF A /' Z S mit Original Only 29. GEOLOGIC MARKERS (List all formations "Corkers encountered): 30. • FORMATION TESTS NAME D TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Zone 4A 8640' 8625' None 42P 8658' 8642' Zone 3 / Top CLG 8707' 8688' Zone 2C / Base CLG 8782' 8756' 23 SB 8883' 8842' 22 TS 8945' 8889' GOC 9030' 8940' 22N 9060' 8954' 21 TS 9075' 8960' 21N 9125' 8978' 21P 9135' 8981' 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 for oing is t u - an. .+ r; c to the best of my knowledge. ,, f /( Signed: Joe Lastufk ' le: Drilling Technologist Date:1/2t PBU C -01 203 -010 312 -147 Prepared By Name/Number. Joe Lastufka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: David Johnston, 564 - 5985 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 -01A, Well History (Pre Rig Sidetrack) Date Summary 04/18/12 T /I /O /OO =SSV /0/150/0, Temp =SI. PPPOT -T (PASS), pre CTD. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, all moved freely (2.5 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 04/20/12 RAN 20' X 3.70" DUMMY WHIPSTOCK TO 8595'SLM (TARGET 8900'MD). 04/21/12 RAN 10' X 3.70" DUMMY WHIPSTOCK & 2 1/2" SAMPLE BAILER TO 8595'SLM. (TARGET DEPTH 8900') BAILER EMPTY. RAN 3.72" CENT, 3' X 1 7/8" , 3.80" & SAMPLE BAILER TO 9116'SLM. BAILER EMPTY. RDMO. 05/07/12 CTU #9 1.75" Job scope: Mill out 3.725" XN Nipple, 3.7" Dummy whipstock drift, Set CIBP. RU. MU w/ 3.13" external dimple CTC, 13" DCV, 3.38" Hyd Disco, 3.13" Circ sub, 3.13" LH VIP Motor, 3.8" LH Diamond Parabolic Mill. Pumped 100bbIs of 1% KCI, 100bbIs of KCL +safelube down backside for well kill. Followed by 20bbls of 60/40 for FP. RIH w/ milling toolstring. Dry tagged 3.725" XN Nipple @8385ctmd. PUH. Tagged again at the same depth. Painted flag. Milled through XN Nipple. Backreamed through the same twice. Made a dry run w/ no overpull. POOH. FP coil. RIH w PDS logging tools & dummy whipstock. 05/08/12 CTU #9 1.75" Job scope: Mill out 3.725" XN Nipple, 3.7" Dummy whipstock drift, Set CIBP. POOH w/ 3.7" dummy Whipstock drift, GR/CCL toolstring. At surface confirmed good logging data. RIH w / 4.5" CIBP. Corrected flag depth. Set CIBP an. 8900' middle of joint. POOH. At surface. Perform PT on CIBP to 2400psi. Good test. Start RD. 05/19/12 T /I /O = 280/160/0. Conduct PJSM. Cycled MV, SSV, SV. Closed SV and SSV. Bled off pressure and performed LTT. (passed). Rigged up lubricator with 4" CIW 'H' TWC # 286 using 1 -1' ext. PT'd lubricator to 200 -300 psi. low for 5 min. (passed) and 3500 psi. high for 5 min. (passed). Set TWC tagging at 114 ". Bled off TWC. Closed SSV and SV, bled off pressure and rigged down lubricator. Attached CIW pulling tool. Rigged up lubricator. Torqued all flanges on tree to API specs (see log). PT'd lubricator to 200 -300 psi.low for 5 min. (passed) and 3500 psi. high for 5 min. (passed). Opened SV and SSV. Ran polish rod down to 6" above TWC and PT'd tree to 200 -300 psi. low for 5 min. (passed) and 4900 psi. high for 5 min. (passed). Charted and documented. Pulled TWC, closed SSV and SV. Bled off pressure and rigged down lubricator. PT'd tree cap to 500 psi. (passed). 05/22/12 T /I /O /OO = 180NAC/160/0. Temp = SI. Bleed WHPs to 0 psi (Pre CTD). No AL. T FL © surface. OA FL @ surface. Bled TP to slop trailer from 180 psi to 0 psi in 1 minute. Bled OAP to slop trailer from 160 to 0 psi in 1 minute. Monitored for 30 min, all pressures remained at 0 psi. Job complete. Final WHPs = ONAC /0/0. Could not verify OOA valve position, cellar full of water. SV, WV = C. SSV, MV = 0. IA, OA = OTG. 00A = ?. 11:30. 05/23/12 T /I /O= SSV /0/70/0 +. Temp= SI. Obtain cellar water sample (Pre -CTD). No AL. Water in cellar appears to be snow melt, sample collected. 06/14/12 T /I /0 /00 = ONAC /110/1. Temp =SI. Bleed WHPs to 0 psi (Pre CTD). WH and FL have been removed. OA is cemented to surface. Bled OAP from 110 psi to 0 psi in <1 min. Held open bleed on OA for 1 hr. Monitor during rig down. OAP unchanged. Job incomplete. Final WHPs= ONAC /0/1. SV,WV,SSV = Closed. MV =Open. IA,OA,00A =OTG. NOVP. (0430 hrs). Page 1 of 2 • • C -01A, Well History (Pre Rig Sidetrack) Date Summary 06/20/12 T /I /O /00 = SSVNAC /110/0. Temp = SI. Bleed OAP to 0 psi. (CTD Prep). No flowline, AL or wellhouse. OA cemented to surface. OOAP taken from tree gauge, unable to access OOA for pressure (cellar is > 48" deep). No change in WHPs ovemight. Bled OAP from 110 psi to 0 psi in < 1 min. Monitored for 1 hr. OAP increased 27 psi. Final WHPs = SSVNAC /27/0. SV, WV, SSV = C. MV = 0. IA & OA = OTG. Unable to verify OOA valve position. NOVP. 02:45 Hrs. 06/22/12 T /1 /0 /00 =1Nac /110/ ? ?. Temp =SI. WHPs (pre CTD). WHPs unchanged since 6/22/12. Unable to get OOAP due to cellar depth. SV, WV, SSV =C. MV =O. IA &OA =OTG. OOAP = ? ?. NOVP. 1345. 06/23/12 T /I /0= SI /0/100 Conducted PJSM w /crew; P.T. O/A (charted) to 300 psi /3500 psi (passed); Removed blind & installed 3" FMC 5000 psi valve to existing O/A valve (piggy backed) torqued all flange nuts /studs to spec.; P.T. (charted & downloaded) to 300 psi /3500 psi (passed); Pre Nordicl Page 2 of 2 • • f ly % - APE No Common Well Name: C -01 Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/26/2012 End Date: 7/8/2012 X3-01 1 YM C: (2,208,377.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 12/3/1972 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'46.408 "8 Long: 0148 °40'04.344 "W Active Datum: C -01A: @63.84ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 6/26/2012 17:00 20:20 3.33 MOB P PRE PREP RIG FOR MOVE. WARM UP MOVING SYSTEM. 20:20 20:30 0.17 MOB P PRE NORDIC C AROUND SUPERINTEND RIG IN PREPARATION T OL ON FOR MOVE. HOLD PRE -RIG MOVE SAFETY CAT ME WIG CR, NORC FIELD SUPT, TOOLPUSHER RI , AND WSL. DISCU S OBSTACLES ETING ON PAD, POSITION EW DI OF EQUIPMENT, PLANNED ROUTE, E -STOP FUNCTION, STOP SIGNALS, CLEAR & CONCISE RADIO COMMUNICATION AND SPOTTER POSITION. 20:30 - 21:45 1.25 MOB P PRE RECONFIRM THAT THERE IS NO PRESSURE ON TREE, 0 PSI ON TUBING AND ANNULUS AND ALL VALVES CLOSED. PULL OVER C-01. ACCEPT RIG AT 21:00 HRS. 21:45 22:00 0.25 MOB P PR DISCUSS WORKING A E HOLD PJSM BEFORE REMOVING TREE CAP. T HEIGHT, WORKING WITH PRESSURE AND WELL BARRIERS. CONFIRM PRESSURE TESTING OF TREE BODY AND VALVES WITH PRE -RIG TEST CHARTS AND VALVE SHOP FOREMAN. 22:00 00:00 2.00 MOB P PRE VERIFY LEAKTIGHT TEST ON SWAB, LOOSEN BOLTS AND REMOVE TREE CAP. SPOT CUTTINGS BOX, TIGER TANK. POSITION E QUIPMENT. PREP FOR OPERATIONS. 6/27/2012 00:00 01:30 1.50 MOB P PRE CONTINUE WORKING ON RECOVERY OF TREE CAP AND PREPARING FOR OPERATIONS. CALL TIGER OUT TANK FOR HARDLINE CREW TO RIG UP . 01:30 - 02:50 1.33 MOB P PRE LOWER DOWN BOP AND NIPPLE UP TO TREE. MOB P ANNOUNCES H2S IN T 02:50 - 03:10 0.33 PRE PERFORM RIG EVACUATION DRILL; DRILLER HE PITS AND SLB DRILLER SOUNDS EVACUATION ALARM. ALL CREW ON LOCATION GATHER AT MUSTERPOINT WITHIN LESS THAN 5MINS. 03:10 - 03:30 0.33 MOB P PRE COMPLETE NIPPLING UP BOP, INSTALL MUD - BUCKET ON RIGFLOOR 03:30 - 04:30 1.00 MOB P PRE OPEN HCR AND KILL SIDE CHECK VALVE, AND GREASE MUD CROSS. 04:30 - 05:30 1.00 BOPSUR P PRE RIG UP 2 -3/8" TEST -JOINT FOR TESTING BOPE. FUNCTION TEST BOPE FROM OPS CAB AND DRILLERS CONSOLE. MEANWHILE HARDLINE CREW COMPLETE PRESSURE -TEST ON SURFACE LINE TO TIGERTANK. 05:30 06:00 0.50 BOPSUR P PRE FLUID -PACK MUD GAS SEPERATOR. 06:00 - 06:45 0.75 BOPSUR P PRE CREW CHANGE 06:45 07:00 0.25 BOPSUR P PRE PJSM TO SHELL TEST BOP STACK TO START TESTING BOP'S Printed 7/9/2012 10:11:42AM Common Well Name: C -01 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/26/2012 End Date: 7/8/2012 X3 -011 YM-C: (2,208,377.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 12/3/1972 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °1746.408 "8 Long: 0148°40'04.344'W Active Datum: C -01A: @63.84ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 08:00 1.00 BOPSUR P PRE PERFORM LOW & HIGH PRESSURE TESTS FOR SHELL TEST GOOD LOW PT, INCREASE TO HIGH PT 4500PSI 08:00 - 08:30 0.50 BOPSUR P PRE FAILED HIGH PRESSURE TEST, FOUND LEAKING CHOKE VALVE SERVICE VALVE AND RETEST 08:30 - 09:00 0.50 BOPSUR P PRE GOOD TEST 09:00 - 09:45 0.75 BOPSUR P PRE GOOD SHELL TEST, CALL STATE INSPECTOR 09:45 - 17:00 7.25 BOPSUR P PRE START BOPE WITH STATE INSPECTOR LOU GRIMALDI WITNESSIN? TEST 17:00 - 17:45 0.75 BOPSUR P PRE PU INJECTOR TO MU CTC TO TEST THE PACK -OFF, LUBRICATOR & INNER REEL VALVE 17:45 - 18:00 0.25 BOPSUR P PRE PULL TEST CTC TO 35K, GOOD PULL TEST PRESSURE TEST COIL CONNECTOR 18:00 - 18:45 0.75 BOPSUR P PRE STAB ON WELL TO PT INNER REEL VALVE, LUBRICATOR & PACK OFF. 18:45 - 19:00 0.25 BOPSUR P PRE CIRCULATE THROUGH REEL TO ENSURE REEL IS FLUID - PACKED. 19:00 - 19:30 0.50 BOPSUR P PRE CLOSE INNER REEL VALVE AND PERFORM PRESSURE -TEST AGAINST INNER REEL VALVE, PACK -OFF'S AND LUBRICATOR. TEST TO 300PSI / 5MINS AND 3.500PSI / 5MINS. ACHIEVE GOOD TEST AND BLEED OFF PRESSURES. STATE INSPECTOR LOU GRIMALDI ACCEPTS BOP -TEST. 19:30 - 21:45 2.25 BOPSUR P PRE EMPTY OUT MUD FROM PITS #3 & #4 TO BE IN COMPLIANCE WITH NORDIC FLUID MANAGEMENT POLICY WHEN RIH. LOAD KCL INTO PITS. PUMP SLACK FORWARD WITH 60BBLS COIL VOLUME. 21:45 - 22:30 0.75 BOPSUR P PRE MAKE UP BHI UQC. 22:30 - 23:30 1.00 BOPSUR P PRE PRESSURE -TEST CHECK VALVES TO 300PSI / 5MIN AND 3,500PSI / 5MINS. OBSERVE MINOR LEAK ON TEST - PLATE. BLEED OFF AND CHECK TEST - PLATE. CLEAN UP TEST -PLATE AND RE- INSTALL SAME. REPEAT TEST AND ACHIEVE A GOOD TEST ON CHECK VALVES. MEANWHILE CHECK LOW PRESSURE ALARMS ON THE SSV -PANEL AND OPEN UP SSV. 23:30 - 00:00 0.50 BOPSUR P PRE MAKE UP JETTING NOZZLE (BHA #1) AND STAB ON INJECTOR. PRESSURE -TEST QUICK TEST SUB (QTS) TO 250PSI / 5MINS AND 3,500PSI / 5MINS. 6/28/2012 00:00 - 00:15 0.25 BOPSUR P PRE COMPLETE PRESSURE - TESTING QUICK TEST SUB (QTS). 00:15 - 00:30 0.25 BOPSUR P PRE HOLD PJSM. DISCUSS THE UPCOMING STEPS OF INITIAL WELL ENTRY. DISCUSS HOW TO MANAGE ACTIVE SYSTEM (STRAPPING OF PITS & TIGER TANK) AND HOW TO REACT IF GAS IS OBSERVED IN RETURNS. Printed 7/9/2012 10:11:42AM i, ,s/r 6r,':^' i V Common Well Name: C -01 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/26/2012 End Date: 7/8/2012 X3 -011 YM-C: (2,208,377.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 12/3/1972 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'46.408 "8 Long: 0148°40'04.344'W Active Datum: C -01A: @63.84ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 01:00 0.50 BOPSUR P PRE CLOSE IN CHOKE, OPEN SWAB WITH 23.5 TURNS AND MASTER VALVE WITH 23.5 TURNS. FLOWCHECK WELL FOR 15MINS. ACHIEVE GOOD NO -FLO. 01:00 - 02:50 1.83 BOPSUR P PRE START RIH WITH BHA #1 AT 100FT /MIN, HOLDING 100 - 150PSI BACKPRESSURE ON CHOKE. IA = 85PS1 / OA = OPSI / OOA = OPSI 02:50 - 03:25 0.58 BOPSUR P PRE TAG CIBP AT 8,915'. PICK UP TO 8,909' AND DISPLACE WELL TO KCL. PUMP AT -3.5 BPM WITH 1,465 PSI CIRC PRESSURE. 03:25 - 05:20 1.92 BOPSUR P PRE WELL TURNED TO KCL NOW. HAVE NOT SEEN ANY INDICATION FOR GAS THROUGHOUT. SWAP FROM KCL TO 8.6 PPG DRILL MUD AND DISPLACE WELL TO MUD. CONTINUE PUMPING AT -3.5 BPM AND POOH AT 100FP /MIN (SLOWER THAN 80% FLUID VELOCITY). IA = 88PS1 / OA = OPSI / OOA = OPSI 05:20 - 05:30 0.17 BOPSUR P PRE PULL TO SURFACE AND FLOWCHECK. OBTAIN GOOD NO FLOW. 05:30 - 06:45 1.25 BOPSUR P PRE POP OFF INJECTOR AND LD BHA #1. 06:45 - 07:00 0.25 WHIP P WEXIT PJSM TO MU WS BHA 07:00 - 08:00 1.00 WHIP P WEXIT MI 1 WS BHA 08:00 - 10:20 2.33 WHIP P WEXIT RIH 10:20 - 12:45 2.42 WHIP P WEXIT TIE IN 12:45 - 13:25 0.67 WHIP P WEXIT GAMMA TIE IN COMPLETED -30' CORRECTION PUH TO 8600' TO LOG CCL 13:25 - 13:30 0.08 WHIP P WEXIT CCL IS ON DEPTH, CONFIRM WITH LEO'S AND ODE AND WE HAVE A GREEN LIGHT TO SET THE WHIPSTOCK 13:30 - 13:40 0.17 WHIP P WEXIT PUH TO 8811.7' - BULLNOSE TO TOWS= 15.7' 8811.7 - 15.7 = 8796',TOWS AS PER OPS NOTE WS SHEARED OUT AT 2300 PSI, ZERO WOB AND STACK WEIGHT TO ENSURE WS IS SET. 6.5K DOWN ON WS WITH NO MOVEMENT, CLEAN PU @ 32K FLOW CHECK WELL 13:40 - 15:20 1.67 WHIP P WEXIT POOH PVT= 326 BBLS 15:20 - 15:30 0.17 WHIP P WEXIT FLOW CHECK WELL, TRIP SHEET IS SHOWS CORRECT DISPLACEMENT, 0 LOSSES OR GAIN 15:30 - 16:40 1.17 WHIP P WEXIT REMOVE INJECTOR AND LD THE WS BHA 16:40 - 18:00 1.33 STWHIP P WEXIT MU INJECOTR TO BHA AND RIH 18:00 - 19:40 1.67 STWHIP P WEXIT LOG TIE IN PASS FROM 8,545' TO 8,635.8' AND APPLY -28' CORRECTION. Printed 7/9/2012 10:11:42AM Common Well Name: C -01 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 6/26/2012 End Date: 7/8/2012 X3 -011 YM-C: (2,208,377.00 ) Project: Prudhoe Bay Site: PB C Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 12/3/1972 12:00:OOAM Rig Release: Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °17'46.408 "8 Long: 0148°40'04.344'W Active Datum: C -01A: @63.84ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:40 - 20:00 0.33 STWHIP P WEXIT SHUT DOWN PUMPS AND DRYTAG TOP OF WHIPSTOCK (TOWS) AT 8,798' WITH 3K LBS DOWN WEIGHT. PICK UP TO 8,785' AND BRING MUD PUMPS ONLINE. TAKE SCR'S: PUMP #1: PUMP #2: 2.7 BPM - 3,040 PSI - 115 SPM2.7 BPM - 2,975 PSI- 115 SPM 1.0 BPM - 1,635 PSI - 42 SPM1.0 BPM - 1,545 PSI - 45 SPM 0.5 BPM - 1,225 PSI - 23 SPM0.5 BPM - 1,230 PSI - 22 SPM U lin 20:00 - 21:20 1.33 STWHIP P WEXIT RIH DOWN FROM 8,790' AT 1 FT /MIN, TAG /��!/I W TOWS AT 8,797.4' AND COMMENCE TIME G,016 MILLING THE 1ST FOOT AT 1FT /HR. SEE INCREASE IN MOTORWORK FROM FREESPIN AT 3,270PSI TO 3,300PSI. MOTOR DOES NOT STALL. WOB = 1.31K LBS / CIRC PRESSURE _ 3,311PSI / FREESPIN = 3,270PSI @ 2.74BPM. PVT = 325BBLS. HALF WAY THROUGH 1ST FOOT (8,797.80'): WOB = 1.31K LBS / CIRC PRESSURE = 3,289PSI 21:20 - 21:40 0.33 STWHIP P WEXIT FIRST FOOT MILLED. AS PER BAKER BTT HAND'S RECOMMENDATION, CONTINUE MILLING WITH HIGHER WOB. WOB = 2.45K LBS / CIRC PRESSURE = 3,303PSI / PVT = 329BBLS. 21:40 - 22:15 0.58 STWHIP P WEXIT MILLING AHEAD. AS THE MILL IS GETTING MORE AND MORE ENGAGED WITH THE TUBING WALL, OBSERVE AN INCREASE IN WOB AND CIRC PRESSURE. WOB = 2.57K LBS / CIRC PRESSURE = 3,354PSI / PVT = 330BBLS. 22:15 - 22:30 0.25 STWHIP P WEXIT WOB COMES UP TO 3.2K LBS. PAUSE TIME - MILLING AND ALLOW MILL TO DRILL OFF. 22:30 - 00:00 1.50 STWHIP P WEXIT CONTINUE MILLING WOB = 3.5K LBS / CIRC PRESSURE = 3,325PSI / PVT = 331 BBLS. 6/29/2012 00:00 - 01:35 1.58 STWHIP P WEXIT CONTINUE MILLING WINDOW FROM 8,800' TO 8,801'. SEE STEADY WOB BETWEEN 3.4K LBS AND 3.6K LBS, HOWEVER ONLY VERY LITTLE DIFF PRESSURE / MOTORWORK OF <100PSI. CIRC PRESSURE RANGES FROM 3,280PS1 TO 3,314PSI. 01:35 - 01:45 0.17 STWHIP P WEXIT NOTICE INCREASE IN WELL HEAD PRESSURE FROM -'40PSI TO 114PSI. INDICATION FOR MICROMOTION PLUGGING UP, CLEAR UP MICROMOTION. Printed 7/9/2012 10:11:42AM • • • \ "t li ly .. ■ 36 • 38 ? in 11-118 PROJECT • in ° ■ 4 C —PAD i z _e- • 35 — N — I 23 • • 3 I t a' 0 s $ §iN ? VICINITY MAP NTS • 2 24 • lik OF A4 c -19 Ar 2/ 25 • r. s a 4 49 -la » tr +1 P'w51Yi • 34 .�.�1 m »n » .» - C- PAD `. icilor F. Allison » • • 30 1 1. a • 8 SURVEYOR'S CERTIFICATE ❑ 32 1 HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS AS —BUILT REPRESENTS A SURVEY LEGEND MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL AS —BUILT CONDUCTOR DIMENSIONS AND OTHER DETAILS ARE CORRECT AS OF JULY 13, 2012. • EXISTING WELL CONDUCTOR NOTES: 1. DATE OF SURVEY: JULY 13. 2012. 2. REFERENCE FIELD BOOK: NS12 -36 PG's. 52 -56. 3. COORDINATES ARE DATUM NAD 27, ALASKA STATE PLANE, ZONE -4. GRAPHIC SCALE 4. GEODETIC COORDINATES ARE NAD 27. 0 50 100 200 5, HORIZONTAL & VERTICAL CONTROL IS BASED ON C —PAD OPERATOR MONUMENTS. } 01 1 6. VERTICAL DATUM IS BPX MSL. 7. C —PAD SCALE FACTOR: 0.9999306. ( IN FEET ) 8. WELL C -1 WAS BEST FIT BETWEEN ADJACENT WELLS 2 AND 34. 1 inch = 100 ft. LOCATED WITHIN PROTRACTED SEC. 19, T. 11 N., R. 14 E., UMIAT MERIDIAN, ALASKA WELL A.S.P. PLANT GEODETIC I GEODETIC I CELLAR SECTION NO. COORDINATES COORDINATES POSITION(DMS) POSITION(D.DD) 1 BOX ELEV. OFFSETS 1 F. Robert ORAMN' Y= 5,959,705.73 N= 2449.27 70'17'46.405" 70.2962236' 34 9' 3763 FSL C -1 X= 6 E= 2000.28 148'40'04.319" 148.6678664' 881 FEL -, woLF ____ __ __,_ „_._. ,__ Ct�'. JAB S___._ bn DAtE _... __ I r � ORANI7 NG. -21 -12 ,.__.,... _— .,_.._... ._.«.-- . --... IJ „.__,....._. ;, FRB12 WOC 01 _ SHEET: — p OC p WOA C —PAD _-- _- .-- -_.._� _ IS R 'SCALE 1” AS —BUILT WELL LOCATION 1 OF 1 00 7-21-12 21 SSUE0 FOR INFORMA110N .rzw , °° 1 = 100' WELL C -1 WI MOM VIM NO. DATE REVISION BY CHK ~Oa, wNM NOW 'MEE= 4' CPN 41110 ViELU-EAD= McEVOY C -0 1 A SAFETY NOTE WELL ANGLE > 70' fa 9114'. *"4-112 CHROME TBG*** ACTUATOR= OTIS KB. B_EV = 638. 137 COIDUCTOR H 98' p 10 .., 1 BP13..B/ = 38' KOP= 5100' , .•,' V, 18-5/8 CSG, 96.50, -1 62, 1--)‹ •:: 1 440 I g *49 Mix Angle = 91' 0 9751. K-55 BlItS, • • • ...4 1 1993' Hi-Es caleirER P . . , Datum LD= 8911' 13 = 17.657 1 s, • ■ 210017 - 1' 9-5/7 MR, 171 Datum 1VD = 8800' SS 19-5/8' CSG PATCI-I, 400, L-80 Tak ID= 9.825" H 2015' II I 200T Haorrom OF cauvr 1 i 1 2012' H -' lEBK SEAL ASSEMBLY 1 1 13-3/8' CSG, 689, NT-80, 13= 12.415' H 2161' I-- Pr zuw H4-1/2' FES X NF', ID = 3.813' I 9-5/1 tr;OC -1_ 220T 2161' H13-318- X9-5/8' X0. D= 8.681' 1 9-5/7 FOC MED. GAS UFT IMICRELS 118-5/7 CSG, 109.350, K-55 MRS, 13 = 17.563' H 2506' I--A ST LO TVD DEV TYFE VLV LATCH PORT MTh 111 4 3194 3194 1 FAG MK FE 0 01/09/10 3 5510 5509 5 WAG DMY RK 0 01/09/10 19-5/8" X 7' BOT LPT & MR HGR, ID= 7 H 7484' 2 7035 7029 3 FAG DAY RK 0 1706/06 ci 1 8091 8081 4 KBG2 DM( BK 0 10106/06 1 9-5/7 CSG, 470, N-I30 MRS, D= 8.081* H 8015' 1 8128' 1 FES X NP, ID = 3.813" 1 Minimum ID = 3.725" @ 8400' 4-1/2" HES XN NIPPLE ,,:. ,:, 8201' HT" X 4-1/7 BKR S-3 FKFL D = 3.870' 1 4-1/2' 1BG, 12.80, 13-CIO YAM TOP, 97 1 8234' H4-1/7 FES X NP 0 = 3.813'J .0152 bpf, D = 3.958' 8304' Hr x 4- vr UNDUE OVERSHOT 1 17LIBING 811.8 (TAGGE) 09126106) H 8300' I 8335' 1 FES X NP, ID = 3.813" 1 :4 ■:.1 8356' H7' X 4-1/2' BM S-3 FKR, D = 3.875" 1 1 8379' H4-1/7 FES X NP. D = 3.813" 1 1 8400' H4-1/7 FES XN P.? MLLE) T03.80' (05/07/12) 1 1 TBG, 12.60, L-80, .0152 bpf, D = 3.958' H 8412' 1 i 1 8412' H4 MEG 13= 3.958' 1 • 8414' H7' X 5' BKRZXP FICR IN/ L.F1R HGR, D = 4.417 1 8427' H5' X 4-1/2' XO, 1)= 3.990' 1 ( intP5 1TOP OF W-FSTOCK H 8554' vzi V1 PA_LOUT IAODOW(C-01A) 8554 1 r UR, 29#, t4-80 BTRS, .0371 bpi, D= 6.184" H - 8554 l' .4 4V 8900' H GBP (05/06/12)1 1,• • *A.., I ,,I s PERFORATION SULWAR( b.'“■11■11A I 9095' H4-1/7 mkRxER.rr I REF LOG MAVIGIVRORBAR ON 02/20/03 el :• li 8925' 43" ■ ANGLE AT TOP FERF: la .••••••., t: *•••. 9130 H cep ( ymcw09 ) 1 ....-:-.... 2te: Refer to Roduclion DB for historical perf da SEE SW 1013WAL Opn/Sqz DATE . 9975' FWD 3-3/8' 6 8925 - 8935 C 07/1909 °14k 3-317 6 9110 - 9120 C 07/19/09 2-1/2' 4 9380 - 9969 C 02/20103 IRSH-FASORLL FLUG (11115/06) H 99TT CID11 ' e: .11111LV 141/2 LP, 12.89, L-80 BT .0152 bpf, D= 3.958' H 10059' DA1E REV BY CO1.940415 1 DATE REV BY MAWS FRUDFIDE BAY UFO 02123/78 OFIGINAL COMPLETION 02/01/10 JLWPJC MSC CORRECTIONS HELL C-01A 03/14/90 PRO 05/14/12 JJUJI0 MUD XN/ SET CEP (05/07-08/12 PERMIT Mx 2030100 02122/03 cac.nac RIG SIDETIMCK (C 05/14/12 JIAD TVC/S & 70' ANGLEADDED 1 AR No: 50-029-20121-01 10/06108 D16 MVO 05/16/12 PJC DRANNG CORRECTIONS/FERFS SEC 19, T11N, R14E, 1515.91' RI_ & 881.67 Fa 11/15/06 FILIAPJC RSH-FASCRLL CONS (/ 9977' 07/27/09 _ KJ13/PJC CEP/ FS (07/199) 11 BP Exploration (Alaska) _ • • L--' . . SEAN PARNELL, GOVERNOR ! _ _.. ALASKA OIL AND CAS 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 Q BP Exploration (Alaska), Inc. 0 c3 k° P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C -01A Sundry Number: 312 -147 Fe APR 1 6 ail . Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 1 ' / Cath P. Foerster Chair DATED this i day of April, 2012. Encl. STATE OF ALASKA / RECEIVED 7 6 `� % OIL AND GAS CONSERVATION COM SSION f/ #S PQ� 1 APPLICATION FOR SUNDRY APPROVAL APR 10 2012 p , e 0 20 AAC 25.280 r+^^ 1. Type of me quest: t.1 �../ V YP q ❑ Abandon w 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 203 - 010 . 3. Address: ❑ Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 50 029 - 20121 - 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 -01A . Spacing Exception Required? ❑ Yes ® No • 9. Property Designation: 10. Field / Pool(s): ADL 028305• Prudhoe Bay Field / Prudhoe Bay Oil Pool. 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10059' • 9023' . 9975' 9022' 9130' 9974' Casing Length Size MD TVD Burst Collapse Structural Conductor 98' 30" 98' 98' Surface 2508' 18 -5/8" 2508' 2508' 930 870 Intermediate 8015' 13 -3/8" x 9 -5/8" 8015' 8005' 5020 2270 Production Liner 1092' 7" 7462' - 8554' 7454' - 8541' 8160 7020 Liner 1652' 4 -1/2" 8407' - 10059' 8395' - 9023' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8925' - 9969' 8875' - 9021' 4 -1/2 ", 12.6# 13CR80 / L -80 8412' Packers and SSSV Type: 7" x 4 -1/2" Baker 'S -3' Packer Packers and SSSV 8201' / 8191' 7" x 4 -1/2" Baker 'S -3' Packer MD (ft) and TVD (ft): 8355' / 8344' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: May 1, 2012 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG I Suspended • 17. I hereby certify that th= foregoing is true -nd correct to the best of my knowledge. Contact Dave Johnson, 564 -4171 Printed Name ,, n , c, ,g A Title Engineering Team Leader ,/ r Prepared By Name /Number: Signatur= Phon 564 - 4711 Date ( � Joe Lastufka, 564-4091 Commission Use Only Conditi • s of approval plotify Commission so that a representative may witness � t 1 f� Sundry Number: `-� ❑ Plug Integrity lig BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance 3$06 pf&L &-, P 77:;-c--- c f `�, - me 2s - ;taco Other: A � iK Af t"' P 'feu_ e, A.".0 L-�`lrcr �''�� i • I Subsequent Form Required: fit© 4/6 Approved By: / ✓�,�Z APPROVED BY COMMISSIONER THE COMMISSION Date J Form 10-403 Revised 01010 Submit In Duplicate // 0 i � Wz --- v /2 /7_, e t s • • To: Alaska Oil & Gas Conservation Commission a From: David E Johnston by CTD Engineer Date: April 5, 2012 Re: C -01A Sundry Approval Sundry approval is requested for well C -01A. C -01A was a rotary sidetrack drilled in Feb 2003 and completed as a Zone 2A with 589' of perforations. The well came on strong and produced fulltime until late 2004 when it was shut -in for IAxOA communication. In Oct 2006 a RWO was completed, and the well produced fulltime until mid 2008 when it began cycling for • high GOR. In July 2009, a CIBP was set to isolate production from the lateral, and 10' of Z2A & 10' of a Z2B lens were shot. Unfortunately, production did not change significantly and C- 01A continued to cycle. On 1/12/2010 a WRP was set at 9,000' to isolate Z2A and only allow the Z2B lens to flow. The well flowed for -3 months before cycling for high GOR. The WRP was pulled in Sept 2011 in hopes that Z2A had recharged during the -1.5 yr shut -in period. When POP'ed, the well tested above marginal GOR. C -01A is currently cycling with degrading production and ontime. � e �� 4e 47 q (,o, 6 , A ‘ �S tL/4.k T A, (Fit avrrD , j a► 4' 'IT 4n• a( ,/ REASON FOR SIDETRACK w ig oA nce /kid prOAte Qt q/fvr na#1 . fo4i4cK,y 714 ivul To q /we hv.t Anotof /t Vel f�l ✓k/ .'ft'',''P /rv C -01A is no longer a competitive producer due to a h gh GOR, and there are no 7f remaining wellwork options. This makes a coil sidetrack the best plan forward. The / proposed sidetrack will access reserves in a -40 acre Zone 2A target in central C -pad. • /2_ The The proposed plan for C -01 B is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around June 1, 2012. C -01A will be isolated with C -01 B's primary cement job. The sidetrack, C -01 B, will exit the existing 4.5" liner and kick off to land in zone 2A. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. Pre -Rig Work: (scheduled to begin May 1, 2012) 1. S Dummy GLV's (Done 1/9/2010) 2. F MIT -00A to 600 psi (Failed 4/1/2012) 3. F MIT -OA to 1,200 psi (Failed 4/1/2012) 4. F MIT -IA to 3,000 psi (passed 3/30/2012) 5. E Mill XN nipple at 8400' with Well Tech 6. E Dummy whipstock drift to 8,900' 7. F Load and kill well 8. E Set 4 -1/2" packer whipstock at 8,850' (KB Packer is for lost circulation prevention only, not for P&A of C -01A perforations). 9. F MIT -KB Packer whipstock to 2,400 psi for 30 min 10. 0 AC -LDS; AC- PPPOT -IC, T 11.0 PT MV, SV, WV 12. 0 Bleed gas lift and production flowlines down to zero and blind flange 13. 0 Remove wellhouse, level pad l • • Rig Work: (scheduled to begin on June 1, 2012) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Mill 3.8" window at 8,850' and 10' of rathole. Swap the well to drilling mud. 3. Drill Build: 4.25" OH, 350' 4. Drill Lateral: 4.25" OH, 2,075' with resistivity 'r 5. Run 3 -1/4" x 2 -7/8" solid liner leaving TOL at 8,700' 6. Pump primary cement leaving TOC at 8,700', 25 bbls of 15.8 ppg liner cmt planned 7. Cleanout liner and MCNL /GR /CCL log 8. Test liner lap to 2,400 psi. 9. Perforate liner per asset instructions ( -200') 10. Freeze protect well, RDMO Post -Rig Work: 1. Re- install wellhouse and FL's. 2. Generic GLV's David E. Johnston CTD Engineer 602 -2720 CC: Well File Sondra Stewman/Terrie Hubble , TREE= 4" CM/ • I , WELLHEAD = McEVOY C -01 A S NOTE: * * *4 -1/2" CHROME TBG* ** ACTUATOR = OTIS KB. ELEV = 63.8' 130" CONDUCTOR H 98' l- •' -∎ • BF. ELEV = 38 .4 ► 411 • KOP = 5100' 18 -5/8" CSG, 96.5 #, -I 625' V ► �� • Max Angle = 91 97 51' K -55 BTRS, . ■ ��A 1993' g @ • I 1993 H HES CEMENTER 1 Datum MD = 8911' ID = 17.655" i� ► iii • I 2007' H 9 -5/8" PBR, 12'1 Datum TV D = 8800' SS • .� .! • I9 -5/8" CSG PATCH, 40 #, L -80 TCII, ID = 9.625" H 2015' 1 I I 2007' I-1 BOTTOM OF CEMENT I J' 2012' i 9 -5/8" TIEBK SEAL ASSEMBLY I 113 -3/8" CSG, 68 #, NT -80, ID = 12.415" I-1 2161' I I 2104' 1-14-1 /2" HES X NIP, ID = 3.813" ( ( 9 -5/8" FOC 2207' I 2161' H 13 -3/8" X 9 -5/8" XO. ID = 8.681" I 9 -5/8" FOCI --I 2369' 1 118 -5/8" CSG, 109.35 #, K -55 BTRS, ID = 17.563" H 2508' FA GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 8400' IF 4 3194 3194 1 MMG DMY RK 0 01/09/10 3 5510 5509 5 MMG DMY RK 0 01/09/10 4-1/2" HES XN NIPPLE 2 7035 7029 3 MMG DMY RK 0 10/06/06 1 8091 8081 4 KBG2 DMY BK 0 10/06/06 TOP OF 7" LNR I-) 7462' 0 7484' I-19-5/8" X 7" BOT HGR PKR I 19 -5/8" CSG, 47 #, N-80 BTRS, ID = 8.681" 1-1 8015' ' I 8128' H4 -1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13 -CR80 VAM TOP, - I 8297' 0 I 8201' 1-17" X 4 -112" BKR S -3 PKR, ID = 3.870" .0152 bpf, ID = 3.958" , 8234' H 4-1/2" HES X NIP, ID = 3.813" I (TUBING STUB (TAGGED 09 /26/06) H 8300' 8304' -17" x 4 -1/2" UNIQUE OVERSHOT I 1 1 8335' -14-1/2" HES X NIP, 10 = 3.813" I Z 0 8355' -17" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 8379' -14-1/2" HES X NIP, ID = 3.813" I 1 8400' -14-1/2" HES XN NIP, ID = 3.725" I 14-1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" H 8412' I---le- ' 8412'1-14-1/2" WLEG, ID = 3.958" I 1 8414' -17" X 5" BKR ZXP PKR W/ LNR TOP HGR, ID = 4.410" I 'TOP OF WHIPSTOCK H 8554' 8427' -15" X 4-1/2" XO, ID = 3.990" I PERFORATION SUMMARY MILLOUT WINDOW (C -01A) 8554' - 8567' REF LOG: MWD /GR/ROP /EWR ON 02/20/03 , ANGLE AT TOP PERF: 43° @ 8925' ` Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE ►1•4•4•1•1�4 90 95 ' - 14 - 1/2" MARKERJT) 3 -3/8" 6 8925 8935 0 07/19/09 i4. - ` 3 -3/8" 6 9110 9120 0 07/19/09 .: :� 9130' 1 -I CIBP(07/19/09) I 2-1/2" 4 9380 - 9969 C 02/20/03 :•:•:•:•:•:4: ..iviiv1.. k y 1 1 1001� 4 11 1111 •• ` 9975' PBTD I 1111111 • 17" LNR, 29 #, N-80 BTRS, .0371 bpf, ID = 6.184" I 92' '' 14.1:11 I FISI+FASDRILL PLUG (11/15/06) I 9977' CTDM v == I4 -1/2" LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" I 10059' .1, DATE REV BY COMMENTS DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT 02/23/78 ORIGINAL COMPLETION 11/15/06 RLM/PJC FISH - FASDRILL DEBRIS @ 9977' WELL: C-01A 03/14/90 RWO 07/27/09 KJB /PJC CIBP / PERFS (07/19/09) PERMIT No: '2030100 02/22/03 DAC /KK RIG SIDETRACK (C -01A) 02/01/10 JLW /PJC MISC CORRECTIONS API No: 50- 029 - 20121 -01 10 /05/06 D16 RWO 02/27/10 JCM/SV SET WRP (01/12/10) SEC 19, T11N, R14E, 1515.91' FNL & 881.67 FEL 10/22/06 PC / PJC DRLG DRAFT CORRECTIONS 09/22/11 RCT/ PJC PULL WRP (9/2/11) 11/02/06 KSB/TLH GLV C/O BP Exploration (Alaska) I � WELLHEAD = McEVOY • C-01 B SY NOTE: * * *4 -1 /2" CHROME TBG * ** ACTUATOR= OTIS proposed CTD sidetrack KB. ELEV = 63.8' 30" CONDUCTOR — 98' A - ■ 4 1 BF. ELEV = 38' � • KOP = 5100' 18 -5/8" CSG, 96.5#, 625' X ,,.l Max Angle = 11 @ 9751' K -55 BTRS, O 1993 -IHES CEMENTER Vi Datum MD = 8911' ID = 17.655" � 4 Datum TV D = 8800' SS ■ • • 2007' H 9-5/8" PBR 12' J 2007' H BOTTOM OF CEMENT 9 -5/8" CSG PATCH, 40 #, L -80 TCII, ID = 9.625" - I 2015' J 2012' H 9 -5/8" TIEBK SEAL ASSEMBLY 13 -3/8" CSG, 68 #, NT -80, ID = 12.415" H 2161' ' ,\ 2104' H 4 -1 /2" HES X NIP, ID = 3.813" 9 -5/8" FOC H 2207' 2161' — 13 -3/8' X 9 -5/8' XO. ID = 8 -681" I 9 -5/8" FOC H 2369' 118 -5/8" CSG, 109.35#, K -55 BTRS, ID = 17.563" H 2508' kT MD TVD DEVATYPE MANDRELS 118-5/8" PORT DATE 4 3194 3194 1 MMG DMY RK 0 01/09/10 Minimum ID = 2.377" @ —9350' 3 5510 5509 5 MMG DMY RK 0 01/09/10 2 7035 7029 3 MMG DMY RK 0 10/06/06 3-1/4" x 2 -7/8" XO 1 8091 8081 4 KBG2 DMY BK 0 10/06/06 4 TOP OF 7" LNR H 7462' 7484' - 19 - 5/8" X 7" BOT HGR PKR I 9 -5/8" CSG, 47 #, N-80 BTRS, ID = 8.681" H 8015' { - 4 I I 8128' — 14 - 1/2" HES X NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, 13 -CR80 VAM TOP, H I 8297' 8201' � 7" X 4 -1/2" BKR S -3 PKR, ID = 3.870" .0152 bpf, ID= 3.958" I 8234' H4 HES X NIP, ID = 3.813" TUBING STUB (TAGGED 09 /26/06) H 8300' \ \ \-- 8304' H7" x 4 -1/2" UNIQUE OVERSHOT I 8335' H4 - 1/2" HES X NIP, ID = 3.813" TSGR = 8,411' MD 0 8355' H 7" X 4 -1/2" BKR S -3 PKR, ID = 3.875" 8379' H4 -1/2" HES X NIP, ID = 3.813" I 8400' —14 -112" HES XN NIP, ID = 3.80" milled out 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I-1 8412' 1 J 8412' H 4 -1/2" WLEG, ID = 3.958" TOP OF WHIPSTOCK H 8554' M 8414' H 7" X 5" BKR ZXP PKR W/ LNR TOP HGR, ID = 4.410" MILLOUT WINDOW (C -01A) 8554 ' - 8567' 8427' 5" X 4-1/2" XO, ID = 3.990" 21 Top of 3 -1/2" liner and cement @ - 8,700' / PERFORATION SUMMARY 3 -1/2" x 3 -1/4" XO 2 -7/8" liner TD @ 11,275' REF LOG: MNVD/GR/ROP /EWR ON 02/20/03 no , ANGLE AT TOP PERF: 43° @ 8925' I Note: Refer to Production DB for historical perf data P �_�� SIZE SPF INTERVAL Opn /Sqz DATE 3 2 ° � ` 3 -1/4" x 2 -7/8" XO © - 9,350' 3 -3/8" 6 8925 - 8935 0 07/19/09 • :r :. I 9095' H4 -1/2" MARKER JTI 3 -3/8" 6 9110 - 9120 0 07/19/09 :1:1:1:1:1:1 -- 2 -1/2" 4 9380 - 9969 C 02/20/03 a , ' , ' % , ' . 9130' OBP (07119!09) *# * ** , -1 /2" packer whipstock / � � 1 9975' H FBTD 11.1 ��• . 8,850' 17" LNR, 29#, N-80 BTRS, .0371 bpf, ID = 6.184" 92 e t IFISH- FASDRILL PLUG (11/15/06) 9977' CT DM 4 =�� ♦ •`=V 4 -1/2" LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" -1_ 10059' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/23/78 ORIGINAL COMPLETION 11/15/06 RLM/PJC FISH - FASDRILL DEBRIS @ 9977' WELL: C-01B 03/14/90 RWO 07/27/09 KJB /PJC OBP/ PERFS (07/19/09) PERMIT No: 'n30100 02/22/03 DAC /KK RIG SIDETRACK (C -01A) 02/01/10 JLW /PJC MISC CORRECTIONS AR No: 50- 029 - 20121 -01 10/05/06 D16 RWO 02/27/10 JCM'SV SET WRP (01/12/10) SEC 19, T11 N, R14E, 1515.91' FNL & 881.67 FEL 10/22/06 PC/ PJC DRLG DRAFT CORRECTIONS 09/22/11 RCT/ PJC PULL WRP(9 /2/11) 11/02/06 KSB/TLH GLV GO 03/21/12 WJH proposed CTD sidetrack BP Exploration (Alaska) NORDIC - CALISTA RIG 1 CHOKE / REEL /CIRCULATION MANIFOLD DIAGRAM V12 M V,. 7- 1/16" 5000 psi BOP's ID = 7.06" V15 V11 17 1/16" 6000 psi, OX-46 Transducers 0 III III I OOR BO t., V V2 i Vi V 16 —666 iY— y± EGASSE Note tvp"ca BOP arrangement for 2316" coiled tubing dr IrM C W �eMY A•� 'j 7 1/16" 6000 psi. RX-46 ., III �i 'a_` 3 V 17 HCR IC 1K OK ,,, To Poor Boy Gas Bust �i� I 1174 It V18 V19 C I , • 2 1/16" 5000 psi , 11)(.24 9.00'5000 Par HCR I .= ■ .....061 �� 2-1/16” 5000 pin CHECK VALVE Manual Choke _ ° 11 1 ∎ 1 11 71/16 Cameron FOV Gate I • a� Valve x 5000 i1 - MEOH /Diesel r Pal FP Line CoFIeX Hose . =. 1/4 Turn Nalco r r r r r 10WOG To Produclon Tree or Cross Over • II T • ress e transducers CoFIeX Hose N11 0 11 0/12 To Coiled Tubing Bleed OM Inner Reel Valve .. •- - mi. - I 0/13 ■ Cement Line In Ground Level Tie - in N10 <^t i J CV3 CV2 T Stand Pipe _ - __ _ - all _ Manual Choke ■ - -.. '•• -- — Pressure Transducers . _ 1 = / # N9 Mokon 0 MINIMIE � � CV17 " i 1111P, " CVt VOW OM Tiger Tank Mud Pump 2 u In F rom 1 MINN • ► O Baker MP 1 & MP 2 Choke • • CV14 to Pits Rig Floor t Mud Pump 81 40 CV16 Reverse Ci • i • ' i CIr CT whle ••' allM ill L d l \ O • • To Manifold CV15 1- Jun -2010 41 Reverse Cirndafinn line I CT while OM CoFIeX Hose Page l of l Subject: FW: INT ENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and f` 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 STATE OF ALASKA ' ALASKA IIIAND GAS CONSERVATION COMMISSICID REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other Ell PULL PLUG Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ - 203 -0100 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ' 50- 029 - 20121 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028305 „ PBU C -01A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10059 feet Plugs (measured) 9130 feet true vertical 9022.64 feet Junk (measured) 9977 feet Effective Depth measured 9975 feet ii t # ,• ,:) �1 t � 'Packer (measured) 7484 8201 8355 feet true vertical 9021.55 feet ' (true vertical) 7476 8191 8344 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 98' 30” 38 - 136 38 - 136 Surface 588' 18 -5/8" 96.5# K -55 37 - 625 37 - 625 930 870 Surface 1883' 18 -5/8" 109.3# K -55 625 - 2508 625 - 2508 2860 1270 Intermediate 2125' 13 -3/8" 68# NT -80 36 - 2161 36 - 2161 5020 2270 Production 1980' 9 -5/8" 40# L -80 35 - 2015 35 - 2015 5750 3090 Production 6003' 9 -5/8" 47# N -80 2012 - 8015 2012 - 8005 6870 4760 Liner 7" 29# N -80 7462 - 8567 7454 - 8554 8160 7020 Liner 4 -1/2" 12.6# L -80 8407 - 10059 8395 - 9023 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4 -1/2" 12.6# 13Cr80 34 - 8306 34 - 8295 4 -1/2" 12.6# L -80 8304 - 8412 8293 - 8400 Packers and SSSV (type, measured and true vertical depth) 7" BOT Packer 7484 7476 4 -1/2" Baker S -3 Perm Packer 8201 8191 4 -1/2" Baker S -3 Perm Packer 8355 8344 5" Baker ZXP Top Packer F I IED 8402 12. Stimulation or cement squeeze summary: Intervals treated (measured): SEP - 8 2011 Treatment descriptions including volumes used and final pressure: Alaska Oil & Gas Cons. Commission 13. Representative Daily Average Production or Injectf Data Oil-Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 414 23,953 25 1,858 Subsequent to operation: 605 36,047 33 1,402 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development El - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ` la Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed Na - oe Lastu' a A Title Petrotechnical Data Technologist 1 Signatk re 1, �_ Phone 564 -4091 Date 9/28/2011 Form • ' _1 Rovis' ` ;; DMS S td, 1011 1.z ?. tr "•� Submit Original Only J C-01A 203 -010 . PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base C-01A 2/20/03 PER 9,380. 9,969. 9,010.68 9,021.47 C-01A 7/11/06 BPS 8,500. 9,969. 8,487.46 9,021.47 C -01A 10/27/06 BPP 8,500. 9,969. 8,487.46 9,021.47 C -01A 7/19/09 APF 8,925. 8,935. 8,874.63 8,881.9 C -01A 7/19/09 APF 9,110. 9,120. 8,973.15 8,976.56 C -01A 7/19/09 BPS 9,130. 9,969. 8,979.72 9,021.47 C -01A 1/12/10 BPS 9,000. 9,130. 8,924.2 8,979.72 C -01A 9/2/11 BPP 'd 9,000. 9,130. 8,924.2 8,979.72 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 • • • C -0 1A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY � ..,�t y s sq 9 �. Z�7 $Y'+d4 % '�'� f :','+.-' �: , tr>�- r4_i"�"ta, " �. f'� tTYDAT.Et :... ' . . ` I � 0,M4' $a: 1� 'Y t a. .: ? P r.� "` "` A � x -e.X: �£. r �, � � 2Y��A. °��.`C'n R�.� 1�A "'.u''h.t�'- 9/1/2011 ** *WELL SHUT IN ON ARRIVAL * ** (profile mod) DRIFT W/ 3.70" CENT AND 3.25" LIB, IMPRESSION OF FILL @ 8986' SLM. :BAIL W/ 10'x3.0" PUMP BAILER @ 8981' SLM. ** *JOB CONTINUED ON 9/2/11 * ** 3 i 9/2/2011 ** *JOB CONITNUED FROM 9/1/11 * ** (profile mod) BAIL ON 4 -1/2" WRP @ 8979' SLM W/ 3.0" PUMP BAILERS (rec —2 gal of sand). PULL 4 -1/2" WRP FROM 8979' SLM (several small chunks of rubber element lost). ** *WELL TURNED OVER TO DSO * ** { FLUIDS PUMPED BBLS 1 DIESEL 1 TOTAL TREE = 4" CIW WELLHEAD`= McEVOY • C 1 A SAFETY ti: * * *4 - 1/2" CHROMETBG* ** ACTUATOR = OTIS KB. ELEV __.._ 63. 8' ' 130" • CONDUCTOR H 98' U : * - BF. ELEV = 38 �� • KOP = _ 5100' 18 -5/8" CSG, 96.5 #, - 625' : ► Max Angle = 91 @ 9751' K 55 BTRS, �� ji� " Datum MD = 8911' • � 0,1 1 1993 H HES CEMENTER 1 ID = 17.655" .' 1 2007' 1-19 5/8" PBR, 12'1 Datum TV D = 8800' SS •- & . I9 -5/8" CSG PATCH, 40 #, L -80 TCII, ID = 9.625" 1-1 2015' 1 ' 1 2007' H BOTTOM OF CEMENT 1 41 2012' -19 -518" TIEBK SEAL ASSEMBLY I 1 13 -3/8" CSG, 68 #, NT -80, ID = 12.415" H 2161' 1--- V 2104' 1- 14 -1/2" HES X NIP, ID = 3.813" I 1 9 -5/8" FOCI-1 2207' J 2161' 1 - 113 - 3/8" X 9 -5/8" XO. ID = 8.681" I 1 9 -5/8" FOCI -1 2369' 1 118 -5/8" CSG, 109.35 #, K -55 BTRS, ID = 17.563" H 2508' IA , GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 8400' 4 3194 3194 1 MMG DMY RK 0 01/09/10 3 5510 5509 5 MMG DMY RK 0 01/09/10 4 -1/2" HES XN NIPPLE 2 7035 7029 3 MMG DMY RK 0 10/06/06 1 8091 8081 4 KBG2 DMY BK 0 10/06/06 1TOP OF 7" LNR H j 7462' e 7484' H9-5/8" X 7" BOT HGR PKR ( 1 9 -5/8" CSG, 47 #, N-80 BTRS, ID = 8.681" 1 8015' ' 1 8128' H4 -1/2" HES X NIP, ID = 3.813" 1 4 -1/2" TBG, 12.6 #, 13 -CR80 VAM TOP, - 8297' ►•� 1 8201' 1-17" X 4 -1/2" BKR S-3 PKR, ID = 3.870" 1 .0152 bpf, ID = 3.958" II 8234' 1 - 14 - 1/2" HES X NIP, ID = 3.813" I 1TUBING STUB (TAGGED 09/26/06) H 8300' 8304' H7" x 4 -1/2" UNIQUE OVERSHOT 1 1 , 8335' I-14 -1/2" HES X NIP, ID = 3.813" I C1 8355' 1 X 4 -1/2" BKR S -3 PKR, ID = 3.875" I 8379' H4 -1/2" HES X NIP, ID = 3.813" 1 • 8400' H4 -1/2" HES XN NIP, ID = 3.725" 1 14 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" 1 - 1 8412' 1 8412' H4 -1/2" WLEG, ID = 3.958" 1 8414' H 7" X 5" BKR ZXP PKR W/ LNR TOP HGR, ID = 4.410" 1 1 TOP OF WHIPSTOCK H $554' 8427' H5" X 4-1/2" X0, ID = 3.990" 1 PERFORATION SUMMARY MILLOUT WINDOW (C -01A) 8554' - 8567' REF LOG: MWD /GR/ROP /EWR ON 02/20/03 ANGLE AT TOP PERF: 43° @ 8925' ` Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE ►�•4•4•�•�•« 1 9095' 1-14 112" MARKER JTl 3 -3/8" 6 8925 - 8935 0 07/19/09 1,4,.:-.10.1 +♦ 3 -3/8" 6 9110 - 9120 0 07/19/09 . p3 , ` 9130' 1 -I CIBP (07/19/09) 2 -1/2" 4 9380 - 9969 C 02/20/03 .:*:.: 7 - W / • , �'� a ♦ � ' l t � �ti 9975' --1 PBTD I * : •. +4 G 1 7" LNR, 29 #, N -80 BTRS, .0371 bpf, ID = 6.184" 1-1 92 "'' CW4 1FISH- FASDRILL PLUG (11/15/06) 1 9977' CTDM _: `> 14 -1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" 1-1 10059' �. DATE REV BY COMMENTS DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT 02/23/78 ORIGINAL COMPLETION 1 11/15/06 RLM/PJC FISH - FASDRILL DEBRIS @ 9977' WELL: C-01A 03/14/90 RWO = 07/27/09 KJB /PJC CIBP / PERFS (07/19/09) PERMIT No: 2030100 02/22/03 DAC /KK RIG SIDETRACK (C -01A) 02/01/10 JLW /PJC MISC CORRECTIONS API No: 50- 029 - 20121 -01 10/05/06 D16 RWO 02/27/10 JCM/SV SET WRP (01/12/10) SEC 19, T11 N, R14E, 1515.91' FNL & 881.67 FEL 10/22/06 PC / PJC DRLG DRAFT CORRECTIONS 09/22/11 RCT/ PJC PULL WRP (9/2/11) 11/02/06 KSB/TLH GLV C/0 BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 d t F MCS/A/SD August 22, 2011 41JG 31 2011 Alaska OH & to ", Mr. Tom Maunder . man Alaska Oil and Gas Conservation Commission Anctrarags 333 West 7 Avenue .� �� Anchorage, Alaska 99501 a03 Subject: Corrosion Inhibitor Treatments of GPB C -Pad c i Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C - 01A 2030100 50 0292012101 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 -068 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 -128 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 -258 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 • • ~~ ._ ~~ MICROFILMED Q3/01/2008 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F: ~LaserFiche\CvrPgs_Inserts~Miicrafilm_Marker. doc . . WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Cornrn. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 November 13, 2006 RE: MWD Formation Evaluation Logs: S-106_PB1, S-112, S-205, C-OlA, 2T-218, P2-57A. The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 S-106_PBl: dO I-Old-. if 1L./3~ Digital Log Images: 50-029-22999-00, 70 1 CD Rom S-112: u:¡:~ QO;).-13S- IÞ IL/~/ Digital Log Images: 50-029-23099-00 5 .gIS;' 4fo¿{e.dwrðV\.~- S 205: U.:r:.c..<90d- S-~ d: 1t../3'9-d Digital Log Images: 50-029-23107-00 1 CD Rom 1 CD Rom C-OIA: 963 -bl 0 :ç- ¡LlnÖ Digital Log Images: c-i"''''''''NED JAN 3 0 2007 50-029-20121-01 ~. 1 CD Rom 2T-218: ;)63 -0 if ~ }L/3--:J- I Digital Log Images: 50-029-20449-00 1 CD Rom P2-57A: ,;JDd- -é)I~ -4 IL/ó{ð1 Digital Log Images: 50-029-22183-01 1 CD Rom RECEIVED OCT 2 3 2006 ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERA TIÐNS1¡¡ & Ga~ Cons. COOlmission . STATE OF ALASKA . h n~hlìfaíJe 1. Operations Performed: Repair WellŒ Stimulate 0 OtherD Abandon 0 PlulJ PerforationsD Alter CasingD Pull TubingOO Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development ŒJ ExploratoryD ':Ii! ?n~n1nn 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20121-01-00 7. KB Elevation (ft): 9. Well Name and Number: 63.S0 C-01A 8. Property Designation: 10. Field/Pool(s): ADL-02S305 Prudhoe Bay Field I Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10059 feet true vertical 9023.0 feet Plugs (measured) None Effective Depth measured 9975 feet Junk (measured) None true vertical 9022.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 9S 30" Stove Pipe 3S - 136 3S.0 - 136.0 SURFACE 2469 1S-5/S" 109.35#/96.5# K-55 39 - 250S 39.0 - 250S.0 2S60 1270 PRODUCTION 2130 13-3/S" 68# NT-SO 40 - 2170 40.0 - 2170.0 5020 2270 TIE-BK PROD 1975 9·5/S" 40# L-SO 40 - 2015 40.0 - 2015.0 5750 3090 PRODUCTION 600S 9-5/S" 47# N-80 2007 - 8015 2007.0 - 8005.0 6870 4760 LINER 1092 7" 29# N-80 7462 - 8554 7454.0 - 8541.0 8160 7020 LINER 1652 4-1/2" 12.6# L-SO 8407 - 10059 8395.0 - 9023.0 8430 7500 ~~MN~ífJ' c C " ~,<,,, "i;~·';;;"::; /. Perforation depth: Measured depth: 9380-9969 True vertical depth: 9011-9021 Tubing ( size, grade, and measured depth): 4-1/2"12.6# 13Cr80 @ 42 . S306 4-1/2" 12.6# L-80 @ 8304 - 8412 Packers & SSSV (type & measured depth): 9-5/8" Packer @ 2007 9-5/S" BOT HGR Packer @ 7484 RBDMS BFl 7" Baker 5-3 Packer @ 8201 2 :J 2DDfi 7" Baker 5-3 Packer @ S355 7" Baker ZXP Packer @ 8420 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: RWO work completed -.- ran and cemented 9-5/S" Tieback Liner and replaced tubing with 4-1/2" Chrome tubing. 13 Representative Daily Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casino Pressure TubinIJ Pressure Prior to well operation: 51 0 0 --- 0 Subsequent to operation: SI 0 0 -- 0 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 _ ~ OilŒ] 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. TSUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr 306-227 P~inted Name~ayne R. SCh~~ Title Petroleum Engineer Phone 564-5174 Date 1 0/20/06 SIgnature ~..ð( Form 10-404 Revised 4/2004 !R\G\NAL o . . C-01A DESCRIPTION OF WORK COMPLETED EVENT SUMMARY AWGRS 07/09/2006 T/I/0=1890/260/300. Temp=SI. WHP's, FLs (pre-Eline). TBG FL @ 6546'. IA FL @ 5344'. OA FL near surface. AWGRS 07/11/2006 SHOT TWO STRAND STRING SHOT FROM 8293'-8305', SHOT SMALL CHARGE TUBING PUNCHER FROM 8272'-8283', SET HALIBURTON 3.66" FAS-DRILL PLUG AT 8500' MID-ELEMENT DEPTH. ALL SHOTS FIRED. AWGRS 07/15/2006 T/I/O/OOA= 2250/1500/840/50 CIRC-OUT (PRE RWO) Pumped 5 bbls neat, 200 bbls 1 % kcl down tubing, up the IA taking returns down the flowline to production. AWGRS 07/16/2006 T/I/O/OOA= 2250/1500/840/50 CIRC-OUT (PRE RWO) Pumped 706 bbls 1% kcl down tubing, up the IA taking returns down flowline to production. Pumped 151 bbls diesel down IA. U-tube TxlA to freeze protect. CMIT TxlA PASSED to 3500 psi. Pumped 8.5 bbls diesel to pressure up TBG/IA to 3500 psi. 1 st test lost 80/80 on TBG/IA in 1 st 15 min, 2nd 15 min lost 40/40 on TBG/IA. Flowline was not freeze protected per Pad Operator. Bled pressures down. Final WHP's= 0/0/700/50 AWGRS 07/17/2006 CHEMICALLY CUT TUBING AT 8304' USING A 3-5/8" SEVERING HEAD AND ANCHOR BODY. PLUG, TUBING PUNCHER AND STRING SHOT DONE 11-JUL- 2006. NO PROBLEMS RIH OR POOH. GOOD INDICATION OF CUT. WELL LEFT SHUT IN AND TURNED OVER TO DSO. JOB COMPLETE. AWGRS 07/20/2006 T/IAlOAlOOA = VacNac/590/20. Temp = S/I. Bleed WHPs to 0 psi (pre PPPOT, RWO). Bled OA to 170 psi in 2 hrs. Bled OOA to 0 psi in 30 min. OOA gained 2.5 psi in 30 min. Final = VacNac/170/2.5. AWGRS 07/21/2006 T/IAlOAlOOA = VacNac/170/? Temp = S/I. Bleed WHPs to 0 (pre-PPPOT, RWO). Bled OA to 0 psi. Final = VacNaclO/? AWGRS 07/22/2006 T/IAlOA = 260/0/0 (Pre-Rig Workover Inspection) PPPOT-IC = PASSED PPPOT-T = PASSED Bled Casing hanger void to 0 psi. Functioned and torqued alllockdowns to 550 ftIlbs. Installed Packing tool and energized "Y" seals. Rigged up test equipment. Pumped until clean fluid returns were achieved. Pressured up void to 3,800 psi. for 30 mins. - Passed Bled tubing hanger void to 0 spi. Torqued lockdown screws to 550 ftIlbs. Installed test equipment and pumped until clean returns were achieved. Pressured up tubing hanger void to 5,000 psi. for 30 mins. - Passed AWGRS 07/24/2006 T/I/0/00=ONAC/37/9 Temp=SI Bleed WHPs to 0 psi (pre-RIG) Bled OOAP from 9 psi to 0 psi in 5 minutes. Bled OAP from 37 psi to 0 psi in 90 minutes (fis). Monitor for 15 minutes. No change in pressures. Final WHPs=ONAC/O/O. AWGRS 07/25/2006 TII/O/OO= ONac/10/0+. Temp=SI. Monitor WHP's (pre rig). Bled OAP from 10 psi to 0+ psi in 5 min. Final WHPs= ONac/O+/O. AWGRS 08/17/2006 Temp= S/I MIT OA 1000 psi ***POST-PONED*** (Post-RWO) - Post-poned due to 2 of 8 bolts missing on OOA flange. Notified pad operator, DSM & co rep. Tagged OOA. AWGRS 08/18/2006 TII/0/00=1000/960/0/0. (Ann Comm post RWO). MIT OA to 1000 psi. Passed on third test. Lost 80 psi in first 15 minutes & 20 psi in second 15 minutes. Bleed OA pressure down to 0 psi. FWHP=1050/960/0/0. Page 1 . . C-01A DESCRIPTION OF WORK COMPLETED AWGRS 09/10/2006 T/I/O=930/98010/9, Temp=SI, No AIL. Bleed WHP's to 0 psi (pre BPV). TBG FL @ surface, IA FL @ surface. Bled TBGP to production from 930 psi to LP 230 psi in 30 min, lAP decreased to 230 psi. Switched bleed to slop oil trailer. Bled lAP from 230 psi to 0 psi in 1.25 hrs (fluid) returned 1.5 bb/s fluid, TBGP decreased to 12 psi. Bled TBGP from 12 psi to 0 psi in 10 min (gas). Bled OOAP from 9 psi to 0 psi in 20 seconds (gas). Monitored pressures for 30 min, TBGP remained unchanged, lAP went on vac, OAP went on vac, OOAP increased to 0+ psi. Flow line needs FP FWHP= ON ACN AC/O+. AWGRS 09/10/2006 SET BPV. PRE RIG DIMS 09/24/2006 Move Rig From B-Pad to C-01, MIRU,Circulate Out Freeze Protection, Displace to Sea Water. DIMS 09/25/2006 NID Production Tree, N/U BOPE, Test BOPE, Pull Hanger, UD Tubing. AWGRS 09/25/2006 pulled a 6" ciw twc thru bop's. DIMS 09/26/2006 DIMS 09/27/2006 DIMS 09/28/2006 DIMS 09/29/2006 DIMS 09/30/2006 DIMS 1 0101/2006 DIMS 10102/2006 DIMS 10103/2006 DIMS 10104/2006 DIMS 10105/2006 UD 41/2" Tbg, M/U BHA #1 Tbg Dress Assembly, P/U 4" HT-38 DP, Circ high Vis Sweep, POOH with BHA #1 RlU SWS and Run USIT Log, Run 4 Strand String Shot, RID SWS, M/U and Run 9 5/8" RBP, Set RBP at 2,490', Displace Well to 9.8 ppg Brine. Test RBP, POOH, N/D BOPE, N/D Tbg Spool, N/U Spacer Spool, N/U BOPE, Pull Csg from PBR at 2,007', Circ Out Artic Pack, UD 11 3/4" x 9 5/8" Thermocasing, UD 103/4" Csg. UD 10 3/4" Csg, M/U Csg Scraper and RIH to PBR, Circulate Sweeps, POOH, RlU and Run 9 5/8" Csg. Run 9 5/8" Csg, Attempt to Sting into PBR, UD 9 5/8" Csg, M/U 11 1/2" Polishing Mill, RIH RIH, Dress PBR, POOH, RlU and Run 9 5/8" Csg, CMT 9 5/8" Csg, N/D and Set Emergency Slips. N/U and Test BOPE, M/U BHA #4, RIH, Drill CMT and ES Cementer. Clean Out and Test 9 5/8" Csg, Clean Sand Off of HES RBP, RIH, Pull RBP, CBU, UD 4" DP, RlU and Run 41/2" 13 CR80 K-Bear Tbg Run 41/2" Tbg, Reverse in Inhibited fluid, Set and Test Packer, N/D BOPE, N/U Tree Page 2 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/24/2006 10/6/2006 Spud Date: 12/3/1972 End: 10/6/2006 9/24/2006 00:00 - 00:30 0.50 MOB P PRE Move Rig Off Well B-02A. 00:30 - 02:00 1.50 MOB P PRE Bridle Up , Prepare Derrick to UD, Set BOPs on Stand, Install Booster Wheels and Test Same. 02:00 - 03:00 1.00 MOB P PRE PJSM, Lay Down Derrick, Secure to Stand. 03:00 - 11 :00 8.00 MOB P PRE Move Rig from B-Pad to C-Pad. Hydraulic Drive Motor Failure, Replaced Motor. 11 :00 - 13:00 2.00 MOB P PRE Rig Down Rear Boosters. Install BOPs on Pedestel, Set Rig Mats. 13:00 - 15:00 2.00 MOB P PRE PJSM Raise Derrick, Spot and Shim Rig, Spot Pump and Motor Complexes. 15:00 - 16:00 1.00 MOB P PRE RlU Floor, Spot and Berm Slop Tank, Install Double Annulus Valve. 16:00 - 17:00 1.00 MOB P PRE Prepare Pits, And Take on Sea Water. 17:00 - 18:00 1.00 MOB P PRE RlU DSM, Pull BPV, RID DSM. 18:00 - 19:00 1.00 MOB P PRE RlU to Circulate Mix Sweeps. 19:00 - 20:00 1.00 MOB P PRE Pre-Spud Meeting. PJSM on Displacing Well to Seawater, Test Pump and Lines to 3,500 psi. 20:00 - 22:00 2.00 KILL P DECOMP Pump Down Annulus, at 8 bpm wn20 psi, Taking Diesel Returns to Slop Tank. Pumped Down Tubing with 40 bbl Sweep Followed by 120 deg Sea Water, Taking Returns to Slop Tank. 22:00 - 23:00 1.00 KILL P DECOMP Monitor Well, Test Casing and Down Hole Plugs to 1,000 psi Held Pressure Test for 30 minutes. 23:00 - 00:00 1.00 KILL P DECOMP BID and RID Lines, Set and Tested TWC to 1,000 psi from Below and 3,500 psi From above for 10 minute Tests. 9/25/2006 00:00 - 01 :00 1.00 WHSUR P DECOMP Continue to Set and Test TWC, Tested to 1,000 psi From Below and 3,500 psi From Above for 10 min Tests. 01 :00 - 02:00 1.00 WHSUR P DECOMP NID Production Tree, and Adapter Flange, Clean Void, Check Hanger Threads and Cross Over. 02:00 - 04:30 2.50 BOPSU P DECOMP N/U BOPE, Cut Riser to Length, Function Test Koomey Lines. 04:30 - 05:30 1.00 BOPSU P DECOMP RlU BOP Test Equipment. 05:30 - 11 :00 5.50 BOPSU P DECOMP Test BOPE to 250 psi Low Pressure and 3,500 psi High Pressure. Each Test was Held for 5 Minutes. AOGCC Witness of Test was Waived by John Crisp. Test was Witnessed by the Doyon Toolpusher and BP WSL. Test #1- Lower Pipe Rams 4", Dart Valve Test #2- Hydrill 4", HCR Choke, HCR Kill, Choke Valves #12,13,14, TIW. Test #3- Choke Valves 9, 11, Manual Kill. Test #4- IBOP, Choke Valves #5,8,10. Test #5-Choke Valves 4,6,7, ManualIBOP. Test #6- Choke Valve #2. Test #7- 4.5" Pipe VBR. Test #8- 4.5" Annular Preventer. Test #9- HCR Choke, Blinds. Test #10- Manual Choke and Blinds. Accumulater Test- 3,000 psi Starting Pressure, 1,750 psi After Actuation, First 200 psi in 17 seconds, Full Pressure in 1 Minute 28 Seconds. 5 Nitrogen Bottles at 2,250 psi. 11 :00 - 12:00 1.00 BOPSU P DECOMP RID BOP Test Equipment. Blow Down Lines. 12:00 - 12:30 0.50 BOPSU P DECOMP RlU DSM Lubricator and Pull TWC, RID DSM. Printed: 10/9/2006 10:33:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/24/2006 Rig Release: 10/6/2006 Rig Number: Spud Date: 12/3/1972 End: 1 0/6/2006 9/25/2006 12:30 - 13:00 0.50 PULL P DECOMP Service Top Drive, Oraworks, Iron Rough Neck. 13:00 - 13:30 0.50 PULL P DECOMP M/U Landing Jt, BOLDS, Pull Hanger to Rig Floor with 135,000# Up Weight. 13:30 - 14:30 1.00 PULL P DECOMP Circulate Annular Volume at 10 bpm w/500 psi. Monitor Well 14:30 - 20:30 6.00 PULL P DECOMP UD Hanger Assembly, UD 4.5" Tubing t/3,500'. 20:30 - 21 :00 0.50 PULL P DECOMP Service Pipe Skate. 21 :00 - 00:00 3.00 PULL P DECOMP Continue to UD 4.5" Tubing. 9/26/2006 00:00 - 00:30 0.50 PULL P DECOMP Continue to POOH wI 4.5" Tubing, 4 GLMs, 1XN Nipple Assembly, and 20.65' Cut Jt. Clean Cut on Cut Jt, 0045/8". 00:30 - 01 :30 1.00 PULL P DECOMP RID Tubing Tools, Clear Rig Floor, Prepare Pipe Shed, RlU to P/U BHA #1, Set Wear Ring. 01 :30 - 03:30 2.00 CLEAN P CLEAN P/U 12- 6.25" Drill Collars and Stand Back in Derrick. 03:30 - 04:00 0.50 CLEAN P CLEAN Service Top Drive and Rig. 04:00 - 05:30 1 .50 CLEAN P CLEAN Stand back 6 1/4" DC's, UD 9 5/8" Casing Scraper Assembly. 05:30 - 09:30 4.00 CLEAN P CLEAN P/U 4 3/4" DC's, Shoe, WP Extensions, and 7" and 95/8" Casing Scrapers . 09:30 - 16:30 7.00 CLEAN P CLEAN RIH picking up 4" HT-38 OP from pipeshed to 8,283' 16:30 - 17:00 0.50 CLEAN P CLEAN Establish parameters, Up weight 162,000#, Down weight 162,000#, Rotating weight 160,000#, 2,000 ftllbs Torque at 20 rpm. Tag top of 41/2" tubing stub at 8,300', Wash over to 8,310'. 17:00 - 19:00 2.00 CLEAN P CLEAN Pump 20 bbl high vis sweep and 1 bottoms up. 2,600 psi at 11 bpm. Monitor well, well static. 19:00 - 21 :30 2.50 CLEAN P CLEAN POOH standing back 4" HT-38 DP. 21 :30 - 23:00 1 .50 CLEAN P CLEAN UD 4 3/4" DC's, Shoe and Casing Scraper Assembly. No recovery in boot basket. 23:00 - 00:00 1.00 CLEAN P CLEAN Clear and clean rig floor. 9/27/2006 00:00 - 02:30 2.50 CLEAN P CLEAN Wait on Schlumberger Wireline Services, Wireline crews were over on hours. Wait while crew rested. Perform rig service and maintenance. 02:30 - 14:00 11.50 CLEAN P CLEAN Spot and RlU wireline unit, RlU shooting nipple and pack-off. RlU and Run Usit Log. Log up from 8,100'. Corrosion level appeared to be low. 14:00 - 15:00 1.00 CLEAN P CLEAN UD 7" B USIT tool and P/U larger C USIT tool for logging 9 5/8" and 103/4" Casing. 15:00 - 16:30 1.50 CLEAN P CLEAN RIH to 2,500' and log up to 130' with USIT log. Log with USIT, Gamma, and CCL. TOC 2,014'. 16:30 - 18:30 2.00 CLEAN P CLEAN UD USIT logging tool and RlU 4 strand string shot. 18:30 - 19:30 1.00 CLEAN P CLEAN RIH with string shot, Correlate and shoot at 1,968'. POOH with fired string shot. 19:30 - 20:30 1.00 CLEAN P CLEAN RID Schlumberger wireline equipment, UD shooting nipple. 20:30 - 23:00 2.50 CLEAN P CLEAN M/U HES 9 5/8" RBP and RIH with 4" HT-38 DP to 2,490'. Set RBP. Top of RBP at 2,490' 23:00 - 00:00 1.00 CLEAN P CLEAN Displace seawater from wellbore with 120 degree 9.8 ppg Brine. 9/28/2006 00:00 - 01 :00 1.00 CLEAN P CLEAN Test HES 9 5/8" RBP to 2,500 psi for 15 minutes. Good test. 01 :00 - 02:30 1.50 CLEAN P CLEAN POOH with HES RBP running tool standing back 4" HT-38 DP. 02:30 - 03:30 1.00 CLEAN P CLEAN P/U 1 joint of 7" casing and RIH. Dump 2,200 Ibs of 20/40 mesh sand down hole. 03:30 - 05:30 2.00 WHSUR P CLEAN Nipple Down BOP stack and remove 13 5/8" x 13 5/8" McEvoy tubing spool. Secure Slips to casing. 05:30 - 08:00 2.50 WHSUR P CLEAN N/U 48", 135/8" Spacer Spool. N/U BOPE. 08:00 - 08:30 0.50 WHSUR P CLEAN Test breaks on spacer spool to 2,500 psi for 15 minutes. Good Printed: 10/912006 10:33:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/24/2006 10/6/2006 Spud Date: 12/3/1972 End: 10/6/2006 9/28/2006 08:00 - 08:30 0.50 WHSUR P CLEAN test. 08:30 - 09:30 1.00 CLEAN P CLEAN P/U Baker 9 5/8" Spear assembly with pack-off. 09:30 - 10:00 0.50 CLEAN P CLEAN Spear into 11 3/4" x 9 5/8" Thermocasing. Pull Thermocasing to rig floor. Unseat from emergency slips and pull out of PBR, Maximum pull of 210,000#. Pull emergency slips to rig floor. 10:00 - 11 :00 1.00 CLEAN P CLEAN RlU Baker false bowl and 10 3/4" slips. Remove emergency slips. 11 :00 - 11 :30 0.50 CLEAN P CLEAN Pressure test Little Red Services lines to 3,500 psi and hold for 5 minutes. Good test. 11 :30 - 12:30 1.00 CLEAN P CLEAN Release spear from casing and UD 9 5/8" spear assembly. 12:30 - 13:00 0.50 CLEAN P CLEAN RlU casing handling equipment. 13:00 - 14:00 1.00 CLEAN P CLEAN Service Top Drive and Drawworks. 14:00 - 14:30 0.50 CLEAN P CLEAN Wait on handling sub to be cut at Baker Machine. Used cut joint that emergency slips were set on and had it cut down and a 9 5/8" BTC collar threaded on. 14:30 - 15:30 1.00 CLEAN P CLEAN M/U handling sub and circulating head. Break circulation at 1.5 bpm at 800 psi. 15:30 - 16:00 0.50 CLEAN P CLEAN Pump 60 bbls of 180 degree diesel with Little Red Services. 16:00 - 16:30 0.50 CLEAN P CLEAN Pump 40 bbl Safe Surf ° sweep followed by 120 degree 9.8 ppg NaCI Brine. 16:30 - 17:00 0.50 CLEAN P CLEAN Let hot diesel soak into Artic Pack. 17:00 - 17:30 0.50 CLEAN P CLEAN Pump 120 degree 9.8 ppg NaCI Brine until good 9.8 ppg returns at surface. Artic Pack returns were mostly crude oil with a small amount of oil soaked gel. 17:30 - 18:00 0.50 CLEAN P CLEAN Monitor well, well static. Blow down and RID lines. 18:00 - 19:30 1.50 CLEAN P CLEAN UD 3 joints of 11 3/4" x 9 5/8" Thermocasing. Themocasing appeared to be in good condition with no holes or collapses. 19:30 - 00:00 4.50 CLEAN P CLEAN UD 10 3/4" BTC casing. Casing appeared to be in good condition. Break out torque 40,000 ftllbs to 45,000 ftllbs. 9/29/2006 00:00 - 05:00 5.00 CLEAN P CLEAN UD 10 3/4" BTC casing. Casing appeared to be in good condition. Break out torque 40,000 ftllbs to 45,000 ftllbs. Recovered 9 5/8" Cut off pup that emergegcy slips were set on, 3 joints of 11 3/4" x9 5/8" Thermocasing, 1 each 10' and 5' 9 5/8" pup, 9518" x 10 3/4" XC, 44 joints of 10 3/4" BTC casing, 2 joints of 9 5/8" casing, 10 3/4" x 9 5/8" XO, 1 FOC and 9 5/8" Seal assembly. Seal assembly was in good condition. 05:00 - 06:30 1.50 CLEAN P CLEAN Clean rig floor and casing handling equipment and RID same. 06:30 - 09:00 2.50 CLEAN P CLEAN P/U BHA#2, 133/8" Casing Scraper Assembly, 8 12/" bit, bit sub, 3 1/2" pup joint, 2 x XC, 133/8" casing scraper, 3 x XC, bumper sub, fishing jar, XC, XC, 12 x 6 1/4" DC's, XO. Total BHA lenght is 425.88' 09:00 - 10:00 1.00 CLEAN P CLEAN RIH with BHA #2 on 4" HT-38 DP to top of PBR at 2,015', Wash out inside PBR to 2,038'. No problems going into PBR. 10:00 - 12:00 2.00 CLEAN P CLEAN Pump 20 bbl high vis sweep around and circulate at 10 bpm with 670 psi. Still getting some Artic Pack returns mixed with brine. 12:00 - 13:00 1.00 CLEAN P CLEAN Pump 40 bbl Safe Surf ° sweep around at 12 bpm with 880 psi. Returns cleaned up. Monitor well, well static. 13:00 - 14:00 1.00 CLEAN P CLEAN POOH with BHA #2, Stand back 4" HT-38 DP. 14:00 - 16:00 2.00 CLEAN P CLEAN Stand back 61/4" DC's, UD 133/8" Scraper Assembly. 16:00 - 18:30 2.50 BOPSU P CLEAN RlU and drain BOP stack, install test plug. Install 9 5/8" rams in lower gate on BOP stack. 18:30 - 19:00 0.50 BOPSU P CLEAN Install 9 5/8" test joint and test 9 5/8" rams to 250 psi low Printed: 10/9/2006 10:33:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/24/2006 Rig Release: 10/6/2006 Rig Number: Spud Date: 12/3/1972 End: 10/6/2006 pressure and 3,500 high pressure. Hold each test for 5 minutes, Good test. 19:00 - 19:30 0.50 CLEAN RID test equipment and UD 9 5/8" test joint. 19:30 - 21 :00 1.50 TIEB1 RlU 95/8" handling equipment, RlU Torque Turn equipment for TC II threads. 21 :00 - 00:00 3.00 CASE P TIEB1 P/U 9 5/8" Seal Assembly and jewelry. P/U and Run 9 5/8" 40#, L-80, TC II casing to 425'. Bakerlock Float equipment assembly connections, Use Jet Lube Seal Guard pipe dope. Average M/U torque 12,600 ftllbs. 9/30/2006 00:00 - 02:30 2.50 CASE P TIEB1 P/U and Run 9 5/8" 40#, L-80, TC II casing from 425' to 1,992'. Use Jet Lube Seal Guard pipe dope. Average M/U torque 12,600 ftllbs. 02:30 - 04:00 1.50 CASE P TIEB1 Remove short bails and install long bails. M/U 9 5/8" TC II Pin x 9 5/8" BTC XO and 9 5/8" circulating swedge. 04:00 - 07:30 3.50 CASE P TIEB1 Establish parameters, 110,000# Up weight, 114,000# Down weight. 2 1/2 bpm at 90 psi. Slack off and tag at 2,015'. Unable to get into PBR, Attempt to work into PBR. Rotate 2 turns to attempt to get into PBR. Still unable to get into PBR. Circulate above PBR at 8 bpm with 580 psi to make sure top of PBR is clear. Attempt to work into PBR, still unable to get in PBR. 07:30 - 08:30 1.00 CASE P TIEB1 RlU to pull 9 5/8" Casing. 08:30 - 09:00 0.50 CASE P TIEB1 UD Landing joint, RID pump in swedge and lines, Break out 9 5/8" BTC Box x 9 5/8" TC II Pin XO. 09:00 - 15:00 6.00 CASE P TIEB1 UD 9 5/8" TC II casing. Use Compensator to remove joints from connection. Inspect pins and boxes. 15:00 - 16:00 1.00 CASE P TIEB1 RID stabbing board and compensator, Remove long bails and install short bails on top drive. 16:00 - 17:30 1.50 CASE P TIEB1 Break connection below baffle and stand back back 2 joints of 9 5/8" casing with cementer in derrick. Pull and inspect seal assembly. No marks on seal assembly. 17:30 - 18:30 1.00 CASE P TIEB1 Clear and clean rig floor. 18:30 - 20:00 1.50 CASE P TIEB1 Drain BOP stack, Install test plug, Remove 9 5/8" Rams and install 3 1/2" x 6" VBR's. 20:00 - 20:30 0.50 CASE P TIEB1 Test 3 1/2" x 6" VBR's to 250 psi low pressure and 3,500 psi high pressure. Hold each test for 5 minutes. Good test. 20:30 - 21 :00 0.50 CASE P TIEB1 RID test equipment, UD test joint. 21 :00 - 23:00 2.00 CASE P TIEB1 M/U BHA #3,81/2" bit, bit sub, 3 1/2" pup joint. 2 x XO's, 11 1/2" tapered mill, 2 x XO's, bumper sub, fishing jar, XO. Total BHA lenght 50.83' 23:00 - 00:00 1.00 CASE P TIEB1 RIH with BHA #3 on 4" HT-38 DP to 1,100' 10/1/2006 00:00 - 00:30 0.50 CASE P TIEB1 RIH with BHA #3 from 1,100' to 2,015', Establish parameters, Up weight 68,000#, Down weight 68,000#.120 psi at 5 bpm. Sting into PBR with 8 1/2" bit and wash to 2,037' to place 11 1/2" tapered mill at top of PBR. 00:30 - 02:00 1.50 CASE P TIEB1 Dress PBR with 11 1/2" tapered mill. 90 rpm with 5,000 ftllbs of torque. 5,000 - 10,000 WOB, 120 psi pump pressure at 5 bpm. P/U out of PBR and work through without problems. 02:00 - 03:00 1.00 CASE P TIEB1 Pump 40 bbl heated Safe Surf-O sweep around, 725 psi at 12 bpm. 03:00 - 04:00 1.00 CASE P TIEB1 POOH with BHA #3, standing back 4" HT-38 DP. 04:00 - 05:00 1.00 CASE P TIEB1 UD BHA #3 and clear floor. 05:00 - 06:00 1.00 CASE P TIEB1 Install BOP test plug and change 3 1/2" x 6" VBR's to 9 5/8" Rams. Printed; 10/9/2006 10;33;14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/24/2006 Rig Release: 10/6/2006 Rig Number: Spud Date: 12/3/1972 End: 10/6/2006 1011/2006 06:00 - 06:30 0.50 CASE P TIEB1 RlU 95/8" Test joint and equipment. 06:30 - 07:30 1.00 CASE P TIEB1 Test 9 5/8" Rams to 250 psi low pressure and 3,500 psi high pressure. Test failed. 07:30 - 09:30 2.00 CASE P TIEB1 Remove and replace 9 5/8" Rams. 09:30 - 10:00 0.50 CASE P TIEB1 Test 9 518" Rams to 250 psi low pressure and 3,500 psi high pressure. Hold each test for 5 minutes. Good test. 10:00 - 10:30 0.50 CASE P TIEB1 RID test equipment, UD 9 5/8" test joint. 10:30 - 15:00 4.50 CASE P TIEB1 P/U 9 5/8" Seal assembly(machine 2ea. 1" fluid bypass holes 2' up from bottom), between seals, Run 9 5/8",40#, L-80, TC II casing to 1,982'. Use Jet Lube Seal Guard pipe dope. Average M/U torque 12,600 ftllbs. Torque Turn all connections. 15:00 - 16:00 1.00 CASE P TIEB1 Remove short bails and install long bails. M/U 9 5/8" TC II Pin x 95/8" BTC Box XO and HES circulating head on joint #49. 16:00 - 17:00 1.00 CASE P TIEB1 Establish parameters. Up weight 110,000#, Down weight 114,000#, Stab into PBR, RlU HES cementing head. 17:00 - 18:30 1.50 CASE P TIEB1 P/U 2' and Pressure up to 500 psi, Pull up 10' till pressure releases. Circulate 20 bbls of 9.8 ppg brine 120 psi at 31/2 bpm. Drop HES ES opening plug and pump down. Plug on seat at 150 bbls pumped. 18:30 - 19:30 1.00 CASE P TIEB1 Pressure test 9 5/8" Casing to 2,000 psi for 30 minutes. Good test. Bleed off pressure and leave bleeders open, Space seal assembly 2' from being fully inserted in PBR. Pressure up to shear open HES ES Cementer, Cementer sheared open at 2,700 psi. Pump through ES Cementer with 10 bbls of 9.8 ppg brine, 6 bpm at 300 psi. 19:30 - 21 :00 1.50 CEMT P TIEB1 Line up Schlumberger Cement Unit and pump 5 bbls of 9.8 ppg brine. Pressure test lines to 4,500 psi, Good test. Pump 45 bbls of 9.8 ppg brine 5 bpm at 250 psi. Mix and pump 128 bbls of 15.8 ppg class G cement with GasBlok, initial pumping pressure 600 psi at 5.5 bpm, finial pumping pressure 720 psi at 5.4 bpm.Drop closing plug and kick out with 10 bbls of water. Swap over to rig and displace cement with 141 bbls of 9.8 ppg brine. Caught cement at 67 bbls of displacement 6 bpm at 380 psi. Pumping pressure at 120 bbls displacement 820 psi at 6 bpm, Slow rate to 2 bpm at 650 psi. Bumped plug, pressure up to close HES ES Cementer, Cementer closed at 1,500 psi, Pressure up to 1,700 psi and hold for 5 minutes. Cement in place at 20:54 hours. -10 bbls of cement back to surface. 21 :00 - 21 :30 0.50 CEMT P TIEB1 Check for flow, no flow. RID HES Cement head. Flush out annulus with Sapp. 21 :30 - 22:00 0.50 BOPSU P TIEB1 Flush out annulus valves with diesel. Pull riser and Split BOP stack. 22:00 - 00:00 2.00 WHSUR P TIEB1 Set emergency slips as per Cameron. Set up Wach's cutter and make cut on 9 5/8" casing as per Cameron. 101212006 00:00 - 00:30 0.50 WHSUR P TIEB1 UD cut off joint of 9 5/8" casing. 00:30 - 03:30 3.00 WHSUR P TIEB1 Remove 48" Spacer spool, N/U Tubing spool. Test to 2,400 psi for 30 minutes. Good test. 03:30 - 05:30 2.00 BOPSU TIEB1 N/U 15" Spacer spool, Install secondary annulus valve, N/U BOPE., Install riser. 05:30 - 06:30 1.00 BOPSU TIEB1 Remove 9 5/8" Rams from bottom gate and install 3 1/2" x 6" VBR's. 06:30 - 08:00 1.50 BOPSU TIEB1 RIU BOP test equipment. 08:00 - 13:30 5.50 BOPSU TIEB1 Safety stand down, Drillers side tugger cable socket clevis pin Printed: 10/9/2006 10:33:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: 9/24/2006 Rig Release: 10/6/2006 Rig Number: Spud Date: 12/3/1972 End: 10/6/2006 came out while under load. Swivel and tugger chain fell approximately 58' striking man on the shoulder and wrist. Perform incident investigation. Perform full derrick inspection, inspect all tugger lines and connections. Inspect swivels, cold shots, cotter pins, keepers and cables. 13:30 - 16:00 2.50 TIEB1 RlU BOP test equipment. 16:00 - 20:00 4.00 TIEB1 Test BOPE and choke manifold to 250 psi low pressure and 3,500 psi high pressure. Test with 4" and 4 1/2" test joints. Hold each test for 5 minutes. Jeff Jones with AOGCC waived witness of BOP test. Test was witnessed by Doyon Toolpusher and BP WSL. Good Test. 20:00 - 20:30 TIEB1 RID BOP test equipment and install wear bushing. 20:30 - 21 :30 TIEB1 M/U BHA #4, 8 1/2" bit, 2 x boot baskets, 95/8" casing scrapers, bit sub, bumper sub, fishing jar, 12 x 61/4" DC's, XO. Total BHA lenght equals 406.16' 21 :30 - 22:00 0.50 CEMT P TIEB1 RIH with BHA #4 on 4" HT-38 DP. 22:00 - 00:00 2.00 CEMT P TIEB1 Establish parameters, 90,000# Up weight, 90,000# Down weight, 90,000# rotating weight, 80 rpm with 2,500 ftllbs torque, 200 psi at 5 1/2 bpm. Wash down and tag at 1,997' Drill cement, closing plug and ES cementer. WOB 5,000 - 10,000 Ibs, 80 rpm with 5,000 ftllbs on bottom torque. 10/3/2006 00:00 - 00:30 0.50 CEMT P TIEB1 Drill ES cementer and cement to 2,002'. WOB 5,000 - 10,000 Ibs, 80 rpm with 5,000 ftllbs on bottom torque. 5 1/2 bpm with 200 psi pump pressure. 00:30 - 01 :00 0.50 CEMT P TIEB1 Circulate bottoms up. 10 bpm with 750 psi pump pressure. 01 :00 - 02:00 1.00 CEMT P TIEB1 Pressure test 9 5/8" Casing Tieback to 3,500 psi for 30 minutes. Good test. 02:00 - 03:30 1.50 CEMT P TIEB1 Drill out cement, opening dart and HES baffle collar. 80 rpm with 5,000 ftllbs of torque, 8,000 - 10,000 Ibs WOB, 6 bpm with 230 psi. 03:30 - 04:00 0.50 CEMT P TIEB1 RIH and tag sand at 2,440'. 04:00 - 05:00 1.00 CEMT P TIEB1 Pump 20 bbl high vis sweep chase with seawater and circculate till clean. 1,300 psi pump pressure at 13 bpm. 05:00 - 05:30 0.50 CEMT P TIEB1 POOH with 4" HT-38 DP. 05:30 - 07:00 1.50 CEMT P TIEB1 UD BHA #4 and Empty Boot Baskets. 07:00 - 08:00 1.00 CLEAN P DECOMP M/U BHA #5 08:00 - 09:30 1.50 CLEAN P DECOMP RIH with BHA #5 on DP to 2440'. Take Initial Parameters. 09:30 - 10:30 1.00 CLEAN P DECOMP Wash Sand and Debris from 2440' 2457'. Circulate around Hi- Visc Sweep at 7 bpm and 1720 psi. 10:30 - 12:00 1.50 CLEAN P DECOMP B/O and BID Top Drive. POOH from 2457'. 12:00 - 13:00 1.00 CLEAN P DECOMP Stand Back Drill Collars. B/O Rev Circ Basket. Found two large tennis ball size composite chunks. C/O Boot Baskets - all small pieces of cmt. 13:00 - 13:30 0.50 CLEAN P DECOMP MJU Boot Baskets and RIH wI DC's. 14:00 - 15:00 1.00 CLEAN P DECOMP RIH on DP and Clean Out to 2471' 15:00 - 15:30 0.50 CLEAN P DECOMP Circulate around 20 bbl High Visc Sweep at 7 bpm and 1780 psi. 15:30 - 17:00 1.50 CLEAN P DECOMP POOH and Stand Back Drill Pipe and Collars. 17:00 - 18:00 1.00 CLEAN P DECOMP B/O and C/O Reverse Basket. Found Larger Diameter Aluminium Ring in Basket and small cmt pieces in Boot Baskets. 18:00 - 19:00 1.00 CLEAN P DECOMP RIH with Reverse Basket BHA to 2,412' 19:00 - 19:30 0.50 CLEAN P DECOMP M/U and establish parameters, Up weight 92,000#, Down Printed: 10/9/2006 10:33:14 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: 9/24/2006 1 0/6/2006 Spud Date: 12/3/1972 End: 10/6/2006 10/3/2006 19:00 - 19:30 0.50 CLEAN P DECOMP weight 97,000#, Rotating weight 95,000#, 60 rpm with 2,000 ftllbs of torque, 1,950 psi pump pressure at 7 bpm. Wash down to top of HES RBP at 2,488' 19:30 - 20:00 0.50 CLEAN P DECOMP Pump 20 bbl high vis sweep around 3,480 psi pump pressure at 10 bpm. 20:00 - 20:30 0.50 CLEAN P DECOMP POOH standing back 4" Drill Pipe. 20:30 - 22:00 1.50 CLEAN P DECOMP UD 6 1/4" Drill Collars, UD Reverse baskets and clean out. No recovery in Reverse basket or junk subs. 22:00 - 22:30 0.50 CLEAN P DECOMP Clear and Clean rig floor. 22:30 - 00:00 1.50 CLEAN P DECOMP M/U HES RBP retrieving tool and RIH with 4" Drill Pipe to 1,920' 10/4/2006 00:00 - 00:30 0.50 CLEAN P DECOMP RIH with HES RBP running tool on 4" Drill Pipe from 1,920' to 2,488' Latch onto 9 5/8" RBP and release. 00:30 - 01 :00 0.50 CLEAN P DECOMP Circulate bottoms up. 1,720 psi pump pressure at 8 bpm. 01 :00 - 03:30 2.50 CLEAN P DECOMP POOH with HES 95/8" RBP, Laying down 4" Drill Pipe. 03:30 - 04:00 0.50 CLEAN P DECOMP UD HES RBP and running tool. 04:00 - 06:30 2.50 CLEAN P DECOMP M/U Mule shoe and RIH with 58 stands of 4" Drill pipe from Derrick. 06:30 - 12:30 6.00 CLEAN P DECOMP POOH and UD 4" DP. 12:30 - 14:00 1.50 RUNCO RUNCMP Clean and Clear Rig Floor. Rig Up Tubing Handling Equipment. Double Check and Lay Out Tubing Jewelry as per running order. 14:00 - 14:30 0.50 RUNCMP Inspect Derrick and Remove Ice From Derrick Structure. 14:30 - 15:00 0.50 RUNCMP PJSM with Rig Crew on running tubing string. 15:00 - 00:00 9.00 RUNCMP MIU and RIH wI 4-1/2" 12.6# 13Cr80 Completion String to 5,912'. K-Bear and Vam Top Connections. Use compensator to stab all joints and Torque Turn all connections. Average M/U torque on Vam Top connections 4,400 ftllbs, Average M/U torque on K-Bear connections 4,500 ftllbs. Use Jet Lube Seal Guard Pipe Dope. 10/5/2006 00:00 - 03:00 RUNCMP M/U and RIH wI 4-1/2" 12.6# 13Cr80 Completion String from 5,912' to 7,997'. K-Bear Connections. Use compensator to stab all joints and Torque Turn all connections. Average M/U torque on K-Bear connections 4,500 ftllbs. Use Jet Lube Seal Guard Pipe Dope. 03:00 - 04:00 1.00 RREP RUNCMP Change out hydraulic hose on pipe skate. 04:00 - 05:00 1.00 RUNCMP M/U and RIH wI 4-1/2" 12.6# 13Cr80 Completion String from 7,997' to 8,266'. K-Bear Connections. Use compensator to stab all joints and Torque Turn all connections. Average MIU torque on K-Bear connections 4,500 ftllbs. Use Jet Lube Seal Guard Pipe Dope. 05:00 - 06:30 RUNCMP RlU circulating head, Establish parameters, Up weight 130,000#, Down weight 130,000#.130 psi pump pressure at 3 bpm. Wash over tubing stubing stub at 8,300', Pump pressure increased to 200 psi, Slow pump rate to 2 bpm at 120 psi and wash down, set on shear pins, pins sheared at 10,000#, Slack off and no-go at 8,309'. Pump pressure increased to 380 psi. 06:30 - 08:00 1.50 RUNCO RUNCMP RID Clrc Head. LID Joints 201 and 202 of K-Bear Tubing. M/U K-Bear by Vam Top XO, 1 Jt of Vam Top Tubing, Hanger Assembly, and TC-II Landing Joint. No Space Out Pup Joints required, 2.07' required for 2' space out, shortest available == 2.3'. Top of OverShot Spaced out _4.0' above Top of Tubing Stub. Printed: 10/9/2006 10:33:14 AM .. . Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-01 C-01 WORKOVER DOYON DRILLING INC. DOYON 16 Start: Rig Release: Rig Number: Spud Date: 12/3/1972 End: 10/6/2006 9/24/2006 1 0/6/2006 PJSM. RlU Circ Head to Landing Joint. Reverse Circ 150 bbls of 120 degree SW and 400 bbls of SW wI Corrosion Inhibitor. 3 bpm at 550 psi. RUNCMP RID Circ Head, Drop Ball and Rod, UD landing joint. RUNCMP Line up and pump down tubing to set and test Packer, Pressure up to 3,500 psi and hold for 30 minutes. Good test. Bleed tubing side down to 1,700 psi. Pressure up on the annulus to 3,500 psi for 30 minutes, Good test. Bleed down tubing side and shear DCK valve. Pump both ways through DCK valve to insure it is open. Install TWC and test to 1,000 psi from above and below. Blow down lines and drain BOP stack. NID BOP stack and Riser. Prep wellhead and install Adaptor Flange and test to 5,000 psi for 30 minutes. Good test. N/U Tree and test for 30 minutes. Good test. RID test equipment. RlU DSM Lubricator and pull TWC, RID Lubricator. RlU Little Red Services to pump Freeze Protect. Pump 168 bbls of heated diesel freeze protect down 41/2" x 9 5/8" annulus. 550 psi at 2 1/2 bpm. RlU lines and U-tube diesel freeze protect. Install BPV and test from below to 1,000 psi for 10 minutes. Good test. RID Little Red Services. Remove secondary annulus valve. Secure tree and cellar. Rig Release at 06:00 hrs. 12:30 - 13:30 13:30 - 16:30 16:30 - 17:00 0.50 WHSUR P RUNCMP 17:00 - 19:00 2.00 BOPSU P RUNCMP 19:00 - 20:30 1.50 WHSUR P RUNCMP 20:30 - 22:30 2.00 WHSUR P RUNCMP 22:30 - 23:30 1.00 WHSUR P RUNCMP 23:30 - 00:00 0.50 WHSUR P RUNCMP 10/6/2006 00:00 - 01 :30 1.50 WHSUR P RUNCMP 01 :30 - 03:00 1.50 WHSUR P RUNCMP 03:00 - 04:00 1.00 WHSUR P RUNCMP 04:00 - 06:00 2.00 WHSUR P RUNCMP Printed: 10/9/2006 10:33:14 AM Well Job# Log Description Date BL Color CD 1-21/K-25 11226008 LDL 10/02/06 1 B-27A 11414394 LDL 09/30/06 1 M-24A 11216213 MEM PROD PROFILE 09/30/06 1 MPB-09 11212889 PROD PROFIGLS 10/06/06 1 X-08A 11414278 USIT 09/26/06 1 C-01A 11414279 USIT 09127106 1 K-11 11414765 USIT 10101106 1 A-17A 11414283 USIT 10/02/06 1 Schlumbel'gel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth . ì O· _3 .'- O~" I Ù ".J '- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 . ~r".[, .....¡(./t'\'." \""~. " ¡)".,,~¿ ~:JV3'"¡})~ .-" Date Delivered: 1 0119/06 NO. 4001 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave. Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay . . ~)\ C c Alaska Data & Consulting 2525 Gambell Street. S~'\· ,'~: Anchorage. AK 99503-...'c!.¡_. . v~ " ",,~ ATTN Beth . Received e e r-;::¡ LI ~;:::. ~ ! ~ FRANK H. MURKOWSKI, GOVERNOR AItASIiA OIL AND GAS CONSERVATION COMMISSION 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Doug Cismoski Drilling Engineer BP Exploration (Alaska) Inc. PO Box 196612 Anchorage, AK 99519-6612 ~"MÎ ¡.""'¡ j! '1\\ " . V1Jrt.¡v\:t;:;.tl v u h 0 Ü Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU c-o lA Sundry Number: 306-227 Dear Mr. Cismoski: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this -z.-iday of June, 2006 Enc!. ~þ\( 1f /Ie .c/¿)/ð6 uryt)/1;ØAJ¡¡) e STATE OF ALASKA' t.. RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION JUN 2 2 2006 APPLICATION FOR SUNDRY APPROVAL: \¡.j 6 A- (pi'-.. /1-1..;1 v Iø Pd (, /ZvP& 20 MC 25.280 Alaska Oil & Gas Cons. Commission Anr:horaop. 1. Type of Request: 0 Abandon 1m Repair Well o Plug Perforations o Stimulate o Alter Casing 1m Pull Tubing o Perforate New Pool o Waiver o Other o Change Approved Program o Operation Shutdown o Perforate o Time Extension o Re-Enter Suspended W 2. Operator Name: 4. Well Class Bef~ork: 5. Permit To Drill Number BP Exploration (Alaska) Inc. 181 Development 0 Exploratory 203-010/ 3. Address: o Stratigraphic o Service 6. API Number: . P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20121-01-00/ 7. KB Elevation (ft): 9. Well Name and Number: PBU C-01A /' 8. Property Designation: 10. Field 1 Pool(s): ADL 028305 Prudhoe Bay Field 1 Prudhoe Bay Pool 11,/(Y..·Y····. ." i .' " yY< . ...............f. )l'VI::L.L. ...........,<"},·i< 'i/ 'i.<y.f/.i!'.!i..... .'Y';<,'i{,,;'Y{, .."; Total Depth MD (ft): Total Depth TVD (ft):1 Effective Depth MD (ft): Effective Depth TVD (ft) Plugs (measured): Junk (measured): 10059 9023 9975 / 9022 8400 None Casina Length SiZé MD / TVD Burst Collapse Structural Conductor 98' 30" 98' 98' Surface 2508' 18-5/8" 2508' 2508' 930 870 Intermediate 8015' 13-3/8" x 9-518" 8015' 8005' 5020 2270 Production Liner 1092' 7" 7462' - 8554' 7454' - 8541' 8160 7020 Liner 1652' 4-1/2" 8407' - 10059' 8395' - 9023' 8430 7500 Perforation Depth MD ()/l Perforation Depth TVD (ft): I ~Size: Tubing Grade: Tubing MD (ft): 9380' - 9969' 9011' - 9021' -1/~.~'! 12.6# L-80 8412' Packers and SSSV Type: 7" x 4-1/2" Baker 'S-3' packer ....// I Packers and SSSV MD (ft): 8355' . 12. Attachments: 13. Well Class after proposed work: / 181 Description Summary of Proposal 0 BOP Sketch o Exploratory 181 Development o Service o Detailed Operations Program 14. Estimated Date for July j{J006 15. Well Status after proposed work: Commencing Operations: 181 Oil o Gas o Plugged o Abandoned 16. Verbal Approval: D~I o WAG OGINJ OWINJ o WDSPL Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Doug Cismoski, 564-4303 Printed Name Doug Cismoski Title Drilling Engineer Sicmature j)-:~"iA /:.~ ~ //'-' Date tJl :t~/ I'J~ Prepared By Name/Number¡ Phone 564-4303 Terrie Hubble, 564-4628 V Commission Use Only , Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: ~I f) - d(l7 ....., o Plug Integrity ~BOP Test o Mechanical Integrity Test o Location Clearance Other: T est- Bo ¡ì E +0 ~c;oo , v?Ç-4. RBDMS BFL JUN 2 9 2006 Subsequent Form Required: \0 - +04· j (L] )t,~OMMISSIONER APPROVED BY t· 22,.00 Approved By: THE COMMISSION Date Form 10-403 Revised 07/2005 V'-~ Submit In Duplicate 'Glr~J e e Obp G~ C-01A Rig Workover Scope of Work: Pull 4-%" completion, cut and pull 11-3/4" x 9-5/8" thermocase and 9-5/8" casing, run and cement to surface new 9-5/8" casing, run 4-%" 13CR-80 completion. MASP: 4)psi Well Ty~~ducer Estimated Start Date: July 15, 2006 Pre-ri F 1 S 2 E 3 o 4 o 5 o 6 MITOA to 2000 psi. Proposed Procedure / 1. MIRU. NO tree. NU and test BOPE to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD 4-%" tubing string to the cut. 3. US IT Log 9-5/8" casing for top of cement 4. Cut and pull 9-5/8" including 140' of Thermocase 5. Run and fully cement new 9-5/8" casing to surface 6. Run 4-%" 13CR-80 completion with Baker S-3 packer. Position packer at -8200' MD. 7. Displace the IA to packer fluid and set the packer. 8. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 9. Set BPV. NO BOPE. NU and test tree. RDMO. / · TREE = . 6" Cr-N WELLHEAD = 13-5/8" McEVOY CONVENTIONAL ACTUA TOR = OTIS KB. ELEV = 63.8' BF. ELEV = 38' KOP= 5100' Max Angle = 91 @ 9751' Datum MD = 8911' Datum NO = 8800' SS 110-3/4" CSG, 55.5#, N-80, 10 = 9.760" I 14-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 1 I 9-5/8" FOC 1 113-3/8" CSG, 68#, NT-80, ID = 12.415" 1 1 9-5/8" FOC I 118-518" CSG, 96.5#, K-55, ID = 17.655" I C-01A / 11-3/4 x 9-5/8" THERMOCASE II Minimum 10 = 3.725" @ 8400' 4-1/2" HES XN NIPPLE 1 TOP OF 7" LNR I 9-5/8" CSG, 47#, N-80, ID = 8.681" I PERFORA TION SUMMARY REF LOG: MWD GR ON 02/12/03 ANGLEATTOPPERF: 89@9380' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DATE 2-1/2" 4 9380 - 9969 C 02/20/03 4-1/2" TBG, 12.6#, L-80, .0152 bpf, 10 = 3.958" TOP OF WHIPSTOCK I TOP OF CEMENT 8750' 7" LNR, 29#, N-80, .0371 bpf, ID = 6.184" 1 9198' -i 9-5/8" FOC 1 -i 9-5/8" X 10-3/4" XO 1 -i 9-5/8" PBR. 12' I 2213' -i 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS DEV TYÆ VL V LA TCH o MMG DOME RK 7 MMG SO RK 5 MMG DMY RK 6 KBG DMY BK PORT DA TE 16 03/18/03 20 03/18/03 o 02/21/03 o 02/21/03 ST MD ND 4 3826 3826 3 5822 5819 2 7377 7369 1 8267 8256 8335' 8355' 8379' 8400' 8400' 8412' 8420' 8427' -i 9-5/8" X 7" BOT HGR PKR -1 4-1/2" HES X NIP, 10 = 3.813" I -1 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" -1 4-1/2"HESXNIP, 10=3.813" 1 -1 4-1/2" HES XN NIP, ID = 3.725" I -1 4-1/2" PXN TIP (12/05/04) 1 -j 4-1/2" WLEG, 10 = 3.958" I -i 7" X 5" BKR ZXP PKR, 10 = 4.420" -i 5" X 4-1/2" XO, 10 = 3.990" I MILLOUT WINDOW 8554' - 8567' 1 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.958" I DATE 02/23/78 03/14190 02/22/03 03/18/03 06/16/03 09/14/03 REV BY COMMENTS ORIGINAL COM PLETION RWO DAC/KK RIG SIDETRACK (C-01A) JJ/KAK GLV ClO CMO/TLP KB ELEVATION & MAX ANGLE CMO/TLP PERF REF LOG ADDITION DATE REV BY COMMENTS 09/24/05 MORITLH PXN TIP SET (12/05/04) PRUDHOE BA Y UNIT WELL: C-01A PERMIT No: '2030100 API No: 50-029-20121-01 SEC 19, T11N, R14E, 1515.91' FNL & 881.67 FEL BP Exploration (Alaska) ~ TREE'= . WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = Proposed Completion 6"CW 13-518" IIIk:EVOY CONVENTIONAL ons ------ 63.8' 38' 5100' 91 @ 9751' 8911' 8800' SS C-01 19-518" CSG, 47#, L-80, ID = 3.681" H I 9-5/8" Foe I 113-3/8" eSG, 68#, NT-SO, 10 = 12.415" I I 9-5/S" FOC I 11S-5I8" eSG, 96.5#, K-55, 10= 17.655" I Minimum ID = 3.726" @ 8400' 4-1/2" HES XN NIPPLE I TOP OF 7" LNR H 7462' 9-5/8" CSG, 47#, N-80, 10 = 8.681" H 8016' PERFORA nON SUMMARY REF LOG: MJVD GR ON 02112/03 ANGLE AT TOP ÆRF: 89 @ 9380' Note: Refer to A'oduction DB for historical perf data SIZE SPF INTERVAL OpnlSqz [}I\TE 2-112' 4 9380 - 9969 C 02/20103 4-112" TBG, 12.6#, L-SO, .0152 bpf, 10 = 3.95S" I TOP OF CEMENT I 7" LNR, 29#, N-SO, .0371 bpf, 10 = 6.184" / 2007' --j 13-3IS" X 9-5/8" XO I 2213' --j 4-112" HES X NIP, 10 = 3.S13" I GAS LIFT MANDRELS lVD DEV TYÆ VLV LATCH PORT DATE 7" X 4-1 12' BKR S-3 PKR, ID = 3.875" 9-5/8" X 7" BOT HGR PKR Unique Machine Overshot Top of 4-112" Stub 4-112" HES X NIP, 10 = 3.813" 7" X 4-1/2" BKR S-3 PKR, 10 = 3.875" 4-1/2" HES X NIP, 10 = 3.813" I 4-1/2" HES XN NIP, 10 = 3.725" 8420' H 7" X 5" BKR ZXP PKR, 10 = 4.420" I -l 20' MARKER JT I I 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.95S" H 10069' [}I\ TE REV BY COMMENTS 09/24/05 MORlTLH PXN TIP SET (12105104) [}I\ TE 02/23/78 03/14190 02122/03 03118103 06116103 09/14103 REV BY COMMENTS ORIGINAL COM PLErION RWO I:»\C/KK RIG SIDETRACK (C-01A) JJIKAK GLV C/O CMOffLP KB ELEV A TlON & MAX ANGLE CMOffLP PERF REF LOG ADDITION PRUDHOE BAY UNIT WELL: C-01A ÆRMIT No: ~0301 ()() API No: 50-029-20121-01 SEe 19, T11 N, R14E, 1515.91' FNL & 881.67 FEL BP Exploration (Alaska) e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 February 25,2004 /3/2?Cìfj RE: MWD Formation Evaluation Logs: C-OIA, AK-MW-2277546 C-01A: Digital Log Images: 50-029-20121-01 .9D3··01 [) 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 2fDate#- S¡gneð:e \rílâiq¡7r 1~':Gii;: i' ).. À M~. ^-~ ç- DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Permit to Drill 2030100 Well Name/No. PRUDHOE BAY UNIT C-01A Operator BP EXPLORATION (ALASKA) INC ;5póJVL ì ~ FJ" ~ où 3 API No. 50-029-20121-01-00 MD 1 0059,~ lVD 9023./ Completion Date 2/22/2003/' Completion Status 1-01L .------- REQUIRED INFORMATION Mud Log No Samples No -.~. DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ASI, DEN, NEU Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name Log Log Run Scale Media No Interval Start Stop OH/ CH _/ ED 0 0; 641 LIS Verification 8527 -o~ ~D W; ~ x~- 8526 8527 8526 8526 8526 Directional Survey LIS Verification Directional Survey Directional Survey Directional Survey Well Cores/Samples Information: Name Interval Start Stop Received Sent Current Status 1-01L UIC N Directional surve~ (data taken from Logs Portion of Master Well Data Maint) Received Comments An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 2/4/2003. 1 0006 Open 4/29/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 2/4/2003. 10059 Open 4/17/2003 10006 Open 4/29/2003 1 0059 Open 4/17/2003 10059 Open 4/17/2003 MVVD 1 0059 Open 4/17/2003 MWD .:~ Sample Set Number Comments Permit to Drill 2030100 MD 10059 TVD 9023 ADDITIONAL INFORMATION Well Cored? Y ® Chips Received? cy / N Analysis Received? ~ - ----- Comments: <.~ Compliance Reviewed By: .~ DATA SUBMITTAL COMPLIANCE REPORT 3n /2005 Well Name/No. PRUDHOE BAY UNIT C-01A Operator BP EXPLORATION (ALASKA) INC Completion Date 2/22/2003 Completion Status 1-01L Current Status 1-01L Daily History Received? (bN <!9N Formation Tops ~~ Date: API No. 50-029-20121-01-00 UIC N -- I Áltt/L-~ C ~, q03-0-;Q " ) ) IJ&J<f1 WELL LOG TRANSMITTAL To: State of Alaska April 17,2003 Alaska Oil and Gas Conservation COllin. Attn.: Lisa Weepie 333 West 7th A venue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs C-OIA, AK-MW-2277546 1. LDWG formatted Disc with verification listing. API#: 50-029-20121-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Setvices BP Exploration (Alaska) Inc. Attn: Rob Kalish Petro-Technical Data Center LR2-1 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: s¡gn0m.¿JborJ RECEIVED APR 2 9 2003 Alaska Oil & Gas Cons. Commi!8i0n ,Anchorage Form 10-407 Rev. 07-01-80 RBPMS 8Fl c, Submit In Duplicate G f: No core samples were taken. Brief description of lithology, porosity, CORE DATA fractures, apparent dips and presence of oil, gas or water. Submit core chips. Flow Tubing Press. 28. Casing Pressure CALCULATED 24-HoUR RATE Oll-Bsl GAs-McF WATER-Bsl 1 GAS-OIL RATIO Oil GRAVITY-API (CORR) 27. Date First Production March 30, 2003 Date of Test Hours Tested PRODUCTION FOR TEST PERIOD PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing Oll-Bsl GAs-McF WATER-Bsl CHOKE SIZE /~lt~~ih:a:CH~ 11 Gø~ Gü;;s. ~1\' . ~~ 2-1/2" Gun Diameter, 4 sP~'~.:''''\r:.''.'!'''ß~r·'''''':''') þ.':'~;~, ;. ....~.. '¡"'Of.":~¡ Itrd"""" ~ \~ '. If"\',Io MD TVD 'k! '~~!':.~: " ~\ ~... !:~;' I,!,...,.,~ ~.~ ''Lil.t::rJ!''.~1I11 .~.',r 9380' - 9969' 9011' - 9021' APR o 'ì '"Jon t-.J! {_ ,\.} ~ 26. ACID, FRACTURE, DEPTH INTERVAL (MD) 2200' CEMENT SaUEEZE, ETC. AMOUNT & KIND OF MATERIAL USED Freeze Protect with 193 Bbls of Diesel TVD 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) SIZE 4-1/2", 12.6#, L-80 TUSING RECORD DEPTH SET (MD) 8412 PACKER SET (MD) 8355' 1" 4-1/2" 30" 18-5/8" 13-318" x 9-5/8" WT. PER FT. Stove 109.35# / 96.5# 47# / 68# 29# 12.6# GRADE Pipe K-55 N-80 N-80 L-80 25. CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 98' 36" Surface 25081 24" Surface 8015' 12-1/4" 7462' 85541 8-1/2" 8407' 10059' 6" CEMENTING RECORD ~97 sx Cement 6850 sx Permafrost II 1720 sx Class 'G', 2900 sx PF 500 sx Class 'G' 187 sx Class 'G' II -314" x 10-314" Added) 23. CASING SIZE AMOUNT PUllED 19, T11N, R14E, it (indicate KB, DF, etc.) 6. 1........ Œ = 63.841 ADL 028305 IvY 113. Date T.D. Reached 114. Date Comp., Susp., or Aband. I 2/19/2003 2/22/2003 17. Total Depth (MD+TVD) 118. Plug BackOepth (MD+TVD) 119. Directional Survey 10059 9023 FT 9975 9022 FT II Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, ABI, DEN, NEU Date Spudd"'..... 2/16/200~ 115. 20 if offshore N/A MSL Depth where SSSV set 1 21 (Nipple) 2213' MD 1 Thickness of Permafrost 1900' (Approx.) 16. No. of Completions One 196612, Anchorage, Location of well at surface 1516' SNL, 879' WEL, SEC. At top of productive interval. 1722' SNL, 603' WEL, SEC. At total depth 2510' SNL, 152' WEL, SEC. Elevation in 12. 5. Water depth, x = 665256, Y = 5958728 I "''''se Designation and Serial No. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 11 4. 19, T11N, R14E, UM 19, T11N, R14E, UM x = 664786, Y = 5959506 " 9. X = 664502, Y = 5959706 10. Well Number API Number 50- 029-20121-01 Unit or Lease Name Prudhoe Bay Unit C-01A 3. Address P.O. Box Alaska 99519-6612 o Abandoned'f\~~:psé'rvice \ l:~'~iJoJ ,\1:: .' JttÇ:;,. 2. Name of Operator BP Exploration (Alaska) Inc. Status of Well II Oil 0 Gas o Suspended ~;,;~.:.~'~~,i,~'~r\.~~~·~1 '~.~ltJ(::i-i.." i..~.. '.~.~".';'..'... t Yf~' ..Im" ':;i, ~ ,. ·.n '¡~~\J; f . ~. ':- ~ "~¡ ~;N .' ,', ì'Y \I!'~: '.1"':. -~..,' :. '.,11.:" ."....'I.'~.,""..... _' ft"~·~~""·:":'''1.'~~~ 8. 7. Permit Number 203-010 'J' Classification of Service Well STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) Form 10-407 Rev. 07-01-80 ITEM 28: If no cores taken, indicate 'none' ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. 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 21 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. Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 5: Indicate which elevation is used as reference (where not othelWise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM Classification of Service Wells: injection for in-situ combustion. Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, 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. INSTRUCTIONS Approval No. Permit hereby certify that the foregoing is true and correct to Signed TemeHubble ~A/IÌR Nl~ 203-01 0 C-01 A Well Number No. Title Prepared By Name/Number: Drilling Engineer Technical Assistant Date Terrie Hubble, 564-4628 Dave Wesley, 564-5773 O({ ·0 /- 03 .'" 32. the best of my knowledge 31 List of Attachments: Summary of Daily Drilling Reports, Surveys 21P 9135' 8981 APR 0 ':) t..' 21N 9125' 89781 riJ '\ ¡~ 21TS 9075' 8960' 22N 9060' 89531 GOC 9030' 8940' 22TS 8945' 8889' 23S8 8883 8842' ZONE 2 C I Base CLG 8782' 8756' ZONE 3/Top CLG 8707' 8688' 42P 8658' 8642' Zone 4A 8640' Measured Depth 86251 True Vertical Depth 29. Marker Name Geologic Markers ) Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 30. Formation Tests ) Legal Name: C-01 Common Name: C-01 Test Date 2/14/2003 Test Type FIT Test Depth (TMD) 8,555.0 (ft) BPEXPLORATION L.eak-OffTest·Summary Test Depth (TV D) 8,542.0 (ft) AMW 8.60 (ppg) Surface Pressure Leakoffpressure(i3HP) 490 (psi) 4,306 (psi) 9.70 (ppg) --.-' -~ Printed: 2/24/2003 10:30:32 AM 2/9/2003 05:30 04:00 23:30 2:00 - 12:30 22:00 - 23:00 23:00 - 23:30 07:00 07:30 08:30 09:30 10:30 00:00 - 00:30 00:30 - 01 :30 01 :30 - 04:30 04:30 - 07:00 00:00 04:15 12:30 - 13:00 13:00 - 14:30 14:30 - 16:00 16:00 - 18:00 18:00 - 18:30 18:30 - 22:00 08:30 05:30 00:00 07:30 08:30 09:30 10:30 12:00 04:15 04:00 3.00 PULL 0.25 4.00 PULL MOB MOB MOB MOB 0.50 0.50 1.00 1.00 1.00 1.50 0.50 1.00 3.00 2.50 0.50 PULL 1.00 0.50 0.50 1.50 1.50 2.00 0.50 3.50 .25 PULL WHSUR P WHSUR P WHSUR P WHSUR P WHSUR P BOPSURP BOPSUR P BOPSUR P WHSUR P P P P MOB P WHSUR P WHSUR P WHSUR P WHSUR P PULL P P DECOMP DECOMP DECOMP DECOMP DECOMP DEcOMP DECOMP DECOMP DECOMP PRE PRE PRE PRE DECOMP PRE DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Printed: 2/24/2003 Release rig for move at 23:00. from substructure. Pull sub structure away from C-32B. Lay rig mats and spread Herculite. MI/RU sub structure on C-01. Spot Pit Module and cuttings tank. Berm cellar and cuttings tank area. Connect service lines. Spot Mud engineers shack and Geologist shack. Move camp. Pre spud meeting with crew. ACCEPT RIG at 07:00 Install 2nd annulus valve. R/U DSM and pull BPV. Annulus and tubing on a vacuum. R/U to circulate out freeze protection fluid. Circulate out freeze protection fluid at 4 bpm and 430 psi. No losses encountered. Blow down lines. Verify well is dead. 0 psi on the tubing and 0 psi on the annulus. Install TWC and test from below to 500 psi. NID tree and adapter flange. Cameron die grind the nose off a broken Lock Down Screw. Nipple up BOPE. Make up test joint and install. Test BOPE, 250 psi low for 5 minutes, 3,500 psi high for 5 minutes, and all valves. Witness of test waived by Lou Grimaldi of AOGCC. RlU DSM. Pull TWC with lubricator. RlU and run in with landing joint. Back out all Lock Down Screws. Pull hanger free with 11 OK. Unable to pull from SBR. Maximum pull is 220K, ( Surface equipment weight + 4 1/2" tubing weight + 80% - 3 1/2" tubing yield rating.) Work pipe up to 220K pull, without success. Awaiting arrival of E-line for chern cut of 3 1/2" tubing above the TIW SBR. PJSM with Schlumberger and crew prior to E-line work, regarding rig up and chemical cutter handling. Set pipe in slips with 40K over string weight (140K P/U). RlU Sclumberger unit, sheaves, wireline. Prepare 2 3/8" chemical cutter with CCL. RIH with 2 3/8" chemical cutter and CCL. Log down to 7,470' 0:30:39 AM 2/8/2003 2/7/2003 23:00 08:00 00:00 11 :00 9:00 - 23:00 11 :00 08:00 00:00 19:00 .00 4.00 3.00 8.00 8.00 MOB MOB MOB MOB MOB PRE PRE PRE PRE PRE Move shop and pit Standby due to Phase III weather conditions and remaining C-01 site preparation. Rig on standby. Weather has improved, Phase I main roads, Phase II access roads and pads. HOT Oil commenced with C-01 well circulation and flowline flush at 02:00. Rig on standby. RID Little Red HOT Oil. Blow down flowline and prep for removal. Rig on standby. Remove Flowline and S-Riser Rig on standby. Snow removal and site prep for survey around well head. PJSM for rig move from C-32 to C-01 module away 2/6/2003 22:00 00:00 2.00 PRE Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Hours Task Code NPT Phase Start: Rig Release: Rig Number: 2/6/2003 2/22/2003 Spud Date: 12/3/1972 End: 2/22/2003 ) ') 2/10/2003 07:30 10:30 11 :00 11 :30 12:00 13:30 14:00 15:00 16:30 06:30 - 07:30 02:00 21 :45 - 23:30 23:30 - 00:00 00:00 - 01 :30 01 :30 - 02:00 05:00 10:30 11 :00 11 :30 12:00 13:30 14:00 15:00 16:30 17:00 06:30 05:00 3.00 FISH 0.50 FISH 0.50 FISH 0.50 FISH 1.50 FISH 0.50 FISH 1.00 FISH 1.50 FISH 0.50 FISH 1.75 FISH 0.50 FISH 1.50 FISH 0.50 FISH 3.00 FISH .00 FISH .50 FISH P P P P P P P P P P P P P P P P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Printed: 2/24/2003 PIU and Make up fishing BHA to 336' per Baker representative. Slip and cut drilling line. Service rig. Continue Slip and cut 101' drilling line. Service rig. Continue make up of BHA #1 from 336' to 416'. PIU remaining 4 3/4" collars and accelerator jar. PIU 4" HT-40 drill pipe, 1 X 1 from pipe shed. RIH from 416' to 4,618'. RIH with stands 4" HT-40 drill pipe from derrick. RIH from 4,618' to 7,328'. Break circulation at 3 bpm and 150 psi. Up weight 150K, Down weight 150K Engage fish at 7,398', pull 75K over, attempt to free K-Anchor with rotation. After 6 rotations, fell off. Engage fish again. Jar up with 1 OOK over. Jar several times, pull free. POOH from 7,391' to 416'. POOH with BHA #1 from 416'. LID fish. Recovered 7.42' of 3 1/2", 9.2#, L-80 tubing. Clear floor. PIU and MIU BHA #2 to 416'. RIH with 4" drill pipe from 416' to 2,282'. Adjust rig brake. RIH with drill pipe from 2,282' to 7,398'. Establish up weight 150K, down weight 150K. Circulate at 3 bpm and 140 psi. Engage fish at 7,398'. 1030:39 AM 20:30 21:00 21:30 21:00 21:30 21 :45 0.50 BOPSURP 0.50 FISH P 0.25 FISH P DECOMP DECOMP DECOMP 18:30 19:00 15:00 11 09:00 - 09:30 09:30 - 10:00 10:00 - 11 :00 09:00 4:00 00 08:30 19:00 20:30 5:00 4:00 8:30 0.50 PULL P 1.50 BOPSUR P 3.50 PULL 3.00 PULL 0.50 PULL 0.50 PULL 1.00 PULL PULL 0.50 00 PULL P P P P P P P DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP and up, two passes to confirm collars and jewelry. Chemical cut the 31/2" tubing at 7,380' (WLM), in the middle of the first full joint of 3 1/2' tubing above the seal assembly. Rig back Schlumberger. Pull tubing hanger to the floor with 95K up weight. No overpull. RID Schlumberger E-line equipment. LID the landing joint and tubing hanger. RIU 4 1/2" tubing equipment and Camco control line spooling unit. POH and LID 4 1/2", 12.6#, L-80 BTC tubing from 7380 to 5239', spooling dual encapsulated control lines. Recovered: 53 joints 41/2",12.6#, L-80 tubing 26 control line clamps and pins; 4 SS bands 1 SSSV RID Camco spooling unit. Clear rig floor. RIU 3 1/2" tubing equipment. POH and LID 31/2",9.2#, L-80, BTC tubing from 5239'. Recovered: 162 joints 31/2",9.2#, L-80 tubing 5GLM 14.65' of cut off joint. Very clean cut. RID 3 1/2" tubing equipment. RIU and test BOPE lower rams to 250 psi low for 5 minutes and 3,500 psi high for 5 minutes. Pull test joint and plug. RID. Install wear bushing. PIU and load floor with Baker fishing tools. PJSM with crew regarding make up of fishing BHA. 2/9/2003 05:30 08:30 3.00 PULL P DECOMP Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name NABORS 2ES From-To Hours Task Code.NPT Phase Start: Rig Release: Rig Number: 2/6/2003 2/22/2003 Spud Date: 12/3/1972 End: 2/22/2003 ) QperationsSummary ..·Repol"t BPEXPLORATION ) Printed: 2/24/2003 0:30:39 AM 20:00 21:30 50 FISH P DECaMP P/U and M/U fishing BHA #5 to 416'. cia elevators. 15:30 - 18:00 18:00 - 18:30 18:30 - 20:00 2.50 FISH 0.50 FISH 1.50 FISH P P P DECaMP DECaMP DECaMP 14:30 09:00 10:30 12:30 15:30 10:30 12:30 14:30 .00 FISH 1.50 FISH 2.00 FISH 2.00 FISH P P P P DECaMP DECaMP DECaMP DECaMP M/U fishing BHA #4 to 416'. RIH with 4" HT-40 drill pipe from 416' to 7,411' Establish P/U Weight of 151 K, SIO weight 151 K. Break circulation at 3 bpm and 120 psi. Engage fish at 7,411' Jar with 100K over string weight. Gradually gained 1 foot of upward movement, then no further movement. Jarred down three times, fish came free. Circulate bottoms up at 7,411' at 6 bpm and 500 psi. Inspect derrick. Slug pipe and blow down top drive. POOH with drill pipe from 7,411' to 416'. Stand back BHA from 416' to 31'. UD fish. Recovered 4.86' of 31/2",9.2#, L-80 1/2" pup joint, and SBR (16.84') Also recovered slick stick and K Anchor with fish 24.39'. Clear ig floor. the SBR. Overall tubing stump, 3 08:30 - 09:00 2.00 FISH 1.50 FISH 0.50 FISH P P P DECaMP Continue POOH with drill pipe from 5,180' to 436'. DECaMP POOH with BHA #3 from 436' to 67'. UD OS wash pipe assembly. DECaMP Clear rig floor. 05:00 - 07:00 07:00 - 08:30 03:30 04:30 02:00 04:30 05:00 03:30 1.00 FISH 0.50 FISH 50 FISH P P P DECaMP DECaMP DECaMP Break circulation at 7,348' at 5.5 bpm and 490 psi. P/U Weight 150K, SIO weight 150K, Rot Weight 155K SIO 7 feet to 7,411' with 40 rpm, 240 gpm, 450 psi, torque 2500 - 2700. Continue to SIO to 7,516' with 40 rpm, 250 gpm, 380 psi, torque 1700 - 1800. Continue to SIO to 7,424', drill pipe measurement, until bottom out at top of packer with 40 rpm, 250 gpm, 410 psi, torque 1700. Work wash pipe up and down stump and circulate 45 bbl sweep. Sweep of 85 vis, 30 YP circ. surface to surface at 580 gpm, 2, 000 psi, and 50 rpm. Nothing returned with sweep. Blow down top drive. POH with drill pipe from 7,424' to 5,180' Service top drive. 2/11/2003 01:00 21 :00 22:30 23:00 00:00 02:00 22:30 23:00 00:00 01:00 .00 FISH 1.50 FISH 0.50 FISH 1.00 FISH 1.00 FISH P P P P P DECaMP DECaMP DECaMP DECaMP DECaMP 17:00 19:30 20:00 19:30 20:00 21:00 2.50 FISH 0.50 FISH 1.00 FISH P P P DECaMP DECaMP DECaMP P/U to 50K over (200K) and SIO, P/U to 75K over and SIO twice, P/U to 85K over and SIO twice, P/U to 90K over and came free. POOH from 7398' to 416'. cia elevators. Stand back BHA #2 from 416' to 31'. UD fish. Recovered 6.35' of 3 1/2", 9.2#, L-80 tubing. Clear floor. PJSM regarding BHA P/U . P/U and M/U BHA #3 to 67'. RIH with BHA #3 from 67' to 436'. cia elevators. RIH with drill pipe from 436' to 3797'. RIH with drill pipe from 3,797' to 7,348'. Establish P/U weight 150K, SIO weight 150K , Rot weight 150K. of ig 2/10/2003 6:30 7:00 0.50 FISH P DECaMP Date Legal Wel Common Wel Event Name: Contractor Name: Rig Name: From -- To Hours C-01 C-01 REENTER+COMPLETE NABORS ALASKA DRILLING NABORS 2ES Task Gode NPT Phase Start: Rig Release: Rig Number: Descri ptionof 2/6/2003 2/22/2003 Operations Spud Date: 12/3/1972 End: 2/22/2003 Name: Name: ) Operations Summary Report BPEX.PLORATION ) Body test the BOPE, tubing spool flange to 250 psi low for minutes and to 3,500 psi high for 5 minutes. POH with the HES 9 5/8" storm packer. UD HES 9 5/8" RTTS I Storm packer. RIH with drill pipe from 2,572' to 7,495'. Establish P/U weight 150K, and down weight 150K. Break circulation at 53 spm and 110 psi. Circulate and S/O to TOF at 7,515'. Engage fish, pump pressure increased to 160 psi. Swallow 3' fish, P/U. Up weight 162K, PUH 10' take weight of 20 - 25K. Printed: 2/24/2003 0:30:39 AM 2/13/2003 02:30 23:30 00:00 00:30 03:00 00:00 00:30 02:30 0.50 FISH 0.50 FISH 0.50 FISH 2.00 FISH P P P P DECOMP DECOMP DECOMP DECOMP S/O again and 23:00 23:30 0.50 FISH P DECOMP 5 21:30 06:00 07:00 07:30 08:00 09:30 4:30 11:00 13:30 23:00 21:30 07:00 07:30 08:00 09:30 11 :00 3:30 14:30 .50 FISH 7.00 FISH 2.50 FISH 1.00 FISH 1.00 FISH 0.50 FISH 0.50 FISH 1.50 FISH 1.50 FISH P P P P P P P P P DECOMP N/U BOPE. DECOMP DECOMP DECOMP DEcOMP DECOMP DECOMP DECOMP DECOMP Clear rig floor. P/U and prepare OverShot assembly. M/U fishing BHA #6 to 394'. C/O handling equipment. RIH from 394' to 2,572'. PJSM with HES regarding M/U and installation of storm packer M/U 9 5/8" storm packer and RIH. Set at 38',10' below ground level. Test to 500 psi. Good test. Blow down lines. N/D BOPE. Bleed gas from 9 5/8" X 13 3/8" annulus, and from 13 3/8" X 20" annulus. N/D tubing spool. Encountered trouble with pack-off alien head bolts. Three were damaged and required being ground flush with 9 5/8" slips. Install new 9 5/8" pack-off. Install new tubing spool. Install Wear Bushing. Test to 3,000 psi. Good test. P/U to 240K, hold -1 minute, then S/O P/U to 250K and hold -1 minute. P/U to 275K and hold -1 minute. S/O to 150K and wait several minutes. P/U to 280K and S/O to 150K 3 times. S/O and set jars, P/U to 260K and allow jars to packer came free, weight fell off to 160K. Circulate bottoms up at 120 spm, 540 gpm, 1675 psi. No gas detected at surface. Up weight 151 K, down weight 151 K. Monitor well. Blow down top drive. P/U 151 K with some intermittent drag 170K, from 7,428' to 5,550'. POOH with drill pipe from 7,428' to 416'. Change out handling equipment. Stand back 4 3/4" collars and UD BHA from 416' to 31'. R/U 3 1/2" tubing handling equipment. UD fish. Recovered TIW HBBP-R packer and 73.93' of 31/2" tubing 2/12/2003 05:00 04:00 01:00 00:00 06:00 05:00 04:00 01:00 .00 FISH .00 FISH 3.00 FISH .00 FISH P P P P DECOMP DECOMP DECOMP DECOMP fire. Third to jar, 23:30 00:00 0.50 FISH P DECOMP RIH to top of fish at 7,428' weight 151 K Circulate at 3 bpm and 200 psi. Engage fish. P/U to 190K to allow to 150K, twice. jar to bleed off. 2/11/2003 21:30 23:30 2.00 FISH P DECOMP Establish P/U weight 151 K, S/O Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES From-To Hours Task Code NPT Phase Start: Rig Release: Rig Number: Descri ptionof 2/6/2003 2/22/2003 Operations Spud Date: 12/3/1972 End: 2/22/2003 ) OperatIons Summ.ary Report BPEXPLORAIION ) 03:45 - 05:00 05:00 - 05:30 03:30 03:45 1.25 0.50 0.25 DHEQP P DHEQP P DHEQP P DECOMP DECOMP DECOMP 2/14/2003 01:30 03:15 00:00 01:00 22:00 20:30 13:00 11 :00 12:00 09:30 17:30 19:30 6:30 14:00 03:15 03:30 01:00 01:30 00:00 22:00 - 19:30 20:30 7:30 6:30 4:00 12:00 13:00 11 :00 1.75 DHEQP N 0.25 DHEQP N 1.00 EVAL N 0.50 DHEQP N 2.00 EVAL 2.00 EVAL P 1.00 DHEQP N 2.50 EVAL EVAL DHEQP P EVAL P P .00 .00 .00 .00 EVAL 50 FISH 50 EV AL P P P N N DFAL DFAL DFAL DFAL DFAL DFAL DFAL DECOMP DECOMP DECOMP DECOMP DEcOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP DECOMP Break out and LID O/S fishing assembly. Clear floor of Baker tools. LID 19.6' cut joint of 3 1/2" tubing, 37 full joints of 3 1/2", 9.2#, L-80 tubing, and 13' cut joint of 3 1/2" tubing. The last 83' of tubing had cement on the outside. PJSM with Schlumberger. R/U SWS. RIH with Schlumberger GR/cCLlJB wI 6.059" gauge ring to 2,200'. GR "floating" in Flo-Pro mud system. POH from 2,200', for additional weight. RIH with Schlumberger GR/cCLlJB wI 6.059" gauge ring to 8,675'. POOH. RID Junk Basket and Gauge Ring. R/U HES 7", 29#, EZSV bridge plug. SWS RIH with HES EZSV to 8,653' Correlate to GR I CCL. Log into position, at 8,555'. Position EZSV 3' above casing collar, attempt to fire and set. No indication of firing or tension release. Attempt twice more. Slack off tool weight to attempt to determine whether or not EZSV set. Negative. Log back into position and make another attempt to fire. Negative. POOH. POOH to surface with E-line. PJSM with crew and SWS regarding pulling and handling live firing head. Break out SWS equipment. Trouble shoot. Determine EFI (Firing initiator) faulty. Replace EFI and firing head component. Threads damaged on firing head housing. Necessary to replace. Wait for arrival from Deadhorse. Driver caught behind rig move. Wait for replacement firing head housing. M/U new component, prepare SWS tool, test fire. O.K. M/U HES 7" EZSV bridge plug. SWS RIH with E-line GR I CCL and HES 7" EZSV to 8,620' Log up to correlate with GR I CCL. RIH to 8,620', confirm correlation. Position GR I CCL at 8,526', HES bridge plug at 8,555'. Fire setting tool. Good surface indication of detonation. Line tension decrease. Wait 5 minutes. Log up hole and observe three collars. Run back to depth and tag bridge plug, confirm at 8,555'. SWS POOH from 8,555' to surface. RID Schlumberger. Clear rig floor. Printed: 2/24/2003 0:30:39 AM 08:00 07:30 04:00 04:30 07:00 09:30 08:00 04:30 07:00 07:30 .50 FISH 0.50 FISH 2.50 FISH 0.50 FISH 0.50 FISH P P P P P DECOMP DECOMP DECOMP DECOMP DECOMP Pump dry job. POOH with drill pipe from 7,515' C/O handling equipment. POOH tubing. R/U 3 1/2" tubing equipment. to 394'. from 394' to fish, 3 1/2" DECOMP Displace well to 8.6 ppg Flo-Pro mud system at 230 spm, 560 gpm, 1,400 psi. No problems. 03:15 04:00 0.75 FISH P 2/13/2003 02:30 - 03:00 03:00 - 03:15 0.50 FISH 0.25 FISH P P DECOMP P/U weight 162K, PUH 25'. Circulate at 55 spm and 150 psi. DECOMP PJSM with crew and truck drivers regarding well displacement. Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES From-To Hours Task Code>·NPT Phase Start: Rig Release: Rig Number: 2/6/2003 2/22/2003 Descri ptionof Spud Date: End: Operations 2/3/1972 2/22/2003 ) OperationsSu mmarv/Report BPi EXPLO RAI I ON ) 5:00 5:30 10:30 11 :30 12:00 5:30 6:00 1:30 2:00 5:00 0.50 BOPSURP 0.50 DRILL P 1.00 BOPSURP 0.50 BOPSU~ P 3.00 BOPSURP PROD1 PROD1 PROD1 PROD1 PROD1 2/15/2003 00:00 00:30 01:30 03:00 05:30 06:30 07:30 23:30 - 00:30 01:30 03:00 05:30 06:30 07:30 10:30 00:00 0.50 STWHIP P 1.00 STWHIP P 1.50 STWHIP P 2.50 STWHIP P 1.00 STWHIP P 1.00 BOPSUR P 3.00 BOPSUR N 0.50 STWHIP P RREP WEXIT WEXIT WEXIT WEXIT WEXIT PROD1 PROD1 WEXIT YP maintained at 44 - 46. Funnel vis at 75 - 90. Rotate and work pipe through window. Circulate at 272 GPM and 1,220 psi. CBU, pump 'Super Sweep' , 25 bbls at 1/2 ppb. NOTE: Recovered 105 Ibs. metal shavings Continue to circulate. Pull up to 8,550'. Perform FIT to 9.7 ppg EMW, 490 psi. Monitor for 10 minutes, loss of 60 psi. Circulate. Mix dry job. Pump dry job. POOH with drill pipe from 8,550' to 8,294'. Slip and cut drill line. Service top drive. POOH with drill pipe from 8,294' to 835'. UD BHA #7. Mill is full gauge. Clear rig floor. SCR down time. C/O power limit controller and relay tJ shut down. Flush BOPE with 'Johnny Wacker', function rams. Pull wear ring, install test plug, R/U test joint. R/U equipment and test BOPE, and all related valves, to 250 psi low and 3,500 psi high. Witness of test waived by John Crisp of the AOGCC. Pull test plug, install wear ring. Prepare BHA Printed: 2/24/2003 0:30:39 AM 22:30 23:30 .00 STWHIP P WEXIT 8,571' - 8,579' - 20 - 25K WOM, 2 260 GPM at 1,150 psi. OK Torque, 100 RPM, 8,567' - 8,571' - 8 - 17K WOM, 4 - 6K Torque, 60 260 GPM at 1,100 psi. 00 RPM, 6:00 15:00 15:30 07:00 08:00 08:30 09:00 09:30 10:30 11 :30 2:00 22:30 - 08:00 - 08:30 - 09:00 - 09:30 - 10:30 - 11 :30 - 12:00 5:30 6:00 5:00 6.50 STWHIP P 3.00 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 0.50 STWHIP P 1.00 STWHIP P 1.00 STWHIP P 0.50 STWHIP P WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT M/U 7" whip stock assembly to Upload MWD tools. M/U BHA #7 from 108' to 146'. Shallow test MWD at 146' at 250 gpm and 680 psi. M/U BHA #7 from 146' to 853'. Change out elevators. RIH with drill pipe from 853' to 3,186'. Fill pipe. Function test MWD at 3,186' at 250 gpm and 770 psi. Blow down surface equipment. RIH with drill pipe from 3,186' to 8,511'. Stop and fill pipe at 5,988'. Fill pipe at 8,511 '. Install blower hose. Break circulation at 6 bpm and 1070 psi. P/U weight 165K, S/O weight 165K. Orient Whip Stock 73 deg. RHS. Slack off and tag EZSV bridge plug at 8,573' . Set trip anchor with 15K down weight, shear bolt with 35K down weight. TOW at 8,554 and BOW at 8,567'. Mill window in 7", 29#, L-80 casing as follows: 8,554' - 8,567' - 3 - 5K WOM, 4 - 6K Torque, 90 250 GPM at 1,120 psi. Pump 'Super Sweep', 20 bbls at 1/4 ppb, at 8,561 00 RPM 08' 06:30 07:00 0.50 STWHIP P WEXIT R/U and pressure test 9 5/8" for 30 minutes. P/U whip stock assembly and prepare. 2/14/2003 05:30 06:30 .00 EVAL P DECOMP X 7" casing and liner to 3,500 psi Date Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: From- To Hours C-01 C-01 REENTER+COMPLETE NABORS ALASKA DRILLING NABORS 2ES Task Code< .. NPT Phase Start: 2/6/2003 Rig Release: 2/22/2003 Rig Number: Descri ptionof Spud Date: 12/3/1972 End: 2/22/2003 Operations ) Operations Summary. Report BF> EXPLORATION ) Printed: 2/24/2003 10:30:39 AM Slide from 8,852' to 8,916' at TF 80, WOB 20K, Flow gpm, 1780 psi, average ROP 28 fph Pump a 20 bbl pill (10 ppb) of beads to facilitate sliding Slide from 8,797' to 8,846' at TF 80, WOB 20K, gpm, 1780 psi, average ROP 28 fph Oriented drilling to initiate more RH turn, from azimuth of 138 deg. to 165 deg. Rotate from 8,846' to 8,852' at RPM 30, WOB rate 260 gpm, 1810 psi, average ROP 35 fph rate 250 2 5K, Flow Directional drill from 8,797' to 9,070' 8.2 hrs, ADT = 8.7 hrs P/U Wt 175K, S/O Wt 165K, Rot Wt - 6K, Torque off btm = 3 - 4K Flow rate 250 170K Torque on btm = 5 2:00 00:00 2.00 DRILL P PROD1 ART = 0.5 hrs, Slide from 8,740' to 8,792' at TF 25, WOB 20K, gpm, 1780 psi, average ROP 30 fph Continuing to build inclination. Rotate from 8,792' to 8,797' at RPM 30, WOB rate 260 gpm, 1810 psi, average ROP 35 fph AST= 2 15K, Flow Slide from 8,730' to 8,735' at TF 25, WOB 20K, gpm, 1780 psi, average ROP 30 fph Oriented drilling to build inclination. Rotate from 8,735' to 8,740' at RPM 30, WOB rate 260 gpm, 1780 psi, average ROP 30 fph Flow rate 250 2 15K, Flow Flow rate 250 Rotate from 8,690' to 8,730' at RPM 30, WOB 12 rate 260 gpm, 1780 psi, average ROP 30 fph PJSM regarding P/U drilling BHA. M/U 6" drilling BHA to 105' Up load MWD and load RAS. Continue M/U BHA from 105' to 2,066'. Surface test MWD at 232' at 6 bpm and 970 psi. RIH with 4" drill pipe from 2,066' to 8,457'. Fill pipe at 3,370' and 6,640'. MAD pass from 8,457' to 8,511' at 1 OO'/hr with realtime MWD. Circulate at 6 bpm and 1,560 psi. Orient at 60 - 80 deg. RHS and S/O through window to TO. Flow at 102 spm, 250 gpm, 1620 psi. 4 - 6K WOB. Slide from 8,579' to 8,670' at TF 60 - 80, WOB 10 - 15K, Flow rate 250 gpm, 1640 psi. Sliding at -30 fph. Tended to hang some as Motor and MWD collars pass through window. Maintaining 100 - 150 psi differential. Rotate from 8,670' to 8,690' at RPM 30, WOB 12 - 15K, Flow rate 260 gpm, 1780 psi, average ROP 30 fph. Torque on bottom 3 - 5K. Directional drill from 8,690' to 8,798' 5.5 hrs, ADT = 7.7 hrs P/U Wt 170K, S/O Wt 160K, Rot - 6K, Torque off btm = 3 - 4K 5K, Flow 2/16/2003 06:00 05:00 01:00 00:00 23:00 18:00 20:00 2:00 06:00 05:00 01:00 00:00 23:00 20:00 6.00 .00 4.00 2.00 .00 00 3.00 DRILL DRILL DRILL DRILL DRILL DRILL DRILL P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Wt 65K Torque on btm = 2 ART = 2.2 hrs, AST= 2/15/2003 6:00 - 18:00 2.00 DRILL P PROD1 Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES From·~.To Hours Task Code NPT Phase Start: Rig Release: Rig Number: Descri ption.of 2/6/2003 2/22/2003 Operations Spud Date: 12/3/1972 End: 2/22/2003 ) Operations>SummaryiReport BPEXPL..ORATION ) 2:00 9:30 7.50 DRILL P PROD1 Printed: 2/24/2003 Slide from 9,382' to 9,445' at TF -90 gpm, 1800 psi, average Rap 35 fph. P/U wt = 175K, SIO wt = 160K, ROT Wt. = 170K Torque on btm = 4,000 - 5,000 Torque off btm = 3,000- 5,000 ART = 3.7 hrs AST = 4.9 hrs ADT = 8.6 hours. Rotate from 9,445' to 9,650' at RPM 45, WOB 30K, Flow 260 gpm, 1800 psi, average Rap 45 fph. 0:30:39 AM rate WOB 30K, Flow rate 260 Continue LH turn. Rotate from 9,350' to 9,382' at RPM 45, WOB 30K, Flow rate 260 gpm, 1800 psi, average Rap 45 fph Slide gpm, Slide gpm, from 9,256' to 9,286' at TF -50 1800 psi, average Rap 40 fph. from 9,286' to 9,350' at TF -90 1800 psi, average Rap 35 fph. WOB 25K, Flow rate 260 WOB 30K, Flow rate 260 Orient to generate LH Rotate from 9,220' to 9,256' at RPM 30, WOB 20K, Flow 260 gpm, 1780 psi, average Rap 43 fph turn while landing in target polygon. Slide gpm from 9,164' to 9,220' at TF -40, WOB 25K, Flow 1760 psi, average Rap 40 fph. rate rate 260 Rotate from 9,128' to 9,164' at RPM 30, WOB 25K, Flow rate 260 gpm, 1780 psi, average Rap 41 fph Slide gpm from 9,105' to 9,128' at TF -20, WOB 20K, Flow 1760 psi, average Rap 34 fph. rate 260 Slide from 9,100' to 9,105' at TF -20, WOB 20K, Flow gpm, 1700 psi, average Rap 30 fph rate 255 Rotate from 9,080' to 9,100' at RPM 30, WOB 25K, Flow 260 gpm, 1810 psi, average Rap 60 fph Slide from 9,070" to 9,080" at TF 0, WOB 20K, Flow rate 255 gpm, 1700 psi, average Rap 30 fph rate Directional drill from 9,070' to 9,270'. P/U Wt 175K, SIO Wt 165K, Rot Wt - 6K, Torque off btm = 3 - 4K 2/17/2003 00:00 2:00 2.00 DRILL P PROD1 170K Torque on btm = 5 Positive response with increase in oriented drilling Rap. Continuing RH turn. Slide from 8,916' to 9,058' at TF 20, WOB 20K, Flow rate 255 gpm, 1720 psi, average Rap 40 fph Orient to continue build, direction lined up. Rotate from 9,058' to 9,070' at RPM 30, WOB 25K, Flow rate 260 gpm, 1810 psi, average Rap 35 fph 2/16/2003 12:00 00:00 12.00 DRILL P PROD1 Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES From-To Hours Task Code NPT Phase Start: 2/6/2003 Rig Release: 2/22/2003 Rig Number: Description of Operations Spud Date: 12/3/1972 End: 2/22/2003 ) Operations Summary Report BP EXPLORATION ) 11 :00 - 12:30 12:30 - 15:00 15:00 - 15:30 15:30 - 16:00 16:00 - 18:30 18:30 - 19:30 19:30 - 21 :30 10:00 08:30 09:00 09:30 07:30 06:30 - 07:30 09:00 09:30 10:00 08:30 11 :00 1.50 DRILL 2.50 DRILL 0.50 DRILL 0.50 DRILL 2.50 DRILL 1.00 CASE 2.00 CASE 0.50 0.50 0.50 .00 .00 DRILL .00 DRILL DRILL DRILL DRILL DRILL P P P P P P P P P P P P P PROD1 PROD1 PROD1 PROD1 PROD1 COMP COMP PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 Printed: 2/24/2003 Drill 6" hole 9,751 to TO @ 10,059 ft. Pump rate 265 GPM, 1690 psi off btm, 1970 psi on btm. 60 RPM's. TO 4k off btm, 7k on btm. P/U Wt 175k, S/O Wt 155k, Rot Wt 165k. ART= 5.5 hrs, AST= 0.25 hrs, ADT= 5.75 hrs. Avg ROP rotate 54 ft / hr Slide 11 ft @ 180 TF, Avg ROP slide 44 ft / hr Circ sweep around @ 252 GPM, 1750 psi. Rotate & reciprocate pipe. 60 RPM's TO 4k. P/U Wt 175k, S/O Wt 155k, Rot Wt 165k. No significant increase in cuttings. POH from 10,059 ft to 8,511 ft. Hole in good shape. Flow checks showing well static. Service Top Drive, inspect service loop. O-K. RIH to btm @ 10,059 ft. No fill. Hole in good shape. Spot 50 bbl 'liner running' pill @ 252 GPM, 1770 psi. Rotate & reciprocate pipe. 60 RPM's TO 4k. P/U Wt 175k, S/O Wt 155k, Rot Wt 165k. POH from 10,059 ft to 8,511 ft. Hole in good shape. Flow checks showing well static. Open circ sub, CBU @ 462 GPM 1380 psi. Pump dry job. POH to 2,066 ft. LD 3 1/2" HWDP & jars. Con't POH to BHA @ 202 ft. Pull 'Nukes', Download MWD, Flush MWD / MM. LD BHA. Clear floor. RU for running 4 1/2" liner. PU & RIH w/4 1/2" solid liner as follows: 10:30:39 AM 2/19/2003 00:00 21 :30 - 22:30 22:30 - 00:00 06:30 6.50 DRILL .50 .00 .50 DRILL DRILL DRILL P N N P RREP RREP PROD1 PROD1 PROD1 PROD1 2/18/2003 20:00 23:00 00:00 22:00 - 23:00 22:00 9:30 21:30 00:00 20:00 1.00 20.00 .00 2.50 DRILL DRILL DRILL DRILL N N N N RREP PROD1 RREP PROD1 RREP RREP PROD PROD1 P/U wt = 175K, S/O wt = 160K, ROT Wt. = 170K Torque on btm = 5,000 - 6,000 Torque off btm = 4,000 ART = 3.9 hrs AST = 1.0 hrs ADT = 4.9 hours. Top drive service loop failure. Electrical fire in service loop. (See remarks). LID single joint. Manually break top drive from drill string. POOH with drill pipe from 9,701' to 8,479', inside 7" window. Trip to 'shoe' was slick. Up weight at 175 - 180K. One area with 190K at 9,440' to 9,420'. Prepare for rig repairs. RD service loop on TO. Replace with new assy. Install & wire into TO. MU clamps and function test Top Drive. O-K. CBU @ 1550 psi, 252 GPM. P/U Wt 170k, S/O Wt 160k, Rot Wt 165k. 22 RPM's, TO 2k. Orient string @ 70 degrees RIH w/ 6" bit to btm @ 9,701 ft. No fill. Hole in good shape. Drill 6" hole 9,701 to 9,751 ft. Pump rate 265 GPM, 1650 psi off btm, 1850 psi on btm. 45 RPM's. TO 4k off btm, 6k on btm. P/U Wt 175k, S/O Wt 160k, Rot Wt 170k. ART= 1 hr, ADT= 1 hrs. Avg ROP rotate 50 ft / hr Rotate from 9,675' to 9,701' at RPM 45, WOB 30K, Flow rate 260 gpm, 1800 psi, average ROP 45 fph Slide gpm, from 9,650' to 9,675' at TF -30, WOB 30K, Flow rate 260 1800 psi, average ROP 42 fph. 2/17/2003 2:00 9:30 7.50 DRILL P PROD1 Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES From- To Hours Task Code NPT Phase Start: Rig Release: Rig Number: 2/6/2003 2/22/2003 Description of Spud Date: 12/3/1972 End: 2/22/2003 Operations ') Op.erations Summary Report BPEXPLORATION ) i. 21 :30 - 22:30 .00 CASE P 22:30 - 00:00 1.50 CASE P 2/20/2003 00:00 - 02:30 2.50 CASE P 02:30 - 03:00 0.50 CASE P 03:00 - 03:30 0.50 CASE P 03:30 - 05:00 1.50 CASE P 05:00 - 06:00 1.00 CEMT P 06:00 - 07:00 1.00 CEMT P 07:00 - 08:30 1.50 CEMT P 08:30 - 09:00 0.50 CEMT P 09:00 - 10:00 1.00 CASE P 10:00 - 13:00 3.00 CASE P 13:00 -14:00 1.00 PERF P 14:00 - 15:00 1.00 PERF P 15:00 - 16:00 1.00 PERF P 16:00 - 17:00 1.00 PERF P 17:00 - 17:30 0.50 PERF P 17:30 - 20:30 3.00 PERF P 20:30 - 21 :30 1.00 PERF P 21 :30 - 22:30 1.00 PERF P 22:30 - 23:00 0.50 PERF P COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Printed: 2/24/2003 FS, 1 jt 4 1/2" 12.6#, L 80 IBT csg, FC, 1 jt 41/2" 12.6#, L 80 IBT csg, LC, 21 jts 41/2" 12.6#, L 80 IBT csg, 1 marker jt 4 1/2" 12.6#, L 80 IBT csg, 16 jts 4 1/2" 12.6#, L 80 IBT csg, pup jt, XO, 5" x 7" HMC liner hng, 5" x 7" 'ZXP' liner top pkr, 5" x 7" liner TB sleeve, 3 1/2" IF lift sub. Avg MU TO 4200 ft I Ibs RD csg handling equip. RU DP handling equip. RIH wI 1 std 4" HT 40 DP. Circ one liner volume. @ 147 GPM 100 psi. P/U Wt 45k, S/O Wt 45k Con't RIH w/4 1/2" solid liner on 4" DP from derrick to 4,450 ft. Con't RIH w/4 1/2" solid liner on 4" DP from derrick to TOW @ 8,554 ft. Circ & cond mud 220 GPM, 615 psi. P/U Wt 150k, S/O Wt 145k Con't RIH w/4 1/2" solid liner on 4" DP from derrick to 10,039 ft. Hole in good shape. MU cmt head tag btm @ 10,059 ft. Circ & condition mud 257 GPM, 1090 psi. P/U Wt 170k, S/O Wt 155k. RU Dowell cementers. PJSM wI all personnel. Batch mix cement. Pump 5 bbls H20, test lines 4,500 psi O-K. Pump 15 bbls 8.3 ppg CW 100 @ 4.7 BPM 1040 psi, 25 bbls 9.7 ppg MudPush XL @ 4.6 BPM 1000 psi, 40 bbls 15.8 ppg slurry @ max 4.9 BPM 1470 psi. Wash lines thru tee on floor. Drop plug. Displace wI 45 bbls 8.6 ppg 'Perf Pill' @ max 5 BPM 260 psi, 63 bbls 8.6 ppg mud @ max 4.9 BPM 1150 psi. Park pipe after 75 bbl away in displacement. Latch plug @ 83.6 bbl away Bump plug @ 107.6 bbl wI 3800 psi. Set hanger. Bleed off 0.8 bbls & check floats O-K. CIP @ 0545 Release from hgr wI 40k S/O Wt. Rotate 15 turns wI TO 3k. PU 6 ft wI 1000 psi pump pressure. Pressure decrease as liner running tool cleared HMC hgr. Increase pump rate to 462 GPM 2060 psi. CBU. Set 'ZXP' pkr wI 50k S/O Wt, 10 RPM TO 2k, 120 GPM, 400 psi. Repeat pkr setting sequence. Good surface indication of pkr setting. Displace well wI 50 bbl hi vis spacer and 8.4 ppg seawater. 505 GPM 2535 psi. Reciprocate pipe. P/U Wt 155k, S/O Wt 150k LD cement head & lines. POH wI liner running tool. LD excess 4" DP to 7,099 ft. (42 jts) Con't POH wI liner running tool racking 4" DP in derrick. LD liner running tool. Inspect same O-K. RU floor for PU perf guns & 2 7/8" DP handling equip. Test csg I liner top to 3500 psi I 30 mins. Cement @ 1600 psi compressive strength. PU / MU 589 ft of 2 1/2" 'Millennium' perf guns. RIH w/ perf guns on 2 7/8" 'PAC' DP to 1,622 ft from pipe shed. RD 2 7/8" DP handling equip. RU 4" DP handling equip. Con't RIH wI perf guns on 4" DP from derrick to 41/2" TOL @ 8,406 ft. Slip & cut drlg line. Service TD. Con't RIH wI perf guns on 4" DP. Tag LC @ 9,975 ft. Space out & put guns on depth. Top shot 9,380 ft. Btm shot 10:30:39 AM 2/19/2003 9:30 21:30 2.00 CASE P COMP Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES From- To Hours Task CodeN PI Phase Start: Rig Release: Rig Number: 2/6/2003 2/22/2003 Description of Spud Date: 12/3/1972 End: 2/22/2003 Operations ) Operations Summary Report BPEXPLORATION ') Cameron rep RILDS. Reverse circ clean seawater spotting 2 drums of NALCO EC 1124A corrision inhibitor in annulus from 2,200 ft to 8,357 ft. 3 BPM 170 psi. Finish reverse circ clean seawater spotting 2 drums of NALCO EC 1124A corrision inhibitor in annulus from 2,200 ft to 8,357 ft. 3 BPM 170 psi. Drop 1 7/8" ball & rod, allow to fall on seat in 'XN' nipple @ 8,400 ft. LD landing jt. Set Baker'S 3' pkr wi 1200 psi. Increase pressure to 3500 psi hold for 30 min tbg test. Bleed down tbg to 1500 psi. Pressure test csg to 3500 psi 130 mins. Bleed tbg pressure to 0 psi shearing the 'OCR' valve. Dry rod TWC. Test from below 1000 psi. O-K. NO BOPE. NU adapter flange and tree. Test to 5000 psi RU DSM, pull TWC, RD DSM RU Hot Oil, test lines to 3000 psi, pump 193 bbls of diesel freeze protect at 2.5 bpm at 250 to 425 psi, u-tube diesel to balance at 2200' on annulus and tubing Install BPV, Test to 1000psi NO secondary annulus valve, Secure Well, 13:30 hours on 02/22/2003 Printed: 212412003 0:30:39 AM rig at 2/22/2003 11 :30 12:30 04:00 04:30 06:00 07:30 08:30 02:00 00:00 02:30 2:30 3:30 04:30 06:00 07:30 08:30 11 :30 02:00 04:00 02:30 .00 .00 0.50 1.50 1.50 1.00 3.00 .50 0.50 RUNCOrvP 2.00 RUNCOrvP WHSUR P WHSUR P RUNCOrvP BOPSURP WHSUR P WHSUR P WHSUR P RUNCOrvP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Release 22:30 - 23:00 23:00 - 00:00 10:30 - 12:00 12:00 - 13:00 13:00 - 13:30 13:30 - 14:30 14:30 - 22:30 0.50 1.00 1.50 PERF P 1.00 RUNCOrvP 0.50 RUNCOrvP 1.00 RUNCOrvP 8.00 RUNCOrvP RUNCOrvP RUNCOrvP COMP COMP COMP COMP COMP COMP COMP 01:30 09:00 09:30 09:00 09:30 10:30 7.50 PERF 0.50 PERF 1.00 PERF P P P COMP COMP COMP 2/21/2003 23:30 - 00:00 00:00 - 01 :30 0.50 PERF 1.50 PERF P P COMP cOMP 9,969 ft. P/U Wt 165k, S/O Wt 160k. Pressure up to 3500 psi. Perforate 4 1/2" csg 9,380 ft - 9,969 ft w/2 1/2" 'Millennium' guns, 4 SPF, 11 gr, 26.5" penetration. Good surface indication of shots firing wi sound recorder & pipe movement. Observe well static. POH to 9,280 ft. Observe well static. CBU @ 420 GPM, 2000 psi. Finish CBU @ 420 GPM, 2000 psi. Observe well static. Pump dry job. POH wi perf guns. LD 4" DP. Hole taking proper displacement. RD 4" DP handling equip. RU for 27/8" DP. POH wi perf guns. LD 27/8" DP. Hole taking proper displacement. LD perf guns. All shots fired. Rinse guns prior to LD. Clear & clean rig floor from all excess equip. Pull wear bushing. LD same. PU & RU 4 1/2" tubing handling equip. Run 4 1/2" 12.6#, L 80. IBT completion to 8,414 ft. Space out & land wi WLEG @ 8,412 ft. P/U Wt 120K, S/O Wt 120k. Avg MU TQ 4200 ft Ilbs. Baker Lok all connections below pkr. 2/20/2003 22:30 - 23:00 23:00 - 23:30 0.50 PERF 0.50 PERF P P COMP COMP Date Legal Well Name: C-01 Common Well Name: C-01 Event Name: REENTER+COMPLETE Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 2ES Frorn- To Hours Task Code .. N PT Start: 2/6/2003 Rig Release: 2/22/2003 Rig Number: Descri ption of Spud Date: 12/3/1972 End: 2/22/2003 Operations ) .OperationsS.ummary.Report BPEXPLORAl'"ION ) '" ) Cfo3 -dlO ) 26-Mar-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for We C-O 1 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,526.34' MD Window / Kickoff Survey: 8,554.00' MD (if applicable) Projected Survey: 10,059.00' MD Please call me at 273-3545 if you have any questions or concerns Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 1 7 2003 AJaaka 00 & Gas Cons. Gommis8i0n Andlorage Sperry-Sun Drilling Services North Slope Alaska BPXA C-01A --' Job No. AKZZ2277546, Surveyed: 19 February, 2003 Survey Report 26 March, 2003 Your Ref: API 500292012101 Surface Coordinates: 5959706.00 N, 664502.00 E (70017' 46.4078" N, 148040' 04.3439" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 63.84ft above Mean Sea Level ~' 5pE!r"'......y-SUf1 DR ILL I N G '5 e AVn:::es A Halliburton Company Survey Ref: svy3995 Sperry-Sun Drilling Services Survey Report for C-01A Your Ref: API 500292012101 Job No. AKZZ2277546, Surveyed: 19 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (O/100ft) 8526.24 8.330 59.001 8449.58 8513.42 44.10 N 129.50 E 5959752.93 N 664630.50 E 48.39 Tie On Point AK-6 BP _IFR-AK 8554.00 8.020 59.000 8477.06 8540.90 46.14 N 132.88 E 5959755.03 N 664633.84 E 1.116 48.97 Window Point 8567.00 8.340 59.000 8489.93 8553.77 47.09 N 134.47 E 5959756.02 N 664635.41 E 2.462 49.25 8601 .12 11 .360 71.140 8523.55 8587.39 49.45 N 139.77 E 5959758.50 N 664640.66 E 10.696 50.80 8632.81 16.770 82.060 8554.28 8618.12 51.09 N 147.26 E 5959760.30 N 664648.11 E 18.943 54.30 ~. 8663.90 21.390 93.210 8583.66 8647.50 51.39 N 157.37 E 5959760.83 N 664658.21 E 18.866 60.50 8694.81 21.500 104.290 8612.44 8676.28 49.68 N 168.49 E 5959759.36 N 664669.37 E 13.093 68.90 8725.71 21.300 115.380 8641.23 8705.07 45.87 N 179.06 E 5959755.78 N 664680.01 E 13.094 78.55 8758.07 24.740 126.980 8671.02 8734.86 39.28 N 189.78 E 5959749.42 N 664690.88 E 17.547 90.47 8788.52 30.290 130.860 8698.02 8761.86 30.41 N 200.69 E 5959740.80 N 664701.98 E 19.145 104.25 8816.54 31.000 138.310 8722.13 8785.97 20.40 N 210.84 E 5959731.01 N 664712.34 E 13.780 118.43 8847.47 31.120 148.120 8748.65 8812.49 7.65 N 220.36 E 5959718.48 N 664722.14 E 16.354 134.32 8876.21 34.890 150.230 8772.74 8836.58 5.79 S 228.37 E 5959705.21 N 664730.44 E 13.712 149.79 8910.21 40.210 155.140 8799.70 8863.54 24.21 S 237.82 E 5959687.00 N 664740.30 E 17.942 170.01 8944.26 45.720 159.590 8824.61 8888.45 45.63 S 246.70 E 5959665.78 N 664749.64 E 18.464 192.18 8975.19 50.260 163.950 8845.31 8909.15 67.45 S 253.86 E 5959644.12 N 664757.27 E 18.026 213.57 9003.00 55.610 166.390 8862.07 8925.91 88.89 S 259.52 E 5959622.81 N 664763.40 E 20.470 233.72 9038.31 62.580 168.970 8880.19 8944.03 118.48 S 265.95 E 5959593.37 N 664770.48 E 20.709 260.63 9066.28 65.920 170.560 8892.34 8956.18 143.26 S 270.42 E 5959568.69 N 664775.50 E 12.992 282.60 9097.06 67.400 171.550 8904.54 8968.38 171.18 S 274.82 E 5959540.88 N 664780.50 E 5.643 306.93 9129.91 72.280 171.150 8915.86 8979.70 201.66 S 279.46 E 5959510.51 N 664785.80 E 14.899 333.39 9160.24 72.400 171.510 8925.06 8988.90 230.23 S 283.81 E 5959482.04 N 664790.78 E 1.198 358.20 ~ 9190.54 78.010 170.820 8932.79 8996.63 259.16 S 288.31 E 5959453.21 N 664795.91 E 18.645 383.39 9222.45 82.950 167.310 8938.07 9001.91 290.05 S 294.29 E 5959422.46 N 664802.56 E 18.901 411.01 9252.48 83.350 166.870 8941.65 9005.49 319.11 S 300.95 E 5959393.55 N 664809.86 E 1.972 437.67 9283.13 87.660 164.450 8944.05 9007.89 348. 70 S 308.51 E 5959364.13 N 664818.07 E 16.114 465.31 9313.41 88.340 161.680 8945.11 9008.95 377.65 S 317.33 E 5959335.39 N 664827.52 E 9.414 493.25 9348.85 88.340 155.050 8946.14 9009.98 410.56 S 330.38 E 5959302.77 N 664841.29 E 18.700 526.94 9377.90 89.010 154.880 8946.81 9010.65 436.87 S 342.67 E 5959276.73 N 664854.15 E 2.379 555.06 9411 .34 89.690 148.100 8947.19 9011.03 466.24 S 358.62 E 5959247.72 N 664870.74 E 20.375 587.87 26 March, 2003 - 9:53 Page 2 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for C-01A Your Ref: AP/500292012101 Job No. AKZZ2277546, Surveyed: 19 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9442.53 87.290 143.270 8948.01 9011.85 491.98 S 376.19 E 5959222.37 N 664888.87 E 17.286 618.91 9470.16 87.300 144.160 8949.32 9013.16 514.23 S 392.53 E 5959200.48 N 664905.69 E 3.218 646.46 9563.63 87.790 146.120 8953.32 9017.16 590.85 S 445.90 E 5959125.05 N 664960.72 E 2.160 739.53 9656.70 88.770 145.340 8956.11 9019.95 667.73 S 498.28 E 5959049.34 N 665014.78 E 1.346 832.17 9750.78 90.980 144.130 8956.32 9020.16 744.54 S 552.59 E 5958973.74 N 665070.76 E 2.678 925.98 820.07 S 607.92 E 5958899.43 N 665127.72 E 1.924 1019.45 '- 9844.41 89.320 143.430 8956.07 9019.91 9937.08 89.260 143.930 8957.22 9021.06 894.73 S 662.80 E 5958825.99 N 665184.22 E 0.543 1111.97 9991 .39 89.260 145.010 8957.92 9021.76 938.92 S 694.36 E 5958782.50 N 665216.74 E 1.988 1166.14 10059.00 89.260 145.010 8958.80 9022.64 994.31 S 733.13 E 5958727.97 N 665256.71 E 0.000 1233.54 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 140.480° (True). Magnetic Declination at Surface is 25.962°(12-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10059.00f1., The Bottom Hole Displacement is 1235.36ft., in the Direction of 143.598° (True). Comments ----- Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8526.24 8554.00 10059.00 8513.42 8540.90 9022.64 44.10 N 46.14 N 994.31 S 129.50 E 132.88 E 733.13 E Tie On Point Window Point Projected Survey 26 March, 2003 - 9:53 Page 3 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for C-01A Your Ref: AP/500292012101 Job No. AKZZ2277546, Surveyed: 19 February, 2003 BPXA North Slope Alaska Survey tool program for C-01A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8526.24 0.00 8526.24 8513.42 10059.00 8513.42 BP High Accuracy Gyro(C-01) 9022.64 AK-6 BP _IFR-AK(C-01A) ----' ---- 26 March, 2003 - 9:53 Page 4 of4 DrillQuest 3.03.02.002 ) ) ~o 3--0 J () 26-Mar-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-01A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,526.34 I MD Window / Kickoff Survey: 8,554.00' MD (if applicable) Projected Survey: 10,059.00 I MD Please call me at 273-3545 if you have any questions or concerns Regards, William T. Allen Survey Manager Attachment(s) RECEIVED APR 1 7 2003 Alallca 0fJ & Gas Cons' '. Anch . ComrruSliOn Ofage Sperry-Sun Drilling Services North Slope Alaska BPXA C-01A MWD '-"" Job No. AKMW2277546, Surveyed: 19 February, 2003 Survey Report 26 March, 2003 Your Ref: API 500292012101 Surface Coordinates: 5959706.00 N, 664502.00 E (70017' 46.4078" N, 148040' 04.3439" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 Kelly Bushing: 63.84ft above Mean Sea Level ~' Sper-a""Y-5Uf1 p R t L L IN G'··s e R V I t:es A Halliburton Company Survey Ref: svy3996 Sperry-Sun Drilling Services Survey Report for C-01A MWD Your Ref: API 500292012101 Job No. AKMW2277546, Surveyed: 19 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8526.34 8.330 59.000 8449.68 8513.52 44.11 N 129.51 E 5959752.93 N 664630.52 E 48.39 Tie On Point MWD Magnetic 8554.00 8.020 59.000 8477.06 8540.90 46.14 N 132.88 E 5959755.03 N 664633.84 E 1.121 48.97 Window Point 8567.00 8.340 59.000 8489.93 8553.77 47.09 N 134.47 E 5959756.02 N 664635.41 E 2.462 49.25 8601.12 11 .360 71.140 8523.55 8587.39 49.45 N 139.77 E 5959758.50 N 664640.66 E 10.696 50.80 8632.81 16.770 82.060 8554.28 8618.12 51.09 N 147.26 E 5959760.30 N 664648.11 E 18.943 54.30 ,-" 8663.90 21.390 93.210 8583.66 8647.50 51.39 N 157.37 E 5959760.83 N 664658.21 E 18.866 60.50 8694.81 21.500 104.290 8612.44 8676.28 49.68 N 168.49 E 5959759.36 N 664669.37 E 13.093 68.90 8725.71 21.300 115.380 8641.23 8705.07 45.88 N 179.06 E 5959755.78 N 664680.01 E 13.094 78.55 8758.07 24.740 126.850 8671.02 8734.86 39.29 N 189.79 E 5959749.43 N 664690.89 E 17.423 90.47 8788.52 30.290 130.770 8698.02 8761.86 30.45 N 200.72 E 5959740.83 N 664702.00 E 19.163 104.24 8816.54 31. 000 138.770 8722.13 8785.97 20.40 N 210.83 E 5959731.01 N 664712.33 E 14.762 118.42 8847.47 31.120 148.210 8748.65 8812.49 7.61 N 220.30 E 5959718.43 N 664722.08 E 15.738 134.32 8876.21 34.890 150.430 8772.74 8836.58 5.86 S 228.27 E 5959705.14 N 664730.34 E 13.774 149.78 8910.21 40.210 155.080 8799.70 8863.54 24.29 S 237.70 E 5959686.92 N 664740.17 E 17.719 169.99 8944.26 45.720 159.730 8824.61 8888.45 45.71 S 246.56 E 5959665.70 N 664749.50 E 18.659 192.16 8975.19 50.260 164.010 8845.31 8909.15 67.54 S 253.68 E 5959644.02 N 664757.10 E 17.915 213.53 9003.00 55.610 166.580 8862.07 8925.91 89.00 S 259.29 E 5959622.69 N 664763.18 E 20.600 233.66 9038.31 62.580 170.210 8880.20 8944.04 118.66 S 265.35 E 5959593.17 N 664769.88 E 21.616 260.39 9066.28 65.920 171.430 8892.35 8956.19 143.53 S 269.36 E 5959568.40 N 664774.44 E 12.571 282.13 9097.06 67.400 171.750 8904.54 8968.38 171.48 S 273.50 E 5959540.54 N 664779.18 E 4.902 306.32 9129.91 72.280 171.890 8915.86 8979.70 202.00 S 277.88 E 5959510.13 N 664784.24 E 14.861 332.65 9160.24 72.400 171.980 8925.06 8988.90 230.61 S 281.94 E 5959481.61 N 664788.92 E 0.486 357.30 .~ 9190.54 78.010 170.340 8932.79 8996.63 259.55 S 286.44 E 5959452.78 N 664794.05 E 19.240 382.49 9222.45 82.950 167.650 8938.07 9001.91 290.43 S 292.45 E 5959422.04 N 664800.74 E 17.571 410.14 9252.48 83.350 166.450 8941.65 9005.49 319.48 S 299.13 E 5959393.14 N 664808.05 E 4.185 436.80 9283.13 87.660 164.050 8944.06 9007.90 349.02 S 306.91 E 5959363.78 N 664816.48 E 16.083 464.54 9313.41 88.340 161.950 8945.11 9008.95 377.96 S 315.76 E 5959335.04 N 664825.96 E 7.286 492.49 9348.85 88.340 154.850 8946.14 9009.98 410.88 S 328.79 E 5959302.42 N 664839.71 E 20.025 526.18 9377.90 89.010 155.210 8946.81 9010.65 437.20 S 341.05 E 5959276.37 N 664852.54 E 2.618 554.29 9411 .34 89.690 148.290 8947.19 9011.03 466.64 S 356.87 E 5959247.28 N 664869.00 E 20.792 587.06 26 March, 2003 - 9:52 Page 2 of4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for C-01A MWD Your Ref: API 500292012101 Job No. AKMW2277546, Surveyed: 19 February, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 9442.53 87.290 143.670 8948.01 9011.85 492.47 S 374.31 E 5959221.84 N 664887.00 E 16.686 618.08 9470.16 87.300 144.160 8949.32 9013.16 514.78 S 390.56 E 5959199.89 N 664903.74 E 1.772 645.63 9563.63 87.790 148.080 8953.32 9017.16 592.29 S 442.61 E 5959123.54 N 664957.47 E 4.223 738.55 9656.70 88.770 143.550 8956.12 9019.96 669.22 S 494.86 E 5959047.77 N 665011.39 E 4.978 831.15 9750.78 90.980 143.440 8956.32 9020.16 744.84 S 550.83 E 5958973.39 N 665069.00 E 2.352 925.09 9844.41 89.320 146.780 8956.08 9019.92 821.63 S 604.38 E 5958897.80 N 665124.21 E 3.983 1018.40 -...-r 9937.08 89.260 144.910 8957.23 9021.07 898.31 S 656.40 E 5958822.28 N 665177.90 E 2.019 1110.65 9991.39 89.260 148.240 8957.93 9021.77 943.62 S 686.31 E 5958777.62 N 665208.80 E 6.131 1164.64 10059.00 89.260 148.240 8958.80 9022.64 1001.10 S 721.89 E 5958720.94 N 665245.63 E 0.000 1231.63 Projected Survey All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 140.480° (True). Magnetic Declination at Surface is 25.962°(12-Feb-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10059.00ft., The Bottom Hole Displacement is 1234.24ft., in the Direction of 144.205° (True). Comments ~' Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8526.34 8554.00 10059.00 8513.52 8540.90 9022.64 44.11 N 46.14 N 1001.10 S 129.51 E 132.88 E 721.89 E Tie On Point Window Point Projected Survey 26 March, 2003 - 9:53 Page 3 of 4 DrillQuest 3.03.02.002 Sperry-Sun Drilling Services Survey Report for C-01A MWD Your Ref: AP/500292012101 Job No. AKMW2277546, Surveyed: 19 February, 2003 BPXA North Slope Alaska Survey tool program for C-01A MWD Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8526.34 0.00 8526.34 8513.52 10059.00 8513.52 BP High Accuracy Gyro(C-01) 9022.64 MWD Magnetic(C-01 A MWD) ,-", '~ 26 March, 2003 - 9:53 Page 4 of4 DrillQuest 3.03.02.002 of I hope this will meet with your approval Terrie Hubble GPB Drilling & Wells 564-4628, MB7-5, Cube 718 2/12/2003 8:2 AM Additionally, I qent over another set of reports last week for: 10-403, Well Name 17-01, Permit #180-055 to Abandon for Sidetrack and a 10-401 for 17-01A, #203-028. The surface location is shown as 2443' NSL, 523' EWL, Sec. 22, T10N, R15E. In this case, the As-Built seems to be correct but the original 10-407 was not submitted with the correct data on it. I don't believe an investigation is required. just a note that the original data was incorrect (significantly!) Therefore, in the case of the well we discussed earlier this week, C-01A (permit # 203-010) I should have left the surface location to read: 1516 SNL, 879' WEL, Sec 19 T11N, R14E. Dave Douglas and I have discussed the difficulties that I am having with surface locations that we are providing on our reports not matching the previously submitted 10-407. In the past we always took the As-Built as the true record. However, we now have the capability to run the XY's that are provided in the As-Built, in a program and hopefully verify that the data is accurate. Naturally, there are generally small discrepancies, probably as a result of rounding and how our program performs the calculation versus how the surveying company calculated the data. Dave and I decided that if the difference is less than five feet, we will leave the data as originally submitted on previous reports. If it is gr.eater than five feet, we need to investigate where the error lay Hi urface Locations Bob Subject: Date: From: To: cc: Surface Locations Tue, 11 Feb 2003 17:05: 17 -0600 "Hubble, Terrie L" <HubbleTL@BP.com> "Bob Fleckenstein (E..mail)" <bob_fleckenstein@admin.state.ak.us> "Stewman, Sondra D" <StewmaSD@BP.com>, "Douglas, David W (8IS)" <DouglaDW@BP.com>, "Schnorr, DeWayne R (GeoQuest)" <SchnorDR@BP.com> :~ ) Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Exploration, Production and Refineries Section cc: BY ORDER OF THE COMMISSION DATED this ~C!- day of February. 2003 Michael L. Bill Commissioner ~?~ Sincerely, Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). This permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Enclosed is the approved application for pennit to redrill the above development well. Prudhoe Bay Unit C-OIA BP Exploration (Alaska), Permit No: 203-010 Surface Location: 1516' SNL, 882' WEL, Sec. 19, TI1N, RI4E, UM Bottomhole Location: 2471' SNL, 97' WEL, Sec. 19, TI1N, RI4E, UM Dear Mr. Isaacson: Inc. Re: Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 ~ ~!Æ~ __ ~fÆ AI~ASKA. OIL AND GAS CONSERVATION COMMISSION 'ç ,"L~ ~-e I,....J J ,) fÆ~fÆ~ 333 w. rrn AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 FRANK H. MURKOWSK/, GOVERNOR ì'l t Approved By Form 10-401 Rev. 12-01-85 Conditions of Approval: Permit Number 203 - o/ð 1 API Number 50- 029-20121-01 Samples Required DYes Hydrogen Sulfide Measures ~ Yes Required Working Pressure fC?r BOPE Other: T ( s 1- "E 0 P E k' "5 Ç" c c ORIGINAL SIGNED BY .. M L. SiII.- Com~l~sl~n~r I ' , ! 1 i L by order of the commission Date i~jiR~~riPlìcate the best of my knowledge Title Senior Drilling Engineer Commission Use Only 1 Approval Date I See cover letter ;:), 1 Lit D 3 for other requirements Mud Log Required DYes 1&1 No Directional Survey Required 3 Yes 0 No D 4K D 5K D 10K D 15K D 3.5K psi I8f No DNa D 2K 9 3K ,1e (. for CTU Contact Engineer Name/Number: 21. I hereby certify that Signed Bill Isaacson the ~riegrini is true and correct to ¡.J M- k. \\~.. ~ 896Q'-\t~ il89å4lS.;9aJffit' 8968' - 8988', 8944' - 8954' o Diverter Sketch III Drilling Program o Seabed Report III 20 AAC 25.050 Requirements Prepared By Name/Number: Terrie Hubble, 564-4628 III Filing Fee III Drilling Fluid Program Dave Wesley, 564-5773 Date "1 A'" r£.\ zoo~ 20. Attachments true vertical o Property Plat o Time vs Depth Plot Open: 8945' - 8948', 8970' Sqzd: 8900' - 8920', 8930' Open: 8929' - 8932', 8954' Sqzd: 8884' - 8904', 8914' 8975' - 8945', - 8959' 8929' 9014' - 9025' 8948' - 8950', 8998' - 9008' 8932' - 8934', o BOP Sketch o Refraction Analysis Perforation depth: measured '" j iSSìOr þ,N Ri, ì EI~"6t!-~V8E ~')7454' t. . 1m '(..~ 1~11 ~'" 'i: w¡!" l,t 1 5 200j Production Liner Casing Structural Conductor Surface Intermediate 1736' 98' 2508' 8015' 30" 18-5/8" 13-3/8" x 9-518" 11-314" x 10-314" Added) 7" 297 sx Cement 6840 sx PF II 1720 sx 'G', 2900 sx PF II (250 sx AS I; Added 02/78, See Diagram) 500 sx Class 'G' 98' 2508' 8015' 9181 98' 2508' 8005' 9200 feet 9183 feet 9156 feet 9139 feet Length Size Tubing Patch & Tools fish at about 8827 Part of Perf Assembly at about 9118' Cemented MD TVD o 17. Anticipated pressure {s~20 AAC 25.035 (e) (2)} 90 Maximum surface 2370 psig, At total depth (TVD) 8800' Setting Depth Too Bo~om MD TVD MD TVD 8400' 8388' 0063' 9121 Effective depth: 19. To be completed for Redrill, Re-entry, Present well condition summary Total depth: measured true vertical 18. Casing Program Size Hole Casino 6" 4-1/2" Weiqht 12.6# measured true vertical Specifications Grade L-80 Junk (measured) and Deepen Operations. Lenath 1663' Couolina IBT-M Plugs (measured) (1998 ) Quantitv of Cement (include staae datat 197 sx Class 'G' ,/"' 19, T11 N, R14E, UM 2. Distance to nearest property line 113. Distance to nearest well ADL 028310, 2808' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8550' MD Maximum Hole Angle / 14. Number of acres in property 2560 3250 $200,000.00 15. Proposed depth (MD and TVD) 10063' MD /9021' TVD psig At total depth 2471' SNL, 97' WEL, SEC. C-01A 9. Approximate spud d~ 02/15/03 Amount 196612, Anchorage, Location of well jt surface 1516' SNL...ß62.'d^lMEC. At top of pro~fiv~ interval 2057' SNL, 502' WEL, SEC. 19, T11 N, R14E, UM Number 2S100302630-277 8. Well or Property Name Prudhoe Bay Unit Number /' 19, T11N, R14E, UM 4. 7. Unit 11 Type Bond (See 20 AAC 25.025) " STATE OF ALASKA \ ALASKA G.....:) AND GAS CONSERVATION COMMIt,v1oN PERMIT TO DRILL 20 AAC 25.005 well 0 Exploratory 0 Stratigraphic Test o Development Gas 0 Single Zone KB) 3. Address P.O. Box Alaska 99519-6612 6. Property Designation ADL 028305 10. Field and Pool Prudhoe Bay Field Bay Pool 2. Name of Operator BP Exploration (Alaska) Inc. o Service 5. Datum Elevation (DF or Plan RKB = 64.24' Prudhoe a. Type of work o Drill ORe-Entry III Redrill o Deepen 1b. Type of ~¡G It- III Development Oil o Multiple Zone Z-l3/03 ) ) Well Name: C-Q 1 A Drill and Complete Plan Summary Type of We (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: X = 664,502.00 Y = 5,959,706.00 As-Built 1516' FNL , 882' FEL Sec. 19, T11 N, R14E Umiat /" Target Location: X = 664,896.00 Y = 5,959,173.00 TVDss 8965 Sadlerochit Zone 2 2057' FNL, 502' FEL Sec. 19, T11 N, R14E Umiat Bottom Hole Location: X = 665,311.00 Y = 5,958,768.00 TVDss 8965 24711 FNL , 97' FEL Sec. 19, T11 N, R14E Umiat AFE Number: I PBD4P2018 I I Rig: I Nabors Rig 2ES /' I Estimated Start Date: 12/15/03 /' 1 I Operating days to complete: 115.70 I MD: 110,063' I I TVD: 19,021' I 1 BF/MS: 135.74' 1 1 RKB: 164.24' I Well Desi~n (conventional, slimhole, etc.): I Horizontal Sidetrack I Objective: I Zone 2A / I CasingJTubing Program Hole Size Csgl WtlFt Gr~ Conn Length Top Btm Tbg O.D /' MDrrVD MDrrVD 6" 4 Y2" 12.6# L-80 IBT-M 1,663' 8,400 / 8,388' 10,063' / 9,121' Tubing 4 V2" 12.6# L-80 IBT-M 8,400' GL 8,400' / 8,388' Directional KOP: 18,550' MO Maximum Hole Angle: -8.5° in original well bore at -8,520' MO, and 90.0° from 9,470' - 10,063' MO, in the 6" production interval. Close Approach Well There are no 'close approach' issues: The closest well to the C-01 A is the C-01 original well bore. Survey Program: Standard MWO with IIFR / Cassandra. / C-01 A Sidetrack Page Casing Size I 4 1/2", 12.6#, L-80 Production Liner Basis: Lead: None Tail: Based on -82' of 4 1/2" shoe track, 1,513 of 6" open hole with 40% excess, liner lap, and 200' of 7" X 4" DP annulus volume. Tail TOC: -8,400' MD (-8,388'TVD) Liner top. Fluid Sequence & Volumes Pre 15bbls CW100 Flush Spacer Lead Tai C-01 A Sidetrack 41 bbl 1231 fe 19 BHST -197° F ~. Page 2 15.8 ppg and @f/Sk, sks of 25bbls MudPUSH at 9.5ppg None Dowell 'G' at r 150' of 4 Y2" x 7" Cement Program Open Hole: Cased Hole: 6" Production: Drilling Sample Catchers - Two, at Company man call out throughout entire interval: Recorded MWD Dir/GR/Res/ABI- Real time GR/Res Den/Neu throuqh build interval. None None Logging Program Production Mud Properties: Flo-Pro Density (ppg) Y LSRV PV 8.5 - 8.6 / I -35,000 7 - 11 VP 25 - 30 6" production interval I LSVP I 4-8 I MBT <6 pH 9.0 - 9.5 API FI 4-6 Window Milling Mud Properties: Flo-Pro Density (ppg) I LSRV I Funnel Vis 8.5 - 8.6 -35,000 7 - 11 I Whip Stock Window 7" VP I LSVP 35 + 4 - 8 I MBT pH 9.0- 9.5 API FI <6 Mud Program ) ) ) ) Well Control Well control equipment consisting of 5,OOOpsi working pressure pipe rams (2), blind/shear rams, and an annular preventer will be installed and is capable of handling maximum potential surface pressures. The ram configuration will be: 'GK' Hydril 3 Y2" X 6" (variable pipe upper) Blind Shear ram 2 7/8" X 5" (variable pipe lower) RIG FLOOR + I I JA. JA. JA. JA. JA. JA. JA. DRIP PAN f I I .." I I JA. r , HYDRIL SIN H67879 .." T \.. ~ ì r .." I JA. DBL GATE 31/2" X 6" VARIABLE TOP7NGED PIPE RAM: 13" BORE """ SIN R4683 ---.- I I / SHEAR BLIND RAM: 13 5/8" BORE ~ .." " BOTTOM STUDDFD JA. I I ~ MUD ~ CROSS " I I / JA. DBL STU D 27/8" X 5" VARIABLE SINGLE PIPE RAM " " SIN 2714 JA. " JA. I I [ MUD CROSS ~ l .." I I " JA. ~ TBG SPOOL ~ .." " JA. \ BASE ( FLANG E GROUND LEVEL 1 C-01 A Sidetrack Page 3 C-01 A Sidetrack TD Criteria: TD wil TZ2B 22TS 21TS PGOC TZ1B THaT TZ1A BSAD be as planned. at the end of the target polygon 9254 9043 8712 8782 8847 TSHU I TOP SHUBLIK TSAD I TZ4B UPPER TCGL BCGL TZ2 KINGAK TJD TJC TJA SAG RIVER WS2 WS1 CM3 CM1 THRZ BHRZ 5646 5850 6034 7067 7406 7590 7600 7955 8019 8258 8345 8377 8453 8630 8695 8750 8813 8882 8905 8957 8960 9000 9015 Est. Pore Pressure 3250psi (-7.1ppg EMW) ./" Page 4 &.G No annular injection in this well. Cuttings Handling: Cuttings generated from drilling operations will be hauled at DS-04. Any metal cuttings will be sent to the North Slope Borough. Fluid Handling: Haul all drilling and completion fluids and other Class injection. Haul all Class I wastes to Pad 3 for disposal. Formation Markers Formation Tops (Wp#7) MD TVDss Comments · · · wastes to DS-04 for to grind and inject · · Production Section- · Maximum anticipated BHP · Maximum surface pressure: (based upon BHP and a full column of gas Planned BOP test pressure: Planned completion fluid -3250 pSi @ 8800' TVDss - Z2 -2370 psi @ surface from TD @ 0.10 psi/ft) / 3500 psi 8.6 ppg seawater / 7.2 ppg Diesel BOPE and drilling Based upon calculations below, BOP equipment ) fluid system schematics are currently on wi file with the AOGCC. be tested to 3500 psi ) C-01 A Sidetrack Page 5 Estimated Spud Date: Estimated Pre-rig Start Date: 02/15/03 / 02/01/03 2. MIRU slick line. Pull the ball and packer. Install gas lift valves. Install well house and instrumentation rod I RHC plug from landing nipple below the production Post-Ri~ Work: RiQ Operations: 1. MI/RU Nabors 2ES 2. Circulate out freeze protection and displace well to seawa;ør. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. 4. Pull the 4%" X 3Y2" tubing from the TIW SBR at 7,402' MD and above (SBR was sheared during initial completion and barrel should pull free from slick-stick). P/U 4" drill pipe and RIH with overshot assembly. Latch the slick-stick on top of the TIW HBBP-R ./ packer and rotate the K-Anchor free. POOH. RIH with spear assembly. Latch the TIW HBBP-R packer and pull free with straight pull. POOH.' / RIH with overshot assembly and retrieve the remaining free tubing from the cut at 8,700' MD. POOH. ~ M/U 6" milling BHA and RIH. With sufficient length and weight of drill pipe in the hole, M/U a HES 9 5/8" storm packer. RIH and set storm packer. Change out the 9 5/8" casing pack off. POOH with storm packer. r- Continue RIH with milling assembly. Drift dO~~O . he remaining t~ing stump. POOH. R/U Eline. RIH and set a 7" bridge plug at ,5 ' MD. POOH. Pressure test the 9 5/8" X 7" from surface, a: inst the bridge plug, to 3,500psi for 30 minutes. Record the test. P/U and RIH with 7" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Displace the well to the 8.6ppg Flo-Pro based milling fluid. /" Mill window in 7" casing at ± 8,550' MD. Pull up into 7" casing and conduct an FIT to 10.Oppg EMW. POOH. RIH with 6" Dir/GR/Res/ABI DenlNeu assembly. Kick off and drill the 6" ~tion to TD of approximately 10,065' MD in Zone 2A, according to the directional proposal. POOI-j.,·' Run and cement a 4 Y2", 12.6#, L-80 production liner. POOH. / R/U and RIH with Halliburton 2 %" dpc perforating guns. Perforate per Halliburton recommendation POOH. I' Run a 4 1/2", 12.6#, L-80 completion, stinging into the 4 1/2" liner tie back. / Set packer and test the tubing and annulus to 3,500psi for 30 minutes. l Nipple down the BOPE. Nipple up and test the tree to 5,000psi. ¡' Freeze protect the well to -2,200' and secure the well. Rig down and move off. 17. 18. 19. 20. 21. 9. 10. 11. 6. 7. 8. 5. 15. 16. 13. 12. 14. Set TWC. Sidetrack and Complete Procedure Summary ) ) C-01 A Sidetrack Page 6 » » Hazards and Contingencies » A 7" whip stock will be run and set production liner. Once milling is complete, make sure all BOP equipment is operable. remove any metal cuttings, which may have settled there. in the existing 7" Wash out BOP stack to Job 3: Run Whip Stock Reference RP .:. "De-completions" RP A 9 5/8" X 3 %" TIW HBBP-R packer must possible trapped gas below the packer. » » be retrieved during this de-completion. Be alert for test The existing wellhead is a McEvoy Conventional and has a 7" IJ4S X 4 1/2" TDS tubing hanger. Verify the hanger type and connection. Be prepared with necessary equipment to remove There is a 4 %" Otis SSSV with dual control lines Hazards and Contingencies ~ Two separate barriers, the cement plug and the seawater, isolate the C-01 well bore. Prior pulling the tree, verify a static column of seawater to surface and that no pressure exists. If necessary, shoot a fluid level prior to rig MIRU Monitor the well to ensure the NORM all retrieved well » » head and completion equipment. » fluid column is static, prior to pulling the completion to Job 2: De-complete Wel Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP ~ Post Permit to Dri and Summary of Dnlllng Hazards In 10ppm, the dog house and camp prior to spud The maximum Closest C-02 C-34 SHL Wells Oppm Oppm level recorded of H2S on the pad was Closest BHL Wells C-21 0 ppm C-30 0 ppm in 10/2000. / C-Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautíons should, however, be followed at all times. Recent H2S data from the pad is as follows: » Hazards and Contingencies » No wells will require shut-in for the rig move onto C-01. However, C-34 is 49' to the South and C- 02 is 100' to the North. These are the closest neighboring wells. Care should be taken while moving onto the well. Spotters will be used at all times Job 1 MIRU ) ) C-01 A Sidetrack Expect to lose fluid to the formation after prepared with LCM if necessary Page 7 » Hazards and Contingencies » The well will be DPC perforated, -600psi overbalanced, after running the 4 V2" liner. Ensure all personnel are well briefed on Halliburton's perforating procedures and that all responsibilities are understood. Only essential personnel should be present on the rig floor while making up DPC guns. perforating Have ample seawater on location and be Job 10: DPC Perforate .:. 'Modified Conventional Liner Cementing" RP Reference RP ~ ~ ~ ~ Sufficient The completion design is to run a 4 Y2", 12.6#, L-80 liner throughout the production interval Differential sticking is a concern. The 8.6ppg Flo-Pro will be -600psi over balanced to formation. Minimize the time the pipe is left stationary while running the liner. with rotation Ensure the liner top packer is set prior to POOH. Slack off down weight, as per Baker representative. 4 Y2" liner will be run to extend -150' back up nto the 7" nero to the maximum allowable the Ivishak Hazards and Contingencies Job 9: Install 41h" Production Liner .:. 'Prudhoe Bay Directional Guidelines" RP .:. 'Standard Operating Procedure: Leak-off and Formation Integrity Tests" Reference RP There are no anticipated fault crossings while drilling C-01A. The nearest surrounding faults are of relatively small throw, -15 feet. Historically, these have not been sources of significant lost circulation. They are deemed a low risk. ~ Hazards and Contingencies Job 7: Dri 6" Production Hole .:. Reference RP 'Whip stock Sidetracks" RP ) ) C-01 A Sidetrack Page 8 Reference RP .:. "Freeze Protecting an Inner Hazards and Contingencies )0> There is one close proximity surface issue, C-08. Identify all potential hazards in a pre rig move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig away from the well and about the pad. Annulus" RP Job 13: ND/NU/Release RiQ Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP Hazards and Contingencies )0> Diesel will be used to freeze protect the well pressure is - 0.1 psia at 100° F. The diesel flash point is 00° F. Diesel vapor Job 12: Run Completion Reference RP .:. "Drill Pipe Conveyed Perforating" RP ) ) :s ¢: o ~ -'" õ.. ~ 8800 1: >- ., ;:I ~ bp REFERENCE INFORMATION COMPANY DETAILS BP Amo<;o Cak:ublion Mclhod: Minimum a.va1lo1: ~~= ~~W¿;OOcrNonh Error Surface: Elliptical + Casing Wamin~ McIhod: Rules Based Co-ordioate (NÆ) Reference: Well Centre: C-OI, True North Vertical (IVD) Refeær>:e: 65.11' 65.11 Section (VS) Reference: Slot - 01 (O.OON,O.OOE) Measured Depth Reference: 65.11' 65.11 Où<:uJation MeIho<t MinimJm CUvature CASING DETAILS All TVD depths are ssTVD plus 65. 71' for RKBE. No. TVD MD Name Size 9020.71 10063.15 4112" 4.500 FORMATION TOP DETAILS No. TVDPath MDPath Fonnation 1 8694.71 8711.76 TCGL 2 8758.71 8781.51 BCGL 3 8814.71 8846.96 23SB 4 8948.71 9043.34 21TS 5 9016.71 9254.26 TZlB 8400- Start Dir 12/100' : 8550' MD, 8536.96'TVD / Start Dir 12.21100' : 8570' MD, 8556.75'TVD ./ 8600 9000 200 400 600 Vertical Section at 140.480 [200ft/in] 800 SURVEY PROGRAM Plan: C.Ola wp07 (C-O 1 /Plan C-Ola) Depth Fm Deplh To SurveylPIan Tool Created By: Ken Allen Date: 10/312002 8550.00 10063.16 Planned: C-Ola wp01 V9 MWD Checked: Dale Reviewed: Date WELL DETAILS Name +NI-S +Ð-W Non!ñng Easting latitude Loognude Stot C-O I 2444.61 2005.43 5959106.00 664502.00 10"11'46.408N 148"40'04344W 01 T ARGEf DETAILS Nam:: 1VD +W-S +EI-W Northing Hasting Shape C-Ola Poly 9020.71 -824.68 385.01 5958890.00 664905.00 Polygon C-Ola Flt#1 9020.71 -298.90 -328.64 5959400.00 664180.00 Polygon C-Ola Flt#2 9020.11 -143.12 94.90 5959565.00 664600.00 Polygon C-Olo Flt#3 9020.11 -618.10 114.50 5959090.00 664630.00 Polygon C-Olo FlI#4 9020.11 -111430 362.41 5958S4û.00 664890.00 Polygon C-O 10 Db 9020.71 -955.s5 18833 5958168.00 665311.00 Point C-Ola TIc 9020.11 -54 153 382.21 5959173.00 664896.00 Poinl SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target 1 8550.00 8.09 59.00 8536.96 45.72 132.17 ~o 0.00 48.84 2 8570.00 8.64 75.12 8556.75 46.83 134.83 .00 85.00 49.68 3 9301.89 89.48 163.80 9019.52 -380.70 331.57 12.20 88.77 504.67 4 9396.58 89.48 163.80 9020.38 -471.63 357.99 0.00 0.00 591.62 5 947Q.62 90.00 157.90 9020.71 -541.53 382.27 8.00 -85.02 660.99 C-Ola TIc 6 9919.98 90.00 121.95 9020.71 -879.78 666.84 8.00 -90.00 11 03.0 1 -" 7 10063.16 90.00 121.95 9020.71 -955.55 788.33 0.00 0.00 1238.77 C-Ola T3b Total Depth: 10063.16' MD, 9020.71' TVD ~' o ¿ rfJO ~rfJ° I ¡jo, I I Jß 1;0· ,II II III .?ooo /000 ~~ ~ ~ 1000 1200 d -400 :s ¢: 0 ~ :;::- ?: 1:: 0 ~ ~ 0 -600 f/J COMPANY DETAII.s REFERENCE INFORMATION Depth Fro DepUJ To Sum'ylPJan 8550.00 10063.16 Planned: C-01a "¡>07 V9 Date P Amo<o Co-ooJioa!e (NIE) Reference: WeU Centre: C-01, Tn>: North Vertical (lVD) Refe""",,: 65.71' 65.71 Section (VS) Relereoœ: Slot - OJ (O.OON,O.OOE) Mea5lR"ed Depth Reference: 65.7\" 65.71 CakuJatioo MeIbod: Minimum Curvature Calculation Method: Mini",.." Ouvalllre ~ ~.=: ~~v~:in&.'f Non/¡ Error Surlåcc: rJliplical + Casing WamiOl Method: Rules ßaSC<! -200 SURVEY PROGRAM Plan: C.{)la wp07 (C-OIlPlan C'{)la) Tool Created By: Ken Allen Date: JOß/2002 MWD Che<:ked: Date' Reviewed: ~ +N'-S +EI-\V WELL DETAILS Easliug Longitude Slot Northing Latitude C-01 2444.67 2005.43 5959706.00 664502.00 70ol7'46.408N 148"4OlJ4344W 01 TARGET DETAILS Name TVD +NI-S +E!.W N>rthing Easting Sbape C-Ola Poly 9020.71 -555.13 180.91 5959155.00 664695.00 Polygon C-Ola Flt#1 9020.71 -325.68 -19.\3 5959380.00 664490.00 Polygon C-Ola FlLli2 9020.71 -143.12 94.90 5959565.00 664600.00 Polygon C-Ola Flt#3 9020.71 -618.70 11450 5959090.00 6646.JO.OO Polygon C-Ola Fltfi4 9020.71 -117430 362.41 5958540.00 664890.00 Polygon C-Ola Db 9020.71 -95555 78833 5958768.00 665311.00 Point C-Ola Tic 9020.71 -54153 38227 5959173.00 664896.00 Point SECfION DETAILS All TVD depths are See MD Ine Azi TVD +N/-S +E/-W DLeg TFaee VSec Target ssTVD plus 65.71 'for RKBE. I 8550.00 8.09 59.00 8536.96 45.72 132.17 0.00 0.00 48.84 2 8570.00 8.64 75.12 8556.75 46.83 134.83 12.00 85.00 49.68 3 9301.89 89.48 163.80 9019.52 -380.70 331.57 12.20 88.77 504.67 4 9396.58 89.48 163.80 9020.38 -471.63 357.99 0.00 0.00 591.62 5 9470.62 90.00 157.90 9020.71 -541.53 382.27 8.00 -85.02 660.99 C-Ola TIe 6 9919.98 90.00 121.95 9020.71 -879.78 666.84 8.00 -90.00 1l03.01 7 10063.16 90.00 121.95 9020.71 -955.55 788.33 0.00 0.00 1238.77 C-Ola Db-- CASING DETAILS FORMATION TOP DETAILS No. TVD MD Name Size No. TYDPath MDPath Fonnation 9020.71 10063.15 41/2" 4.500 I 8694.71 8711.76 TCGL 2 8758.71 8781.51 BCGL 3 8814.71 8846.96 23SB 4 8948.71 9043.34 21TS 5 9016.71 9254.26 TZIB -800 -1000 -1200 200 400 600 West(-)Æasl(+) [200ft/in] 800 1000 /~ . ~>rl~::¡ ~_....t' -- '. I'¡p/'/ 'L . '.. .J ~. / :It' .'::~::::. . I ;./ '" " ...... ". ,I ".:,., +. ~... . "'- ..... JP' /" t ...., ". '. ~ / .' ~ '. ¡ .......j 'I: :vl</ f" :! ~ , i '. , : ~_.~"~ ~- ¡ : ./ .... ."toO II ....... 7i'./ . /~ :l ~ ~~;~ ~+ .~. C-01 a Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 -Polygon 6 9020.71 9020.71 9020.71 9020.71 9020.71 9020.71 9020.71 -555.13 -555.13 -371.36 -283.57 -463.35 -559.91 -1086.90 180.91 180.91 239.95 341.90 558.03 856.01 939.50 5959155.00 664695.00 5959155.00 664695.00 5959340.00 664750.00 5959430.00 664850.00 5959255.00 665070.00 5959164.99 665370.00 5958639.99 665465.00 70 70 70 70 70 70 70 17 40.948 N 17 40.948 N 17 42.755 N 17 43.619 N 17 41.851 N 17 40.901 N 17 35.718 N 148 39 59.071 148 39 59.071 148 39 57.350 148 39 54.379 148 39 48.080 148 39 39.395 148 39 36.964 Description Dip. Dir. TVD ft +N/-S ft +E/-W ft Map Northing ft Map Easting ft --> W W W W W W W Name <-- Latitude Deg Min Sec <- Longitude Deg Min . Sec Targets 8711.76 8781.51 8846.96 9043.34 9254.26 0.00 0.00 0.00 0.00 0.00 8694.71 8758.71 8814.71 8948.71 9016.71 TKNG TKD TJc TSGR TSAD TCGL BcGL 23SB 21TS TZ1B --> 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 Formations 10063.15 9020.71 4.500 6.125 4 1/2" Casing Points Plan: Principal: C-01 a wp07 Yes Date Composed: Version: Tied-to: 10/2/2002 9 From: Definitive Path Current Datum: Magnetic Data: Field Strength: Vertical Section: 7/1/2002 57530 nT Depth From (TVD) ft 0.00 65.71 +N/-S ft 0.00 Height 65.71 ft Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 C-01 8550.00 ft Mean Sea Level 26.18 deg 80.81 deg Direction deg 140.48 Wellpath: +N/-S +E/-W Position Uncertainty: Well c-01 C-01 Position: Plan C-01 a 2444.67 2005.43 0.00 ft ft ft Northing: Easting : 5959706.00 664502.00 ft ft Slot Name: Latitude: Longitude: 70 148 01 17 40 46.408 N 4.344 W Well: Site Position: From: Map Position Uncertainty: Ground Level: 0.00 0.00 PB C Pad TR-11-14 UNITED STATES: North Slope Northing: Easting: ft ft 5957218.72 662550.03 ft ft Latitude: Longitude: North Reference: Grid Convergence: 70 148 17 41 22.367 N 2.797 W True 1 .24 deg Site: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 927 Field ) BP KW A Planning Report MAP ') 8846.96 8850.00 8875.00 8900.00 8925.00 34.93 35.29 38.24 41.20 44.18 151.32 151.48 152.76 153.89 154.89 8814.71 8817.20 8837.22 8856.45 8874.83 8749.00 8751.49 8771.51 8790.74 8809.12 5959690.96 5959689.44 5959676.37 5959662.26 5959647.14 664697.10 664697.97 664705.24 664712.72 664720.38 138.82 140.54 155.19 170.76 187.21 12.20 12.20 12.20 12.20 12.20 235B MWD MWD MWD MWD 8750.00 8775.00 8781.51 8800.00 8825.00 23.69 26.54 27.29 29.43 32.35 143.63 146.18 146.76 148.26 150.00 8730.27 8752.90 8758.71 8774.98 8796.43 8664.56 8687.19 8693.00 8709.27 8730.72 5959730.58 5959722.03 5959719.61 5959712.30 5959701.43 664671.26 664677.54 664679.22 664684.09 664690.91 91.94 102.52 105.45 114.17 126.85 12.20 12.20 12.20 12.20 12.20 MWD MWD BCGL MWD MWD 8650.00 8675.00 8700.00 8711.76 8725.00 13.14 15.56 18.17 19.44 20.89 123.31 130.83 136.31 138.39 140.43 8635.44 8659.66 8683.58 8694.71 8707.14 8569.73 8593.95 8617.87 8629.00 8641.43 5959752.61 5959748.96 5959744.06 5959741.33 5959737.93 664649.27 664654.27 664659.61 664662.23 664665.28 60.90 66.92 74.12 77.90 82.47 12.20 12.20 12.20 12.20 12.20 MWD MWD MWD TcGL MWD 59.00 75.12 79.17 98.00 112.73 8536.96 8556.75 8561.69 8586.38 8610.99 8471.25 8491.04 8495.98 8520.67 8545.28 5959754.60 5959755.77 5959755.95 5959756.11 5959754.99 664633.13 664635.76 664636.49 664640.37 664644.64 48.84 49.68 50.01 52.43 56.06 0.00 12.00 12.20 12.20 12.20 Start Dir 12/100' : 8550' MD, Start Dir 12.2/100' : 8570' MD MWD MWD MWD Survey 8.09 8.64 89.48 89.48 90.00 90.00 90.00 59.00 75.12 163.80 163.80 157.90 121.95 121.95 8536.96 8556.75 9019.52 9020.38 9020.71 9020.71 9020.71 45.72 46.83 -380.70 -471.63 -541.53 -879.78 -955.55 132.17 134.83 331.57 357.99 382.27 666.84 788.33 0.00 12.00 12.20 0.00 8.00 8.00 0.00 0.00 2.72 11.05 0.00 0.70 0.00 0.00 0.00 80.62 12.12 0.00 -7.97 -8.00 0.00 0.00 85.00 88.77 0.00 -85.02 -90.00 0.00 c-01a T1c C-01 a T3b Plan Section Information C-01a T1c 9020.71 -541.53 382.27 5959173.00 664896.00 70 17 41.082 N 148 39 53.203 W C-01 a T3b C-O 1 a Flt#4 -Polygon 1 -Polygon 2 9020.71 9020.71 9020.71 9020.71 -955.55 -1174.30 -1174.30 -1200.13 788.33 362.41 362.41 857.00 5958768.00 665311.00 5958540.00 664890.00 5958540.00 664890.00 5958525.00 665385.00 70 70 70 70 17 37.010 N 7 34.859 N 7 34.859 N 7 34.604 N 148 39 41.369 W 148 39 53.782 W 148 39 53.782 W 148 39 39.368 W C-O 1 a Flt#3 -Polygon 1 -Polygon 2 9020.71 9020.71 9020.71 -618.70 -618.70 -1138.06 114.50 114.50 78.12 5959090.00 664630.00 5959090.00 664630.00 5958570.00 664605.00 70 70 70 17 40.323 N 17 40.323 N 17 35.215 N 148 40 148 40 148 40 1.007 W 1.007 W 2.067 W C-01 a Flt#2 -Polygon 1 -Polygon 2 9020.71 9020.71 9020.71 -143.12 -143.12 -369.50 94.90 94.90 154.96 5959565.00 664600.00 5959565.00 664600.00 5959340.00 664665.00 70 70 70 17 45.000 N 17 45.000 N 17 42.774 N 148 40 1.578 W 148 40 1.578 W 148 39 59.827 W C-01 a Flt#1 -Polygon 1 -Polygon 2 9020.71 9020.71 9020.71 -325.68 -298.90 -325.68 -19.13 -328.64 -19.13 5959380.00 664490.00 5959400.00 664180.00 5959380.00 664490.00 70 70 70 17 43.205 N 17 43.468 N 17 43.205 N 148 40 148 40 148 40 4.902 W 3.923 W 4.902 W 9020.71 -1053.66 335.04 5958660.00 664860.00 70 17 36.045 N 148 39 54.580 W Targets } BP KW A Planning Report MAP ) ) BP ) KW A Planning Report MAP !:!! !I: ~' I) II Survey 'it IS 8950.00 47.16 155.78 8892.29 8826.58 5959631.05 664728.19 204.50 12.20 MWD 8975.00 50.15 156.59 8908.81 8843.10 5959614.06 664736.13 222.56 12.20 MWD 9000.00 53.14 157.34 8924.32 8858.61 5959596.19 664744.19 241.35 12.20 MWD 9025.00 56.14 158.03 8938.79 8873.08 5959577.50 664752.34 260.83 12.20 MWD 9043.34 58.34 158.50 8948.71 8883.00 5959563.31 664758.37 275.51 12.20 21TS 9050.00 59.14 158.67 8952.17 8886.46 5959558.05 664760.56 280.92 12.20 MWD 9075.00 62.15 159.27 8964.42 8898.71 5959537.90 664768.82 301.58 12.20 MWD 9100.00 65.15 159.84 8975.52 8909.81 5959517.08 664777.10 322.75 12.20 MWD 9125.00 68.16 160.39 8985.42 8919.71 5959495.68 664785.37 344.37 12.20 MWD 9150.00 71.17 160.91 8994.11 8928.40 5959473.74 664793.62 366.37 12.20 MWD 9175.00 74.18 161.41 9001.55 8935.84 5959451.33 664801.81 388.69 12.20 MWD 9200.00 77.20 161.90 9007.73 8942.02 5959428.51 664809.94 411.28 12.20 MWD 9225.00 80.21 162.38 9012.63 8946.92 5959405.35 664817.96 434.06 12.20 MWD 9250.00 83.23 162.84 9016.23 8950.52 5959381.92 664825.87 456.97 12.20 MWD 9254.26 83.74 162.92 9016.71 8951.00 5959377.90 664827.20 460.89 12.20 TZ1B 9275.00 86.24 163.31 9018.52 8952.81 5959358.27 664833.64 479.95 12.20 MWD 9301.89 89.48 163.80 9019.52 8953.81 5959332.67 664841.80 504.67 12.20 End Dir : 9301.89' MD, 9019.5 9396.58 89.48 163.80 9020.38 8954.67 5959242.35 664870.20 591.62 0.00 Start Dir 8/100' : 9396.58' MD 9400.00 89.51 163.53 9020.41 8954.70 5959239.09 664871.24 594.76 8.00 MWD 9450.00 89.86 159.54 9020.68 8954.97 5959192.04 664888.10 641 .41 8.00 MWD 9470.62 90.00 157.90 9020.71 8955.00 5959173.00 664896.00 660.99 8.00 C-01a T1c 9500.00 90.00 155.55 9020.71 8955.00 5959146.27 664908.20 689.20 8.00 MWD 9550.00 90.00 151.55 9020.71 8955.00 5959102.02 664931.44 737.90 8.00 MWD 9600.00 90.00 147.55 9020.71 8955.00 5959059.49 664957.71 787.26 8.00 MWD 9650.00 90.00 143.55 9020.71 8955.00 5959018.90 664986.88 837.05 8.00 MWD 9700.00 90.00 139.55 9020.71 8955.00 5958980.44 665018.81 887.04 8.00 MWD 9750.00 90.00 135.55 9020.71 8955.00 5958944.31 665053.35 936.96 8.00 MWD 9800.00 90.00 131.55 9020.71 8955.00 5958910.67 665090.32 986.59 8.00 MWD 9850.00 90.00 127.55 9020.71 8955.00 5958879.69 665129.56 1035.67 8.00 MWD 9900.00 90.00 123.55 9020.71 8955.00 5958851.53 665170.85 1083.97 8.00 MWD 9919.98 90.00 121.95 9020.71 8955.00 5958841.09 665187.89 1103.01 8.00 End Dir : 9919.98' MD, 9020.7 10000.00 90.00 121.95 9020.71 8955.00 5958800.24 665256.69 1178.88 0.00 MWD 10063.15 90.00 121.95 9020.71 8955.00 5958768.01 665310.99 1238.75 0.00 41/2" 10063.14 90.00 121.95 9020.71 8955.00 5958768.01 665310.98 1238.74 0.00 Total Depth: 10063.16' MD I 90 10063.16 90.00 121.95 9020.71 8955.00 5958768.00 665311.00 1238.77 0.00 C-01 a T3b DATE 02/23/78 03/14/90 01/29/01 03/09/01 09/14/01 SIS-lsl SIS-LG RNlTP COMMENTS ORIGINA L COMPLETION RWO CONVERTED TO CANVAS FINAL CORRECTIONS DATE 0/15/02 REV BY DEW COMMENTS Proposed pre-rig work PRUDHOE BA Y UNIT W8..L: C-01 ÆRMIT No: 72-0300 API No: 50-029-20121-00 Sec. 19,T11N, R14E BP Exploration (Alaska) REV BY 7" LNR, 29#, N-80, 0.0371 bpf, 10 = 6.184" 1-1 9198' PBTD l-i 9156' 3-1/2" TBG, 9.2#, L-80, 0.0087 bpf, 10 = 2.992" ANGLE AT TOP PERF: 7 @ 8900' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 8900-8920 S 03/19/78 3-3/8" 4 8930-8945 S 03/19/78 5" 4 8945-8948 0 03/19/78 3-3/8" 4 8948-8950 S 03/19/78 5" 4 8970-8975 0 09/24/89 3-3/8" 4 8984-9004 S 09/24/89 2-1/8" 4 9014-9025 0 10/29/89 3-3/8" 2 8960-8970 S 03/19/78 TOP OF 7" LINER 1-1 4.) Chern ical Cut tubing during pre rig ops 1-1 I 9-5/8" CSG, 47#, N-80, 10 = 8.681" 1-1 3.) Chem ìcal Cut tubing during pre rig ops 1-1 2.) P&A Cement top; Pre Rig ops 1-1 PERFORA TION SUMMARY REF LOG: BHCS ON 01/08/73 .) Pu tubing patch during pre rig ops 1-1 1-1 8998' I 7367' j 7385' I l 7402' 7385'· 7430' I~ ~ --1 7417' :8: . j 7430' 1 ~~~~~ 7484' 1-- & ~ ../ -.4 I~~~YI ~ I I~ ~.':~""'..- ~ . ~ -8750' 8015' 7462' -8700' -7500' 9118' 8882' 8897' 1 8936' I 89561 I 89681 1 89861 I 89971 I 89931 89981 8827' 8824' 8750' 1-1 1-1 4-1/2" BLAST JOINT, 1-1 7" X 4-1/2" TIW HBBP PKR, 10 = 4.00" 1-1 4-1/2" OTIS SLIDING SLEEVE, 10 = 2.75" 1-1 7" X 4-1/2" TIW HBBP PKR, 10 = 4.00" 1-1 3-1/2" OTIS X NIP, 10 = 2.75" 1 1-1 ELMDTTLOGGING NOT AVAILABLE 1-1 3-1/2" TUBING TAIL, WLEG 1-1 3-1/2" X NIP, MILLED OUT 1-1 TOP OF 3-1/2" RCP W/ PBR PA TCHlPKR 1-1 9-5/8" TIW SBR I 1-1 9-5/8" X 3-1/2" PKR, TIW HBBP-R, 10 = 4.00" 1-1 3-1/2" RCP W/PBR PA TCHlPKR, 10 = 1.375" 1-1 9-5/8" X 7" BOT HGR PKR 1 1-1 3 1/2" Cement Retainer 1 1-1 MARKER JOINT 1 II Tubing patch, Rope socket, 3 finger I basket fingers 1-1 3-1/2" OTIS SLIDING SLEEVE, 10 = 2.75" 1 1-1 4-1/2" BLAST JOINT, 10 = 2.992", BTM @ 8986' FISH 39.77' TBG CONVEYED PERF GUN 10 = 2.992" BTM@ 8972' TREE :;: 6" CIW WELLHEAD = 13-5/8" McEVOY CONVENTIONAL AëTUÃ TOR-';-'~'''''----'-'------õTìs "K[""Ë[f~\/",;''''m^,''.'''..."....,.. ·"·"""'''·"5'15':47'' _N-M....w.v~"....·.w,.,........"'..."'.,........"'."N"."',.....""""''''Y,WMW.Y.'·HH.WHM''.'W"'w,w"",,,y,w BF. ELEV = 37.21' -KÕP";'''''' .....'",...... .........m·"5'81'i3'Î ',~~.~~~;,g'~~...~,. ':~,~:=~~~I~: Datum MD = 8871' 'båtum^f\75-;;'M''^ã'i3ÕÕ'-ŠS 0-3/4" CSG, 55.5#, N-80, 10 = 9.760" l-i 19221 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 2142' 13-3/8" CSG, 68#, NT-80, 10 = 12.415" l-i 2170' I 9-5/8" FOe 1-1 2369' 18-5/8" CSG, 96.5#, K-55, 10 = 17.655" 1-1 2508' Minimum ID = 1.375" @ 7385-7430' HES 3-1/2" RCP W/PBR PATCH/PKR -, - ~ - (- ~ . , - . L ,~ 11-3/4 x 9-5/8" THERMOCASE ~ ~~ - J t ../;:j ~ ST MD lVD 5 2995 2940 4 4998 4943 3 7005 7043 2 7286 7224 1 7347 7284 1922' 1961' 2007' 2118' 2142' 2170' 2207' 1-1103/4" X 95/8" XO 1-19-5/8" Foe 1 1-19-5/8" PBR, 12' 1-14-1/2" SSSV, OTIS LANDING NIP, 10 = 3.813" 1-14-1/2" X 3-1/2" XO 1 1-113-3/8" X 9-5/8" XO 1-19-5/8" Foe GAS LIFT MANDRELS DEV TYÆ VLV LATCH 1 OTIS RA 3 OTIS RA 3 OTIS RA 4 OTIS RA 5 OTIS RA PORT DATE 140' C 1)1 Pre-Rig u CAUT'.... \THE 7" TIW PACKERS IN THIS W8..L MAY FAIL IF MO. Jl-JAN 2100 psi DIFFERENTIAL PRESSURE IS EXCEEDED. DATE 02/23178 03/14/90 01/29/01 03/09/01 09/14/01 SIS-lsl SIS-LG RNITP COMMENTS ORIGINAL COMPlEflON RWO CONVERTED TO CANVAS FINAL CORRECTIONS DATE 10/16/02 REV BY COMMENTS DEW Proposed completion REV 7" LNR, 29#, N- - 80,0.0371 bpf, 10 = 6.184" FISH 39.77' TBG CONVEYED ÆRF GUN 2.} P&A Cement top; Pre Rig OpS -8750' I 8827' II Tubing patch, Rope socket, 3 finger basket fingers 10,063' 4-1/2",12.6#, L- 80, IBT-M liner ... ..... PRUDHOE BAY UNIT W8..L: C-01A ÆRMIT No: API No: 50-029-20121-01 Sec. 19, T11N,R14E BP Exploration (Alaska) BY 9198' Whip Stock set on bridge plug 8570' 9118' 1-1 PBTD 1-1 9156' / U /1 1922' 1-1 103/4" X 95/8" xo 11 1961' l-f 9-5/8" FOe I J - -I 2007' 1-19-5/8" PBR, 12' /1 2170' 1-113-3/8" X 9-5/8" XO I/'I 2200' 1-14-1/2" 'X' LANDING NIP, 10 = 3.813" ~ 9-5/8" CSG, 47#, N-80, 10 = 8.681" 18-5/8" CSG, 96.5#, K-55, ID = 17.655" TOP OF 7" LINER 1-1 8015' 2508' 7462' ~ g ~ i l & & L ~ J g -I I 1 ST MD TVD DEV TYÆ VLV LATCH PORT DATE 5 TBD TBD 1 4 TBD TBD 3 3 TBD TBD 3 2 TBD TBD 4 1 TBD TBD 5 8341' 1-1 41/2" 'X' nip, ID = 3.813" I 8356' 1-1 7" X 4 1/2" Baker S-3 pkr 1 8368' 1-1 4 1/2" 'X' nip, ID = 3.813" 1 8380' 1-1 4 1/2'''XN' nip, ID = 3.725" 1 - 7" X 5" Baker ZXP packer 8,400' w / TBS, HMC liner hanger XO to 4 1/2" 1-1 Window in 7" liner 9-5/8" FOC 1-1 9-5/8" FOC l-i 2207' 2369' " - ~- ~ I 13-3/8" CSG, 68#, NT-80,ID= 12.415" 0-3/4" CSG, 55.5#, N-80, ID = 9.760" 2170' 1922' - l KOP= :f0:~~::~,~~,I~,:~" Datum MD = ÖãiU'm'ïV5'·; 8550' ,w"""",~'~~~~~~,!,!~, 9471' 8955' SS 11-3/4 x 9-5/8" THERMOCASE ~ ACTUATOR = ï<Ii:"ELBT·; "'SF=:"MêLê\r;· 140' C-01A Prop.Jsed Completio u ~ W8..LHEAD = TREE 6" erN 13-5/8" McEVOY CONVENTIONAL ····õyìs ··6Š~7"1'i· ~N""37~2"F C-01 CONSULT THE C PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. A Diesel will be used to freeze protect the wel Diesel vapor pressure is .... 0.1 psia at 1000 F v" v" ./ The diese Differential sticking may be encountered in this depleted reservoir. Overbalance is approximately 600 psi. Always follow established drilling and connection practices for stuck pipe prevention. The well will be DPC perforated. Ensure all personnel are briefed on Halliburton's perforating procedures. Only essential personnel should be on the rig floor during handling of the perforating guns. flash pOint is 1000 F v" There are no fault crossings expected, during the drilling of the 6" production interval. There are surrounding faults, with small throw of 10 - 15'. No significant losses are expected, but due attention should be paid to the possibility. The lost circulation tree should be followed if lost fluid returns are encountered. v" v" v" retrieved we All wells pass major risk criteria. The closest neighboring wells, at surface, are C- 02 and C-34. C-02 is approximately 100' to the North, and C-34 is approximately 49' to the South. No shut-in should be required, but care should be taken during rig MIRU and RDMO. Use spotters as necessary. Standard Operating Procedures for H2S precautions should be followed at all times. The highest concentration currently on record is 10 ppm. October 2002. NORM test al head and completion equipment. ~- C-01 A Rig Summary of Drilli site ng Hazards )ST THIS NOTICE IN THE DOGHOUSE ) II- D 5 ~ ~ ~ . II- I: 0 L. ~ 2 D :I a ~ 5 I: D ~ 2 7 a ~ b liB 05499.1 H P054991 CHECK NO. r~_ TOTAL ~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. Alaska Oil & Gas Cons. Commission Anchorage JAN Î 5 2003 ,- RECEIVE[ ~ ~Ol R PERMIT TO DRILL FEE 12/19/2002 INV# CK121702 NET VENDOR DISCOUNT GROSS DESCRIPTION INVOICE I CREDIT MEMO DATE 12/19/2002 P054991 DATE Rev: 07/10/02 C\jody\templates DRY DITCH SAMPLE All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. SPACING EXCEPTION The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. paOT (PH) In accordance with 20 AAC 25.005(t), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). HOLE (If API number last two (2) digits are between 60-69) The permit is existing well , Permit No, API No. . Production should continue to be reported as a function 'of the original API number stated above. CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL for a new wellbore segment "CLUE of ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERlPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# ( Dev ~ Redrll -X Re-Enter _ Serv _ Well bore seg _ Y'lr.> UNIT# // C..é';"'") ON/OFF SHORE ~ 26[., ~ . " 'P Pc¡ p~¿' I' '\ PROGRAM: Exp GEOL AREA ¡f~ Y N Y N Y N Y N Y N Y N l Y N \ Y N \:-:IN ~N ý þÝ /cA :A, Y/N g .y N Ai/It- ÆY..N , N N ø N ^'~ {)Ir~ (iiJ' N llCf.lo~, @N j N N/It- N (J11V'K fJ1~ -~ mçp 2-""570 ~£ .y N ¡JIlt- YOO }fN Y... . /U. 11\ Y N . N ~¡>~. WELLNAME~ßU r..-ò//J INIT CLASS .¿;,..~/./ /-6, / WELL PERMIT CHECKLIST CÖMPANY FIELD & POOL {; ý!,ð / c: ö 1. Permit fee attached. . . . . . . 2. Lease number appropriate. . . 3. Unique well name and number. 4. Well located in a defined pool.. . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. 6. Well located proper distance from other wells.. . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . 8. If deviated, is wellbore plat included.. . . . . . . . . . 9. Operator only affected party.. . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . . . . . . . . 11. Permit can be issued without conservation order. . . . 12. Permit can be issued without administrative approval.. . . 13. W ell located wJin area & strata authorized by injection order # 14. All wells w/in X mile area of review identified. . psig 15. Conductor string provided. . . .. . . . . . 16. Surface casing protects all known USDWs. . . . . . 17. CMT vol adequate to circulate on conductor & surf csg. 18. CMT vol adequate to tie-in long string to surf csg. . . . 19. CMT will cover all known productive horizons. . . .. . . 20. Casing designs adequate for C, T, B & permafrost. . . 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . 22. If a re-drill, has a 10-403 for abandonment been approved 23. Adequate well bore separation proposed.. .... . . . . 24. If diverter required, does It meet regulations. .. . . . 25. Drilling fluid program schematic & equip list adequate. 26. BOPEs, do they meet regulation. . . . . . . . . . 27. BOPE press rating appropriate; test to '35"0 0 2ä. Choke manifold complies w/API RP-53 (May 84). 29. Work will occur without operation shutdown. . . . 30. Is presence of H2S gas probable.. . . . . . . . . 31. Mechanical condition of wells within AOR verified. 32. Permit can be issued w/o hydrogen sulfide measures. 33. Data presented on potential overpressure zones. 34. Seismic analysis of shallow gas zones. . . . . . 35. Seabed condition survey (if off-shore ). . . . . . . 36. Contact name/phone for weekly progress reports. Commentsllnstructions: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: JDH JBR C.OT DTS Ot-(OfO J MJW MLB &/ .2./"'~O.J PETROLEUM ENGINEERING: TEM WGA / GEOLOGY: RP#,-- SFD G:\geology\permits\checklist.doc ADMINISTRATION APPR DATE ~ //¢3 (Service Well Only) (Service Well Only) ENGINEERING APPR DATE \µbA- 1. \3{ O~ (Service Well Only) GEOLOGY APPR DATE ~ø~ (Exploratory Only) Rev: 10/15/02 ) ) We 1-1 ¡story File APPENDIX nformation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. " To improve the readability of the Well History file and to simplify finding infomlation, information of this nature is accumulated at the end of the file under APPENDIX. No special· effort has been made to chronologically organize this category of information page 1 # WELL CASING RECORD # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION eFT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 63 35 19 11N 14E 1516 882 00 84 74 JOB NUMBER: LOGGING ENGINEER OPERATOR WITNESS MWD RUN 2 MW2277546000 J. BOBBITT R. BORDES Comment Record TAPE HEADER PBU/WOA MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE # JOB DATA Reel Header service name LISTPE Date. . . . . . . . 03/04/15 oriTin...... STS Ree Name.......... UNKNOWN Continuation Number. .....01 previous Reel Name. ......UNKNOWN Comments.. .............. .STS LIS writing Library. Scientific Technical services Tape Header service name.......... ...LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/04/15 origin.................. .STS Tape Name. .......... .....UNKNOWN Continuation Number......Ol Previous Tape Name UNKNOWN Comments. STS LIS writing Library. Scientific Technical Services physical EOF C-01A 500292012101 BP EXPLORATION Sperry Sun 15-APR-03 ) c-Ola.tapx Sperry-Sun Drilli~T.services LIS Scan Utl lty $Revision: 3 $ LisLib $Revision: 4 $ Tue Apr 15 11:23:54 2003 ) a03~O/O J loLJI page SROP = SMOOTHED RATE OF PENETRATION WHILE SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (DEEP RESISTIVITY). TNPS = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR 2 (DEEP (SHALLOW (EXTRA (MEDIUM MWD RUNS 1,2 REPRESENT WELL C-01A API#:50-029-20121-00. THIS WELL REACHED A TOTAL DEPTH (TD) 8959'TVDSS 8 MWD RUN 200 WAS (DGR)UTILIZING GEIGER-MUELLER TUBE RESISTIVITY PHASE 4 (EWR4), COMPENSATED POROSITY(CTN), STABILIZED LITHO-DENSITY (ABI) DRILLING OF 10059'MD / (SLD)AND AT BIT INCLINATION THERMAL NEUTRON DETECTORS ELECTROMAGNETIC WAVE 7 MWD DATA FROM D SCHNORR DIRECTIONAL CONSIDERED PDC PER THE EMAIL OF 03-06-03 FOR BP EXPLORATION (ALASKA) INC WITH DUAL GAMMA RAY 6 IS GAMMA RAY DATA WAS LOGGED THROUGH CASING FOR DEPTH TIE-IN 5 IN THE INTERVAL 8527 MD 8554'MD 4 THIS WELL KICKS OFF C-01A FROM 8554'MD 8476 'TVDSS 3 MWD RUN 100 WAS DIRECTIONAL ONLY AND IS NOT PRESENTED. 2 ALL ALL DEPTHS ARE MEASURED DEPTH NOTED. VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD) 1 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS OPEN HOLE BIT SIZE (IN) 6.000 ) (MD) c-01a.tapx CASING DRILLERS SIZE (IN) DEPTH (FT) 7.000 8554.0 UNLESS OTHERWISE ) ) ') c-01a.tapx SLIDE= ORIENTED DRILLING INTERVALS AT BIT DEPTHS COMPENSATED NEUTRON POROSITY PROCESSING PARAMETERS HOLE SIZE: 6.0" MUD WEIGHT: 8.6 PPG MUD SALINITY: 12000-13000 PPM FORMATION WATER SALINITY: 10 994 PPM FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header service name......... ....STSLIB.001 service Sub Level Name... version Number........ ...1.0.0 Date of Generation...... .03/04/15 Maximum physical Record. .65535 Fi 1 e Type. . . . . . . . . . . . . . . . LO previous File Name.. .... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 # FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 8527.0 10006.5 FCNT 8550.0 9970.5 PEF 8550.0 9985.0 RPX 8550.0 10013.5 RPM 8550.0 10013.5 NPHI 8550.0 9970.5 RPS 8550.0 10013.5 RPD 8550.0 10013.5 NCNT 8550.0 9970.5 DRHO 8555.5 9985.0 RHOB 8555.5 9985.0 FET 8579.5 10013.5 ROP 8580.0 10059.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 2 8527.0 10059.0 $ # REMARKS: MERGED MAIN PASS. $ # Data Format specification Record Data Record Type 0 page 3 physical page 4 EOF File Trailer service name. ... ...... service sub Level Name version Number......... Date of Generation.. ... Maximum physical Record File T¥pe....... . Next Flle Name STSLIB.001 1.0.0 03/04/15 65535 LO STSLIB.002 First Reading For Entire File Last Reading For Entire File. 8527 10059 Name service unit DEPT FT ROP MWD FPH GR MWD API RPX MWD OHMM RPS MWD OHMM RPM MWD OHMM RPD MWD OHMM FET MWD HOUR NPHI MWD PU FCNT MWD CNTS NCNT MWD CNTS RHOS MWD G/CC DRHO MWD G/CC PEF MWD BARN Min 8527 0.14 15.26 0.43 0.66 2.23 2.54 0.6 8.92 338.07 19899.2 1.828 -0.628 0.78 Max 10059 246.31 295.94 1620.92 1620.94 2000 2000 29.48 32.45 1901.83 42386.3 2.799 O. 306 14.1 Mean 9293 48.7 28.7504 18.1761 24.071 44.1086 61.1116 2.38063 24.5093 634.073 28618.8 2.27714 0.0562657 1.93022 Nsam 3065 2956 2960 2928 2928 2928 2928 2869 2842 2842 2842 2860 2860 2871 Fi rst Reading 8527 8580 8527 8550 8550 8550 8550 8579.5 8550 8550 8550 8555.5 8555.5 8550 Last Reading 10059 10059 10006.5 10013.5 10013.5 10013.5 10013.5 10013.5 9970.5 9970.5 9970.5 9985 9985 9985 Name Service Order DEPT ROP MWD GR MWD RPX MWD RPS MWD RPM MWD RPD MWD FET MWD NPHI MWD FCNT MWD NCNT MWD RHOB MWD DRHO MWD PEF MWD units size Nsam Rep code offset channel FT 4 1 68 0 1 FPH 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 G/CC 4 1 68 44 12 G/CC 4 1 68 48 13 BARN 4 1 68 52 14 Data specification Block Type. . Log9in9 Direction.... .......... optlcal log depth units.... .... Data Reference Point........ ... Frame spacing............... ... Max frames per record....... ... Absent val ue. . . . . . . . . . . . . . . . . .. . Depth uni ts . . . . . . . . . . . . . . . . . . . . . . . Datum specification Block sub-type ) c-01a.tapx o Down Feet undefined 60 .1IN undefined -999 o ) BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) Page 5 FLO PRO 8.60 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) 6.000 8554.0 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY SLD STABILIZED LITHO DEN CTN COMP THERMAL NEUTRON EWR4 Electromag Resis. 4 $ TOOL NUMBER 65041 150253 100547 148574 # # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) BIT ROTATING SPEED (RPM) HOLE INCLINATION (DEG MINIMUM ANGLE MAXIMUM ANGLE 8601.0 91.0 19-FEB-03 Insite 6.02 Memory Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD NCNT FCNT NPHI PEF RPM RPS RPX DRHO RHOB FET ROP $ START DEPTH 8527.0 8550.0 8550.0 8550.0 8550.0 8550.0 8550.0 8550.0 8550.0 8555.5 8555.5 8579.5 8580.0 STOP DEPTH 10006.5 10013.5 9970.5 9970.5 9970.5 9985.0 10013.5 10013.5 10013.5 9985.0 9985.0 10013.5 10059.0 2 header data for each bit run in separate files 2 5000 File Header se rvi ce name.......... Service Sub Level Name version Number... ...... Date of Generation..... Maximum physical Record File Type........... . previ ous Fi 1 e Name.. . 1.0.0 03/04/15 65535 LO STSLIB.001 ) c-01a.tapx STSLIB.002 ') Name service unit DEPT FT ROP MWD020 FPH GR MWD020 API RPX MWD020 OHMM RPS MWD020 OHMM RPM MWD020 OHMM RPD MWD020 OHMM FET MWD020 HOUR NPHI MWD020 PU FCNT MWD020 CNTS Min 8527 0.14 15.26 0.43 0.66 2.23 2.54 0.6 8.92 338.07 Max Mean 10059 9293 246.31 48.7 295.94 28.7504 1620.92 18.1761 1620.94 24.071 2000 44.1086 2000 61.1116 29.48 2.38063 32.45 24.5093 1901.83 634.073 page 6 Nsam 3065 2956 2960 2928 2928 2928 2928 2869 2842 2842 First Reading 8527 8580 8527 8550 8550 8550 8550 8579.5 8550 8550 Last Reading 10059 10059 10006.5 10013.5 10013.5 10013.5 10013.5 10013.5 9970.5 9970.5 Name service order DEPT ROP MWD020 GR MWD020 RPX MWD020 RPS MWD020 RPM MWD020 RPD MWD020 FET MWD020 NPHI MWD020 FCNT MWD020 NCNT MWD020 RHOS MWD020 DRHO MWD020 PEF MWD020 Units size Nsam Rep Code offset Channel FT 4 1 68 0 1 FPH 4 1 68 4 2 API 4 1 68 8 3 OHMM 4 1 68 12 4 OHMM 4 1 68 16 5 OHMM 4 1 68 20 6 OHMM 4 1 68 24 7 HOUR 4 1 68 28 8 PU 4 1 68 32 9 CNTS 4 1 68 36 10 CNTS 4 1 68 40 11 GIcc 4 1 68 44 12 GIcc 4 1 68 48 13 BARN 4 1 68 52 14 # Data Format specification Data Record Type.... .... Data specification Block Log~ing Direction....... Optlcal log depth units. Data Reference point.... Frame Spacing........... Max frames per record... Absent value............. Depth uni ts. . . . . . . . . . . . . . Datum specification Block . . . . . . . . . . . . . . . sub-type Record Type o o Down Feet undefined 60 .1IN undefined -999 o # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN) # TOOL STANDOFF (IN) EWR FREQUENCY (HZ) # REMARKS $ c-01a.tapx MUD VISCOSITY (s) MUD PH: MUD CHLORIDES (PPM) FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE MUD FILTRATE AT MT: MUD CAKE AT MT: ") 53.0 9.0 12000 13.2 400 171 570 540 69.0 170.0 69.0 69.0 ) ) ) c-Ola.tapx NCNT MWD020 CNTS 19899.2 42386.3 28618.8 2842 8550 9970.5 RHOS MWD020 G/CC 1.828 2.799 2.27714 2860 8555.5 9985 DRHO MWD020 G/CC -0.628 0.306 0.0562657 2860 8555.5 9985 PEF MWD020 BARN 0.78 14.1 1.93022 2871 8550 9985 First Reading For Entire File . . . . . .8527 Last Reading For Entire File. ..... .10059 File Trailer service name. .......... STSLIB.002 service Sub Level Name. version Number......... 1.0.0 Date of Generation..... 03/04/15 Maximum physical Record 65535 File Type.... ...... LO Next File Name..... STSLIB.003 physical EOF Tape Trailer service name.. ..... LISTPE Date. . . . . . . . . . . . . . . 03/04/15 o ri gin. . . . . . . . . . . . . STS Tape Name.... ...... UNKNOWN Continuation Number 01 Next Tape Name..... UNKNOWN Comments. . . . . . . . . . . STS LIS writing Library scientific Technical Services Reel Trailer service name. ... ... LISTPE Date. . . . . . . . . . . . . . . 03/04/15 ori 1i n. . . . . . . . . . . . . STS Ree Name.......... UNKNOWN continuation Number 01 Next Reel Name UNKNOWN Comments. . . . STS LIS writing Library scientific Technical services physical EOF physical EOF End of LIS File page 7