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202-116
) ) Image Project Order File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~O~~- 11 (/J Order File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~escan Needed 11111111111111 RES CAN ~ Color Items: ¿ Greyscale Items: DIGITAL DATA tØ'6iskettes, No. r 0 Other, No/Type: OVERSIZED (Scannable) 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non-Scannable) 0 Other: 0 Logs of various kinds: Scanning Preparation BY: Helen ~ I x30= J() 0 Other::1 Date: '6. ~4. blf Isl m-P I 1111111111111111111 Date: ß ~Lf D if /s/ lfY\; p + ~a = TOTAL PAGES ",~ ~ (Count does n.olt include cover sheet)p Date:S( ~y blf /s/ \111, 1111111111111111111 NOTES: BY: Helen ~ Project Proofing BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: Page Count Matches Number in Scanning Preparation: Helen e If NO in stage 1 page(s) discrepancies were found: ,t;3 (Count does include cover sheet) V YES ¡ ~/ Date: ~ %í ÓLt YES NO NO /s/ VV1. P Stage 1 BY: BY: Helen Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked 1111111111111111111 8/24/2004 Orders File Cover Page.doc STATE OF ALASKA • ALASKA OI • D GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended lb. Well Class: 20AAC 25.105 20AAC 25.110 0 Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 7/22/2011 - 202 - 116 311 -120 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 07/03/2002 - 50 - 029 - 20338 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 07/06/2002 • PBU 07 -13B 628' FNL, 290' FEL, SEC. 33, T11N, R14E, UM 8. KB (ft above MSL): 52.26' 15. Field / Pool(s): Top of Productive Horizon: 4014' FSL, 4047' FEL, SEC. 28, T11N, R14E, UM GL (ft above MSL): Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 5032' FSL, 3476' FEL, SEC. 28, T11N, R14E, UM 11350' 8879' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 675897 y - 5950290 Zone- ASP4 12960' 8975' ADL 028309 TPI: x- 672022 y- 5954844 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 672567 Y 5955874 Zone- ASP4 N/A 18. Directional Survey: 0 Yes No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- DrillLateral Top Window MD/TVD: MWD, GR, ROP, Memory CNL, GR, CCL 11364' 8887' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE Top BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 Surface 108' Surface 108' 30" 243 sx Arcticset 13 -3/8" 72# L -80 Surface 2760' Surface 2728' 17 -1/2" 5600 sx Arcticset 11 9 -5/8" 47# L -80 Surface 10005' Surface 7840' 12 -1/4" 1400 sx Class 'G' 7 -5/8" 29.7# L -80 2312' 2516' 2309' 2504' 13 -3/8" (Scab Liner) 7" 29# L -80 9796' 11364' 7675' 8887' 8 - 1/2" 500 sx Class 'G' 3- 3/16" x 2 -7/8" 8.81# / 6.16# L -80 11085' 12960' 8685' 8975' 3 -3/4" 98 sx Class 'G' 24. Open to production or injection? ❑ Yes 0 - No 25. TUBING RECORD If Yes, list each interval open SIZE DEPTH SET (MD) PACKER SET (MO I TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 4 -1/2 ", 12.6#, L -80 / 13Cr80 11287' 11034' / 8646' 1 MD TVD MD TVD 11267' / 8822' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. RECE IVED DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 2�� 11350' Set Whipstock 00111 & Gsa Gam. Gon iU$ron 27. kiiltfi®iNa 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 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes 0 No Sidewall Core(s) Acquired? ❑ Yes 0 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 MC 250.071. None RBDMS SEP 0 8 7,01 ! , . , + 4 e l'i Form 10-407 Revised 12/2009 CQNTINUED ON REVERSE Su mit Original Only 29. GEOLOGIC MARKERS (List all formations and markrcountered): 30. FSAATION TESTS NAME MD TVD Well Tested? ❑ Yes CI No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 22TS 11293' 8841' None 21 TS / Zone 2A 11377' 8894' Zone 1B 11586' 8974' Formation at Total Depth (Name): 31. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing / iss true and and correct to the best of my knowledge. �J ( 1 Signed: Terrie Hubble � y `^'t' ( Title: Drilling Technologist Date: 09 / ` '( PBU 07 -13B 202 -116 311 - 120 Prepared ByNameMumber. Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Jacob Leemhuis, 564 -4989 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 - Altemating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50 -029- 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • 07 -13B, Well History (Pre Rig Sidetrack) Date Summary 5/27/11 T /I /0= 2280/180/50 MIT IA to 3000 psi PASSED. MIT OA to 2000 psi PASSED. MIT IA; Pumped 18.5 bbls 60 °F crude down IA to psi up to 3000 psi. MIT IA lost 77 psi in 1st 15 minutes and 29 psi in 2nd 15 minutes for a total loss of 107 psi in 30 minutes test. Bleed down IAP to 200 psi. RD off IA. RU to OA. OA lost 10 psi in first 15 minutes and 6 psi in second 15 minutes. Ran test additional 15 minutes. OA lost 0 psi in third 15 minutes. Bleed OA pressure down to 400 psi. FWHP= 2280/300/400. 5/27/11 T /I /O= 2250/290/0. Temp= SI. T,IA & OA FL (pre -CTD). AL spool disconnected. T FL @ 10408' (between sta # 3 & 4). LRS rigged up doing MITIA & OA.LRS in charged of valve positions. 5/30/11 CTU #9 1.75" Coiled Tubing - Job Scope = Whipstock Drift RIH w/ BOT 2.63" Dummy Whipstock drift, Tag 3 3/16 x 2 7/8" cross over in the liner at 11401' ctmd, pooh. Well freeze protected to 2500' MD wtih 50/50 methonal, RDMO. Job Complete. 6/3/11 T /I /0= 1100/280/370, Temp =Sl. PPPOT-T (FAIL), pre CTD. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS, one was tight but moving, the rest moved freely. Unable to pressure test void above 4000 psi, pressure decreased to 1000 ppsi in 4 min. Torqued LDS (600 lb/ft). Re- pressured test void, unable to pressure test void above 4000 psi, void bled to 1000 psi in 4 min (FAIL). Stung into lower port on TBG head to test between metal to metal seal and body seal (0 psi). Pressured void to 5000 psi, good test for 30 min. No change in test void during test. Bled lower test void to 0 psi. Pressured upper test void to 4000 psi, no change in body seal void, test void bled to 1000 psi. Bled void to 0 psi. 7/6/11 T /I /O= 1200/300/200 Conducted PJSM w /crew. Performed leak rate test on SSV- barrier (passed). PT (charted & saved) top side of Swab valve to 300 - psi /3500 psi (passed). PT (charted & saved) top side of SSV to 300 - psi /3500 psi (passed). Installed lubricator PT (charted) w /each break to 300 - psi /3500 -psi (passed). Note: cycled MV w /each set & pull. Set 5" Gray "K" BPV @ 108 ". Torqued all tree flange nuts to specification (see log) & bench - marked. Set 5" Gray test dart @ 84" w/1 -2' ext. PT (charted & saved) tree to 300 psi /4950 psi (passed). Pulled Companion valve & blinded, torqued to specification, PT (charted & saved) to 300 - psi /4950 -psi (passed). Pulled 5" Gray test dart. Pulled 5" Gray "K" BPV. Pre torque & test, Pre Nordic 2. 7/10/11 T /I /0= 460/500/220 (Load and Kill) Pumped 270 bbls 2 %KCL followed by 38 bbls diesel for freeze protect. Final WHP= 0/640/480. 7/13/11 T /I /O = VAC/340/25. Temp = SI. Bleed IA & OA to —0 psi (Pre CTD). AL spool, flowline & well house removed for rig. IA & OA FL near surface. Bled IAP from 340 psi to 0+ psi in 4 hrs (gas /fluid —2.5 bbls). Bled OAP from 25 psi to 0+ psi in 45 min (gas). Monitor 30 min. IAP increased to 10 psi, OAP unchanged. Final WHPs = VAC /10/0 +. Note: Pad Op opened SSV. Cycled MV to get TP. 7/13/11 T /I /O = NA/30/15. Temp = SI. Bleed IA & OA to 0 psi (Pre RWO). AL spool, flowline & well house removed for rig. IA & OA FL near surface. IAP increased 20 psi and OAP increased 15 psi since day shift. Bled OAP from 15 psi to 0+ psi in 1 hrs (gas returreturns). Bled IAP from 30 psi to 0+ psi in 1 hr (gas /fluid returns), maintained open bleed on IA & OA for 2 additional hrs. Monitored for 30 min. IAP increased to 2 psi, OAP increased to 5 psi. Job complete. Final WHPs = NA/2 /5. II Page 1 of 1 • . North America - ALASKA - BP Page 1 after Operation Summary Report Common Well Name: 07 -13 u AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/18/2011 I End Date: X3- 00YW1 -C X3- 00YW1 -C (2,150,300.00 ) Project: Prudhoe Bay Site: PB DS 07 Rig Name /No.: NORDIC 2 Spud Date/Time: 4/23/1979 12:00:OOAM Rig Release: 8/10/2011 Rig Contractor: NORDIC CALISTA UWI: 500292033800 Active Datum: 23 : 14 5/17/1979 00:00 @64.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/18/2011 16:00 - 18:30 2.50 MOB P PRE PREPARE RIG FOR MOVEMENT. PJSM ON RIG MOVE, EMPHASIS ON COMMUNICATION. MOVE OFF 5 -35, CLEAN SITE OVER WELL 1 WHEN RIG MOVED OFF. 18:30 - 19:00 0.50 MOB P PRE 1 PJSM ON RIG MOVE WITH NEW CREW, ASSIGN DUTIES, CONFIRM COMMUNICATION STRATEGIES. 19:00 - 00:00 5.00 MOB P PRE MOVE RIG FROM DS 5 TO DS 7 7/19/2011 00:00 - 00:30 0.50 MOB P PRE MOVE RIG FROM DS 5 TO DS 7. POSITION RIG AT ENTRANCE TO PAD. 00:30 - 02:45 2.25 MOB P PRE 1 WAIT ON RIG MATS TO BE BROUGHT OVER AND PLACED. PJSM ON COMPLETING MOVE. 02:45 - 03:15 0.50 MOB P PRE MOVE RIG FROM PAD ENTRANCE TO FRONT OF WELL 7 -13. 03:15 - 06:00 2.75 MOB P PRE VERIFY VALVE CLOSURE, IA AND OA PRESSURES AT 0 PSI, BPV INSTALLED. POSITION RIG MATS AROUND TREE. PREP CELLAR AREA WITH HERCULITE. POSITION RIG TO MOVE OVER WELL. MOVE OVER WELL. RIG ACCEPT 0600 HRS. STATE NOTIFIED OF UPCOMING BOP TEST AT 0600 —!I P HRS. 06:00 10:30 4.50 MOB PRE CONTINUE TO SPOT RIG EQUIPMENT - CUTTINGS BOX, SPOC SHACK. WELLS SUPPORT RU TIGER TANK & HARDLINE. TEST HARDLINE TO 4000 -PSI. RIG CAMP ARRIVES ON DS 7. 10:30 - 11:00 0.50 MOB P PRE HOLD RIG EVAC DRILL AND AAR. ALL CREW MEMBERS RESPONDED CORRECTLY AND IN 1 -MIN 23 -SEC. NEW SIREN ON REEL HOUSE HELPS EVERYONE HEAR THE ALARM CLEARLY. REITERATED THE IMPORTANCE OF MAINTAINING A SIGN IN SHEET AT EACH MUSTER AREA. FUNCTION TEST ESD - FUNCTIONED PROPERLY. 11:00 - 12:00 1.00 MOB P PRE PU REEL OF 2" COIL OFF OF REEL TRAILER AND INSTALL IN REEL HOUSE. 12:00 - 14:00 2.00 MOB P PRE ND TREE CAP. BRING ON ONE 290 -BBL LOAD OF 8.5 -PPG 2% KCL TO PITS. 14:00 - 15:30 1.50 BOPSUR P PRE NU BOP STACK & LUBRICATOR RISER_. USE HYDRATIGHT TORQUE WRENCH WHERE ABLE WITH API VALVE SHOP FOREMAN GIVING OPERATIONAL INSTRUCTION TO RIG CREW. N. SLB MU ALL INNER REEL IRON. AOGCC REP MATT HERRERA WAIVED STATE'S RIGHT TO WITNESS THE INITIAL BOPE TEST AT 1430 -HRS ON 7/19/11. 15:30 - 22:00 6.50 MOB P PRE 1 MU PACKOFF TO RISER. MU INJECTOR TO PACKOFF. MU GOOSENECK TO INJECTOR HEAD. INSTALL GRAPPLE INTO COIL. 22:00 - 23:00 j 1.00 MOB P PRE PULL COIL ACROSS TO INJECTOR HEAD. 123:00 00:00 1.00 I MOB P PRE j CUT OFF GRAPPLE. REBOOT E -LINE. INSTALL GUARD OVER CONTROL LINE PORT 1 Printed 9/6/2011 9:09:07AM orth America - ALASKA - BP ' Aft Page 2 OM peration Summary Report Common Well Name: 07 -13 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/18/2011 End Date: X3- 00YW1 -C X3- 00YW1 -C (2,150,300.00 ) Project: Prudhoe Bay Site: PB DS 07 Rig Name /No.: NORDIC 2 Spud Date/Time: 4/23/1979 12:00:OOAM Rig Release: 8/10/2011 Rig Contractor: NORDIC CALISTA UWI: 500292033800 Active Datum: 23 : 14 5/17/1979 00:00 @64.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 7/20/2011 00:00 - 01:00 1.00 MOB P PRE I DSM GREASE CREW LEAD ON LOCATION GIVING HYDRATIGHT OPERATION INSTRUCTION TO RIG CREW. SLB FINISH BOOTING E -LINE. 01:00 - 01 :30 0.50 MOB P PRE CLEAN AND DRESS SHAKERS. 01:30 - 03:15 1.75 MOB P PRE MU BALL DROP VALVES IN REEL. STAB INJECTOR ON WELL AND FILL COIL AT 1.42 -BPM. ESTABLISH 1 FOR 1 RETURNS. 03:15 - 04:00 0.75 MOB P PRE SHUT DOWN PUMPS AND LINE UP TO I REVERSE CIRCULATE. PUMP SLACK BACK IN TO COIL. CIRCULATE AT 2 -BPM WITH 3500 -PSI. HEAR E -LINE MOVING. ONCE MOVEMENT STOPS, BLOW AIR BACK THROUGH COIL TO HELP DRY COIL FOR CUTTING. 04 :00 - 06:30 2.50 MOB P PRE POP OF WELL. RU CT CUTTER ON BOTTOM OF INJECTOR. CUT 234' OF COIL. RD CT CUTTER. PUMP SLACK FORWARD UNTIL E -LINE SEEN. BHI TEST CONDUCTIVITY - GOOD. INSTALL SLB CTC. 06:30 - 16:00 9.50 BOPSUR P PRE START BOP TEST. TEST WITNESS WAS WAIVED BY AOGCC INSPECTOR MATT fS HERRERA. TEST CHOKE VALVES, ANNULAR, UPPER ' AND LOWER 2" PIPE/SLIP RAMS, 2 -3/8" PIPE/SLIP RAMS, BLIND SHEAR RAMS, TIW VALVE, INNER REEL VALVE AND CT PACKOFF. NO TEST FAILURES. 16:00 16:30 0.50 MOB P PRE I MOVE INJECTOR OVER TO CIRC: HOLE AND PUMP FRESH WATER OUT. PJSM WITH BPV CREW FOR LOADING BPV ! LUBRICATOR ONTO RIG. 16:30 - 19:15 2.75 ZONISO P WEXIT LOAD DSM LUBRICATOR ONTO RIG AND PRESSURE TEST TO 250 -PSI / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. DISCUSS POTENTIAL OF NEEDING MORE THAN ONE OA BLEED DURING WELL KILL OPS BASED ON PRE RIG L &K (2 OA BLEEDS REQUIRED) WITH CTD WTL. APPROVED MORE THAN ONE BLEED AS LONG AS NO OTHER INTEGRITY ISSUES INDICATED. 19:15 - 19:30 0.25 ZONISO P WEXIT HOLD RIG EVAC DRILL WITH MEINHOLD CREW. ALL CREW MEMBERS AND ADDITIONAL PERSONNEL ON LOCATION RESPONDED TO THE PRIMARY MUSTER AREA BASED ON WIND DIRECTION. NO ISSUES WERE NOTED IN AAR. 19:30 - 20:00 0.50 ZONISO P WEXIT OPEN SSV AND MASTER VALVE. LUBRICATE OUT BPV. WELL ON VAC. CLOSE MASTER & SSV. LD LUBRICATOR AND BPV. CLOSE SWAB VALVE & OPEN SSV. - Printed 9/6/2011 9:09:07AM B orth America - ALASKA - BP Page 3 aft= Operation Summary Report Common Well Name: 07 -13 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/18/2011 End Date: X3- 00YW1 -C X3- 00YW1 -C (2,150,300.00 ) Project: Prudhoe Bay Site: PB DS 07 Rig Name /No.: NORDIC 2 I Spud Date/Time: 4/23/1979 12:00:OOAM Rig Release: 8/10/2011 Rig Contractor: NORDIC CALISTA UWI: 500292033800 Active Datum: 23:14 5/17/1979 00:00 @64.00ft (above Mean Sea Level) Date From - To 1 Hrs I Task Code NPT NPT Depth Phase Description of Operations K P (hr) (ft) 20:00 - 21:00 1.00 ' 1 1 WEXIT ',FINISH BRINGING ON 8.5 -PPG 2% KCL TO 1 PITS. RU BLEED TRAILER IN PREP OF BLEEDING IA &/OR OA DURING BULLHEAD OPS. INSTALL FUSIBLE CAP ON SSV. HOLD PJSM ON WELL KILL OPERATIONS. DISCUSS BULLHEAD PARAMETERS (RATE, PSI, VOLUME), BLEEDING ANNULI CRITERIA, POSITIONS OF PEOPLE AND THE IMPORTANCE OF COMMUNICATION IA / OA / PVT = 115 -PSI / 40 -PSI / 457 -BBLS. 21:00 - 22:15 1.25 KILLW P i WEXIT OPEN MASTER & SWAB. LINE UP AND BULLHEAD 5 -BBLS MEOH AT 1 1 -BPM. i I FOLLOW WITH 8.5 -PPG 2% KCL. 1 STAGE UP TO RATE OF 5 -BPM AND ZERO i !VOLUME PUMPED. ' ICP AT 5 -BPM = 500 -PSI. SEE PRESSURE FLUCTUATION INDICATIVE OF DIFFERENT DENSITY FLUIDS ENTERING FORMATION (DIESEL FP, MEOH). CONTINUE TO BULLHEAD AT 5 -BPM. FCP AT 5 -BPM = 2626 -PSI 1 1 IA / OA = 95 -PSI / 81 -PSI. T 22:15 - 23:00 0.75 KILLW P T 1 WEXIT FLOW CHECK WELL - ON A VAC. CIRCULATE ACROSS THE TOP OF THE WELL MONITORING LOSS RATE. ' 10- MINUTE LOSS RATE = 37 -BPH. ESTABLISH CONTINUOUS HOLE FILL. IA / OA = 100 -PSI / 131 -PSI 23:00 - 00:00 1.00 WHIP P WEXIT I PU INJECTOR AND INSTALL CHECKS INTO BHI UQC. j BEGIN TESTING CHECKS TO 250 -PSI / 3500 -PSI. HOLD AND CHART EACH TEST FOR 5- MINUTES. MAINTAIN CONTINUOUS HOLE FILL WITH LOSS RATE = 31-BPI-I. { ' IA / OA = 103 -PSI / 178 -PSI. 7/21/2011 00:00 - 00:30 0.50 WHIP P I WEXIT CONTINUE TO TEST BHI DBPV TO 250 -PSI / 3500 -PSI. 1 I HOLD AND CHART EACH TEST FOR I 1 5- MINUTES. ' ' GOOD TESTS. RD TEST EQUIPMENT. . LOSS RATE = 31 -BPH. 00:30 01:30 1.00 WHIP P WEXIT TROUBLESHOOT BAKER CHOKE. 1 INDICATOR KNOB AND SHAFT WERE JAMMED TOGETHER, KEEPING THE ' i INDICATOR FROM TURNING PROPERLY. ADJUST COVER AND FUNCTION TEST - ' GOOD. IA / OA = 104 -PSI / 214 -PSI. 01:30 02:15 I 0.75 I WHIP P WEXIT HOLD PJSM WITH RIG CREW, BHI, BTTAND SLB ON MU WHIPSTOCK SETTING BHA. l i MU WHIPSTOCK SETTING BHA. BHA CONSISTS OF: WHIPSTOCK, SETTING I SLEEVE, HYD SETTING TOOL, HOT, DGS, DPS, EDC, P &C, LQC, UQC AND CTC. OAL = 67.03'. I MAINTAIN CONTINUOUS HOLE FILL. Printed 9/6/2011 9:09:07AM orth America - ALASKA - BP Page 4 peration Summary Report Common Well Name: 07 -13 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 7/18/2011 End Date: X3- 00YW1 -C 1 X3- 00YW1 -C (2,150,300.00 ) Project: Prudhoe Bay Site: PB DS 07 Rig Name /No.: NORDIC 2 Spud Date/Time: 4/23/1979 12:00:OOAM Rig Release: 8/10/2011 Rig Contractor: NORDIC CALISTA I UWI 500292033800 Active Datum: 23:14 5/17/1979 00:00 @64.00ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:15 - 02:30 0.25 WHIP P WEXIT MU STRING TO COIL. STAB INJECTOR ONTO WELL. 02:30 - 05:30 3.00 WHIP P WEXIT OPEN EDC AND ESTABLISH CIRCULATION DOWN COIL AT .47 -BPM. I RIH TO 200' BUT NOT ABLE TO ESTABLISH � RETURNS. LINE UP TO CIRCULATE DOWN COIL AND FILL DOWN THE BACKSIDE AT THE SAME TIME. RIH AT 65 -FPM, SLOWING THROUGH TUBING JEWELRY. CIRCULATE AT .45 -BPM DOWN COIL AND .60 -BPM DOWN BACKSIDE. LOSS RATE = 30 -BPH. IA / OA = 105 -PSI / 240 -PSI. 05:30 - 07:00 1.50 WHIP P WEXIT CONTINUE RIH. START LOGGING TO TOP SAG RIVER AT 10700 FT. 07:00 - 10:00 3.00 WHIP N ! DFAL WEXIT POOH FOR NBI SENSOR FAILURE. 1 WHILE POOH, PJSM FOR UD AND CHANGE OUT FAILED BHA COMPONENT. 10:00 - 11:10 1.17 WHIP N DFAL 1 WEXIT TAG STRIPPER AND FLOWCHECK WELL FOR 10 MIN. FILL WELL WITH 2.4 BBLS THEN OPEN CT RISER, STAND INJECTOR BACK IN CIRC HOLE. UD BHA AND SWAP OUT HOT. INSPECT PACKER AND SLIP ELEMENT AT SURFACE, LOOKS FINE. M/U BHA #2 - WHIPSTOCK PACKER, 2.375" COILTRAK. BHA OAL = 67.03 FT. 11:10 - 14:10 3.00 WHIP N DFAL WEXIT RIH BHA #2. PUMP DOWN CT AND ACROSS CT X TBG ANNULUS WHILE RIH TO KEEP 1 WELL FULL. 14:10 - 16:00 1.83 WHIP P WEXIT LOG GR DOWN FROM 10700 FT TO CAPTURE TOP SAG RIVER. CORRECT -35 FT. LOG 25N SHALE AT 11258 FT, CORRECT -1 FT. 16:00 - 16:15 0.25 WHIP P WEXIT j LOG CCL UP FROM 11360 FT, COLLARS ON j MWD LOG MATCH LOCATION ON PDC LOG. 16:15 - 16:30 0.25 WHIP P WEXIT RUN TO 11366 FT AND PICK BACKUP TO SETTING DEPTH. PICK UP TO 11357.2 FT WHICH PLACES THE TOP WHIPSTOCK AT 11348 FT. 5 FT BELOW THE NEAREST COLLAR. CLOSE EDC. ZERO DWOB. CONTINUE FILLING THE CT X TBG ANNULUS. 1 PRESSURE UP CT TO 2800 PSI AND SHEAR OUT SETTING TOOL. SET 2.49K DWOB DOWN TO CONFIRM SET. 16:30 - 19:30 ! 3.00 WHIP P WEXIT PICK UP 50 FT AND PT WELLBORE TO 1000 PSI FOR 15 MIN, GOOD. GET SLOW PUMP PRESSURES THEN POOH. j IA / OA = 125-PSI/ 280 -PSI. 19:30 - 20:15 0.75 WHIP P WEXIT BUMP UP IN PACKOFF. FLOW CHECK - NO FLOW. LD WHIPSTOCK RUNNING BHA. NO ISSUES NOTED WITH SETTING TOOLS. IA / OA / PVT = 130 -PSI / 280 -PSI / 340 -BBLS. Printed 9/6/2011 9:09:07AM Page 5 cz Orth America - . ALASKA - BP peration Summary Report Common Well Name: 07 -13 AFE No Event Type: RE- ENTER- ONSHORE (RON) ' Start Date: 7/18/2011 End Date: X3- 00YW1 -C X3- 00YW1 -C (2,150,300.00 ) Project: Prudhoe Bay Site: PB DS 07 Rig Name /No.: NORDIC 2 Spud Date/Time: 4/23/1979 12:00:OOAM l Rig Release: 8/10/2011 Rig Contractor: NORDIC CALISTA UWI: 500292033800 Active Datum: 23 : 14 5/17/1979 00:00 @64.00ft (above Mean Sea Level) Date ! From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:15 - 20:30 0.25 STWHIP P WEXIT BHI RECONFIGURE TOOL STRING FOR MILLING WINDOW. 20:30 - 21:00 0.50 STWHIP P WEXIT HOLD PJSM WITH RIG CREW, SLB, BTT, AND BHI. DISCUSS WELL CONTROL CONSIDERATIONS, POSITIONS OF PEOPLE AND BHA RUNNING ORDER. MU WINDOW MILLING BHA. BHA CONSISTS OF HCC DSM WINDOW MILL, DSM, 2 -1/8" EXTREME MOTOR, XO, 2 -JTS OF 2- 1/16" CSH, XO, BLIND SUB, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, CTC. OAL = 108.94 ' 21:00 - 21:30 0.50 STWHIP P WEXIT MI1 BHA TO COIL. STAB ON INJECTOR. OPEN EDC AND BREAK CIRCULATION AT .5 -BPM. IA / OA / PVT = 128 -PSI / 253 -PSI / 341 -BBLS. 21:30 - 23:45 2.25 STWHIP P BH WEXIT i RIH WITH WINDOW MILLING BHA AT 75 TO 100 -FPM, SLOWING THROUGH ALL PRODUCTION JEWELRY. CIRCULATE THROUGH OPEN EDC AT .5 -BPM WITH 260 -PSI. 23:45 - 00:00 0.25 STWHIP P WEXIT LOG TIE IN ACROSS TSGR FROM 10,890' TO 10901'. T APPLY -33.5' CORRECTION. 7/22/2011 00:00 - 01:30 1.50 STWHIP P WEXIT CONTINUE TO RIH FROM 10901' SLOWLY. DISPLACE WELL TO 8.6 -PPG POWERPRO MUD AT 2.03 -BPM WITH 3050 -PSI. IA / OA = 178 -PSI / 305 -PSI. 01:30 - 02:00 0.50 STWHIP P WEXIT FILL PITS WITH 8.6 -PPG POWERPRO MUD. CONTINUE CIRCULATING AT 1.47 -BPM WITH 2330 -PSI. CLOSE EDC. OBTAIN SPRS. PUMP #1 - .5 -BPM / 1.5 -BPM WITH 1520 / 2770 -PSI. PUMP #2 - .5 -BPM / 1.5 -BPM WITH 1560 -PSI / 2810 -PSI. 02:00 - 02:30 0.50 STWHIP P WEXIT IRIH, CIRCULATING AT .2 -BPM WITH 1230 -PSI TO TAG TOP OF WHIPSTOCK AT 11350'. PU OFF OF WHIPSTOCK WITH PU WT = 34.5K -LBS. BRING PUMP UP TO 1.6 -BPM WITH 2675 -PSI = �' A " FREE SPIN. WASH DOWN SLOWLY AND SEE MOTOR ' WORK START AT 11,350.5'. c l 02:30 - 07:00 4.50 STWHIP P WEXIT TIME MILL FROM 11,350.5' AT 1 -FPH. CR TUBING CAUSING SLOW WEIGHT TRANSFER. AT 11,351' - MILLING WITH 200 -PSI MOTOR WORK AND 1.2K -LBS DHWOB. AT 11,351.5' - MILLING WITH 300 -PSI MOTOR WORK AND 1.9K -LBS DHWOB. AT 11,352' - MILLING WITH 300 -PSI MOTOR WORK AND 2.1 K -LBS DHWOB. AT 11,352.5' - MILLING WITH 200 -PSI MOTOR WORK AND 1.6K -LBS DHWOB. I 1 AT 11,353' - MILLING WITH 100 -PSI MOTOR WORK AND 1 K -LBS DHWOB. AT 11,353.5' - MILLING WITH 70 -PSI MOTOR WORK AND 1.1K-LBS DHWOB. Printed 9/6/2011 9:09:07AM TREE = GRAY GEN 2 SAFETY NO WELL ANGLE> 70 @ 11 501' * ** 4 -1/21" WELLHEAD = GRAY ACTUATOR = AXELSON PJC D RAF* 07-1 CHROME T PROD MANDRELS & NIPPLE @ 11282, 3 C MILLED TO 3.80" (05/20/02) * ** ORIGINAL, "A" AND "B" KB. ELEV = 64' I WELLBORES NOT SHOWN * ** BF. ELEV = 27.5' KOP = 2190' 20" CONDUCTOR, 108' I I 1 2059' - 4 -1/2" CA TRDP -4A SSSV NIP, ID = 3.812" Max Angle =96° @ 1 94 # H -40, LOCKED OUT (05/20/02) Datum MD = 11309' ID = 19.124" x 2313' H7-5/8" CPH LNR TOP PKR, ID = 6.875" 1 Datum TVD = 8800' SS ifil, 9 -5/8" CSG, 47 #, S00.95 X0 TO L -80 BTC H 2327' 2349' 11 9 -5/8" UPPER FOC 2473' �--� 9-5/8" LOWER FOC I 7 -5/8" SCAB LNR, 29.7 #, -1 2516 L -80 STL, ID = 6.875" 2510' H7-5/8" HY -FLOW ED HGR/ PKR , ID = 6.75" 1 MIP GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80 BTC, ID = 12.347" 11 2760' ST MD TVO DEV TYPE VLV LATCH PORT DATE 9 -5/8" X 7" BKR TYPE "H" PKR, HMC HGR H 9796' I 1 4487 4088 46 KBMG DMY RK 0 01/28/11 2 7665 6146 51 KBMG DMY BK -5 0 01/28/11 & TIE -BACK SLV, ID = 6.188" 4 3 9719 7613 36 KBMG DMY BK -5 0 07/12/02 4 19 -5/8" CSG, 47 #, L -80 BTC, ID =- 8.681" 1-1 -10005 9 -5/8" MILLOUT WINDOW (07 -13A) 10005' - 10055' I Minimum ID = 1.78" @ 11030' I r----1 10983' CTD MD 1 -14 -1/2" OTIS X NIP, ID = 3.813" 1 MILLED OUT BUSHING IN 3" DEPLOY SLV 10983' -1 BKR 45 KB PKR, ID = 2.370" 1 4 -1/2" TBG, 12.6 #, L -80 NSCT -1 10994' 1 x XO TO 13CR -80 NSCT L 11003' -15-3/4" BKR PBR/ SEAL ASSY, ID = 3.875" BEHIND LNR 11029' H 3.70" DEPLOY SLV w / LOC SEAL ASSY, ID = 2.360" I $ II _ 11030' - 13" BKR DEPLOY SLV, ID = 1.780" 11, j� 11034' -17" X 4 -1/2" BKR S -3 PKR, ID = 3.83 1 � � 11085' - 13 -112" BKR DEPLOY SLV, ID = 3.00" I BEHIND 11094' H3-1/2" HES XN NIP, ID = 2.75" 1 CT LNR 11096' 1-13-1/2" X 3- 3/16" XO, ID = 2.786" 1 ■ • L PRODUCTION MANDRELS \ ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 -1/2" TBG, 12.6 #, 13CR -80 NSCT H 11287' 4 11173 8751 41 KBG-2-LS *EMPTY BK -5 F 06/16/02 5 11199 8775 41 KBG -2 -LS *EMPTY BK -5 04/28/95 .0152 bpf, ID = 3.958" _ , • * MANDRELS MILLED TO 3.80" (06/25/02) / BEHIND 3- 3/16" LNR 3- 3/16" WHIPSTOCK (07/21/11) H 11350' 11265' I- BKR KBH -22 ANCHOR BEHIND 1 = I� .. ■ � � 11282' 4 - 112 CAMCO DB NIP, TO 3.80" 0" 06!25/0 NR 3 3/16' LNR, 6.2 #, L -80 TC11, .0076 bpf, ID = 2.80" 11351 L NR, 29 #, L -80 NSCC, 0371 bpf, ID = 6. ( ^ -1135 1� ( ) ,.\.._...,___. 11287 1-14 112" WLEG, ID = 3.958" 1 " PERFORATION SUMMARY g REF LOG: SWS MEM CNL/ GR/CCL ON 08/06/11 " j�-t3$ 3- 3/16" MILLOUT WINDOW (07 -IBA) 11351' - 11356" ANGLE AT TOP PERF: 88° @ 13000' 1 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 1.56" 6 1300 -13070 0 08/08/11 1.56" 6 13220 - 13350 0 08/08/11 1.56" 6 13980 - 14110 0 08/08/11 I 1 PBTD H 14123' 1 12 -3/8" LNR, 4.6 #, L -80 STL, .0039 bpf, ID = 1.995" H 14132' 1 AA 7- 13G DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05/16/79 ROWAN 34ORIGINAL COMPLETION WELL: 07 -13C 09/27/94 N2ES SIDETRACK (07 -13A) PERMIT No: '2110540 07/09/02 NORDIC 1 CTD SIDETRACK (07 -13B) API No: 50- 029 - 20338 -03 08/10/11 NORDIC 2 CTD SIDETRACK (07 -13C) SEC 33, T11 N, R14E, 299' FEL & 630' FNL 08/14/11 PJC DRLG HO CORRECTIONS 08/20/11 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • • Sliffl I NLASEA / SEANPARNELL , GOVERNOR m ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. a© a _ ( 1 P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 07 -13B Sundry Number: 311 -120 5 ,e6e 3 NN APR 1. 5 ZU) 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 holida • weekend. Si o ► • o .s , er DATED this l* day of April, 2011. Encl. �I ALASKA AND GAS T CONSERVATION COMMIS E V T ®A� APPLICATION FOR SUNDRY APPROVAL 4i3 20 AAC 25.280 • 1. Type of Request: �ska 00 & bag Lens. (�,�4 rnmi se i ❑ Abandon - ® Plug for Redrill . ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved PrqktroVororage ❑ 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. -18:1 Development ❑ Exploratory 202 - 116- 3. Address: ❑ Service ❑ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 029 - 20338 - 02 - 00 - 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number. property line where ownership or landownership changes: PBU 07 -13B Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028309 - 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): 12960' - 8975' 12928' - 8979' 12065' None Casing Length Size MD TVD Burst Collapse Structural Conductor 108' 20" 108' 108' 1530 520 Surface 2760' 13 -3/8" 2760' 2728' 4930 2670 Intermediate 10005' 9-5/8" 10005' 7840' 6870 4760 Production Liner 204' 7 - 5/8" 2312' - 2516' 2309' - 2504' Liner 1568' 7" 9796' - 11364' 7675' - 8887' 6890 4790 Liner 1875' 3 - 3/16" x 2 - 7/8" 11085' - 12960' 8685' - 8975' 13450 13890 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11675' - 12051' 8992' - 8997' 4 - 1/2 ", 12.6# 13Cr - 80 11287' Packers and SSSV Type: 7" x 4-1/2" Baker SABL -3 Packer Packers and SSSV 11034' MD / 8646' TVD 7" x 4-1/2" Baker SABL -3 Packer MD (ft) and TVD (ft): 11267' MD / 8822' TVD 12. Attachments: 13. Well Class after proposed work: 0 : Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: April 21, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINS ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG -181 Suspended 17. I hereby certify that le foregoing is true and correct to the best of my knowledge. Contact Jacob Leemhuis, 564 -4989 Printed Name ,(h .►u I; , Title Engineering Team Leader Prepared By Name/Number Signat, '� t - / ._. - Phone 564 -4711 Date F I f I Elizabeth Barker, 564-5674 / Commission Use Only Cond ions of approval: Notify Commission so that a representative may witness 1 Sundry Number 3 ' \ `a c) ❑ Plug Integrity OrBOP Test ❑ Mechanical Integrity Test ❑ Location Clearance i ke 35 f s,..., j30r s4— Other. i4 Zs r5c. Aft.....-1 r e_5- � rw. - s .) Subsequent Form Required: /6 -- q a A f APPROVED BY / 1 4141/ // Approved By: / I COMMISSIONER THE COMMISSION Date Form 10-403 Revis OS / A ' I . / , Submit In Duplicate I l k -- ' Ps. IP - , R N A L , f./z/a • • To: Alaska Oil & Gas Conservation Commission From: Jacob Leemhuis biD CTD Engineer Date: March 15, 2011 Re: 07 -13B Sundry Approval Sundry approval is requested for well 07 -13B. Well 07 -13B is a horizontal coil sidetrack drilled in June 2002 targeting Zone 1B sands. HOT was not tagged but is believed to be 5 -10' below the well. There was 640' of Zone 1B initially perforated. Within 3 months, the oil rate fell and the GOR reached marginal GOR. A Borax/MCNL/STP was run in Jan 2003 to identify the gas source. The borax pass showed no channels, and the liner lap was not leaking. The well continued to cycle for the next 4 years with degrading ontime. A CIBP was set at 12065' CTMD on 3/13/07 for a GSO. An additional 85' of Zone 1B perforations were added in April 2009, but the well reached MGOR within 2 months. Based on the 2003 GOC and the very short rate buzz from the 2009 additional perforations, uphole lenses were not pursued. REASON FOR SIDETRACK Well 07 -13B is no longer a competitive producer, and there are no remaining well work options. The proposed plan for 07 -13C is to drill a through tubing sidetrack with the SLB /Nordic 1 Coiled Tubing Drilling rig on or around June 10,2011. The existing perforations will be isolated by a packer whipstock, as well as the primary cement job. The sidetrack, 07 -13C, will exit the existing 2 -3/8" liner and kick off in the Ivishak and 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 Summary: (scheduled to begin April 21, 2011) 1. 0 MIT -IA to 3000 psi; MIT -OA to 2000 psi. • 2. C Dummy Baker 3- 3/16" PackerWS drift • 3. W Test: PPPOT -T. Torque LDS • 4. V PT MV, SV, WV 5. 0 Blind and bleed lines, remove well house, level pad ' 6. F Load & Kill well. Freeze protect to 2,000' TVD. 7. V Set BPV —24 hrs prior to rig arrival • Co'C . Ifr— a too& 04 1, /f O,er 41' .‘e 000 5G'cV T6 A 4 ‘40..) vCi� , Tn. itC44 -5. 4 4e* iliut 1'1 • KU' $4).1' h/T egA Rig Work: (scheduled to begin on June 10, 2011) c./1310 ��� 1. MIRU and test BOPE to 250 psi low and 3500 psi high. 2. Mill 2.74" window at 11,390' and 10' of rathole. Swap the well to Quickdrill. 3. Drill Build: 3" OH, 400' (35 deg /100 planned) 4. Drill Lateral: 3" OH, 2,382' (4 deg /100 planned) with resistivity 5. Run 2 -3/8 solid liner leaving TOL at 11,010' 14o� 6. Pump primary cement leaving TOC at 11,010', 11.5 bbls of 15.8 ppg liner cmt planned . 7. Cleanout liner and MCNUGR/CCL log 8. Test liner lap to 2000 psi. 9. Perforate liner per asset instructions ( -600') 10. Freeze protect well, RDMO Post Rig: 1. Re- install well house and attach production lines 2. Pull BPV 3. Run generic GLV as needed 4. Test separator ( -600' of perforations) Jacob Leemhuis CTD Engineer 564 -4989 CC: Well File Sondra Stewman/Terrie Hubble - REE = IAY GEN 2 RELHEAD = GRAY • 07-1 3 B SAFETY NO PROD. MANDRELS AND 4 -1/2" NIPPLE 4CTUATOR AXELSON 11282 MILL O 3.80 ". 4 -1/2" CHROME TBG. TRDP -4A (B. ELEV = 52.3' SSSV LOCKED OUT. 40, ELEV = --- 27. , (OP = 2190' - 2059' H4 - 1/2" CAMCO TRDP - 4A SSSV NIP, ID = 3.812" 1 4/lax Angle 12897' 1TOP OF 7 -5/8" LNR 1 2312' 4 )u m t M) 11309' ' � I 2312' H H 7 -5/8 - 5/8 " " CPH LNR PKR, ID = 6.875" = ' 6 .75" Datum TVD = 8800' SS HY - FLO 3D HGR/PKR, 10 7 -5/8" LNR -SCAB, 47 #, L -80, —1 2516' .0459 bpf, ID = 6.875" 1 13 -3/8" CSG, 72#, L -80, ID = 12.347" H 2760' 1 GAS LIFT MANDRELS ST MO TVD DEV TYPE VLV LATCH FORT DATE 1 4487 4088 46 KBMG -M DMY BK 0 01/28/11 'TOP OF 7" LNR H 9796' 2 7665 6146 51 KBMG -M DMY BK 0 01/28/11 3 9719 7613 36 KBMG -M DMY BK -5 0 1TOP OF CEMENT 1-1 9798' V PRODUCTION MANDRELS V , ST ND ND DEV TYPE VLV LATCH FORT DATE 9 -5/8 CSG, 47 #, L -80, ID = 8.681" 1 10005' 1.1 ∎• •4 11173 8752 41 KBMG -M EMPTY BEK -3 06/16/02 � 4. �4 '5 11199 8772 41 KBMG -M EMPTY _ BEK -3 04/28/95 1 v *MANDRELS MILLED TO 3.80" (06125/02) (BEHIND 3 -3116" LNR) 14 1 1� 1ELSV H 10210' 1 10983' H 4-1/2" OTIS X NIP, ID = 3.813" 1 Minimum ID = 2.440" @ 11405' �� 11034' H 7" X 4 -1/2" BAKER SABL -3 PKR, ID = 3.83" 1 ,. 1 14 4 11085' H3.1/2" BKR DEPLOY SLV, ID = 3.000" 3- 3/16" X 2 -7/8" XO 0 tei / V 4 11094' H 3 - 1/2" HES XN NIP, ID = 2.75" 1 r J %. ■ 11096' H 3 X 3 - 3/16" XO, ID = 2.880" 1 '44. 4' •� m14 11216' H 4 -1/2" BLAST RINGS (38.83') 1 MILLOUT WINDOW 11364' - 11371' \ � � 1 � m .. 11267' 7" X 4 - 1/2" BAKER SA BL PKR, ' 1 . ' � t 4 ID = 3,83 4 � , 11282' 4 -1/2" CAMCO DB NIP, ID = 3.80" 1 4-1/2" TBG, 12.6#, 13- CR -80, ,0152 bpf, ID = 3.958" H 11287' ` (MILLED TO 3.80" 06/25/02) 11287' --1 4 -1/2" WLEG ( 17" X 4-1/2' WHIPSTOCK 1 11360' 1 11405' H3-3/16" X 2 - 7/8" X0, ID = 2.440" I PERFOr MSUMM6184, L -80, .0076 tpf, ID = 2.80" H 11405' 1 REF LOG: SWS MEMORY CNL/GR/CCL 07/07/02 1 12065' CTM 112-7/8" BKR ClBP ANGLEAT TOP PERF: 82 11675' l** SET (03/13/07) Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sgz DATE 2' 6 11675 - 11695 0 04/15/09' , ��4:444444144 4 ` 2" 6 11810 -11875 0 04/14/09 tj 4 �� illop 2" 4 11947 - 12051 0 07/08/02 4�44 4 ` =. 2" 4 12100 - 12230 C 07/08/02 4P44� '. 2" 4 12255 - 12371 C 07/08/02 ' 4 4 ( 12928 1 Pero 2" 4 12610 - 12695 C 07/08/02 *444 �' 2" 4 12750 - 12805 C 07/08/02 2' 4 12875 - 12925 C 07/08/02 12 -7,8" LNR, 6.16 #, L -80, .0055 bpf, ID = 2.441" H 12960' 1 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05113/79 ORIGINAL COMPLETION 04/13/07 CJN/PAG GLV C/O WELL: 07 -13B 09/27194 SIDETRACK (07 -13A) 04/16/07 RDW/TLH WAVER SET( NOTE DELETED PERMIT No: '2021160 07/09/02 DAVIKK GTO SIDETRACK (07 -13B) 05/31/09 ACB/TLH PERFS (04/15/09) AIR No: 50 -029- 20338 -02 11/06/02 ADK/TP PERF CORRECTION 02/13/11 JLJ /AGR GLV C/O (01/28/11) SEC 33, T11 N, R14E, 4651' FEL & 290' FNL 05/30/06 DTM WELLHEAD CORRECTIONS 03/13/07 CJA /PAG SET CIBP @ 12065' CTM) BP Exploration (Alaska) • MB-LHEAD = LAY GRAY 0 7 -13 C SAFETY NO. PROD. MANDRELS AND 4-12" /APPLE ACTUATOR = AXE-SON 11282' MILLED TO 3.80 ". 4- 112" CHROME TBG. TRDP -4A ®_ ELE-V= 523' Proposed C TD S iletack SSSV LOCKED OUT. 3F. ELEV = 27.5' .. - :OP= 2190' --1 2059' H4 -112" CAMCO TRDP -4A SSSV NP, ID = 3.812" Mlax Angle = ' @ 12897' ITOP OF 7 -5/8" LNR I 2312' Jatum MD = 11309' ® I::T 2312' H 7 -5/8" CPH LNR PKR, D = 6.875" rum 1VD = 8800SS 2516' H7-5/8" HY -FLO 3D HGR/PKR, D = 6.75" I 7-5/8" LNR-SCAB, 47 #, L-80, 2516' .0459 bpf, ID = 6.875" 1 13 -3/8" CSG, 72#, L -80, ID = 12.347" H 2760' I ■ GAS LIFT MANDRELS ST ND TVD DEV TYPE VLV LATCH PORT DATE 1 4487 4088 46 KBMG-M DMY BK 0 01/28/11 2 7685 6146 51 KBMG-M DMY BK 0 01/28/11 ITOP OF 7" LNR H 97 98' 3 9719 7613 36 KBMG -M DMY BK-5 0 • (TOP OF CEMENT H 9798' V N PRODUCTION MANDRELS 11 • • ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 9-5/8" CSG, 47 #, L -80, ID = 8.681" H 10005' I 4 ' "4 11173 8752 41 KBMG -M EMPTY BEK-3 3 06/16/02 ' 4, ` 4 *5 11199 8772 41 KBMG-M EMPTY BEK-3 04/28195 1 ∎ ■ 'MANDRELS MILLED TO 3.80" (06125/02) (BEHIND 3 -3116" LNR) T S G R 10,693' � 11 1.1.14. EZ SV 10210' 1 = 10983' H 4 -112" OTIS X NIP, ID = 3.813" I Minimum ID = 2.440" @ 11405' ' 11034' I-IT' X 4-1/2" BAKER SABL-3 PKR, D =3.83" I 3 -3/16" X 2 -718" XO fS 1 ♦ 1 11085 H 3-1/2" BKR DEPLOY SLY, D = 3.000" I To L —11,010' � �� 11 VA 1 11094' 3 -1 /2" HIES XN NIP, ID = 2.75" Toc 11,010' X 1 1 4 ` • H I ' ,1 , , WA 11096' H 3-1/2" X 3 -3/16" X0,10 = 2.880" I 1111 1,4, 11216' H 4-1/2" BLAST RINGS (38.83" 1 MLLOUT WINDOW 11364' - 11371' • • ∎ y ••• • 11267' 1 — T' X 4-1/2° BAKER SA BL -3 PKR, 1• '44 D=3.83" 1 �j ,j ' 11282' 4-1/2" CAMCO DB NIP, ID = 3.80" 14 1/2" TBG, 12.6#, 13-CR-80, .0152 bpf, ID = 3.958" 11287 11 (MLLED TO 3.80" 06/2,5/02) 3 -3/16 whipstock @ 11,390' ml 1128T H 4-1/2" WLEGI 7" X 4-1/2' - • K d 11360' PBRFO ° = a'j 'SLINNll619#, L -80, .0076 • . f, ID = 2.80" 11405' TD -14,153' REF LOG: SWS MBVORY CNI./GR/CCL 07/07/02 ANGLEAT TOP PERF: 82 @ 11675' 2 -3/8 4.7# L -80 liner Note: Refer to Production DB for historical pert data 60 deg it clatw ildow SIZE SPF INTERVAL Opn/Sgz DATE Zone 2 exit .i::::: ` 2" 6 11675 - 11695 0 041151 ,.- 1 W �'U �� ` 2' 6 11810 - 11875 0 04/14/09 ,j 111111 1111'1 2' 4 11947 - 12051 0 07/08/02 4 1 411 1 j:, 'lime 2" 4 12100 - 12230 C 07/08/02 *6 � 1 � I 129 28 ' PBTD 2' 4 12255 -12371 C 07/08102 1 2' 4 12610 -12695 C 07/08/02 4� �4 4 o 2' 4 12750 -12805 C 07/08/02 2" 4 12875 - 12925 C 07/08102 I2 -7/8" LNR, 6.16#, L -80, .0055 bpf, D = 2.441" H 12960' I DATE REV BY COMNE+ITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 05113179 ORIGINAL COMPLETION ' 04/13/07 CJNIPAG GLV CI0 WELL: 07 -13B 0927/94 SIDETRACK (07 -13A) 104/16/07 RDW/TLH WAIVER SFTY NOTE DELETED PERMT No: "2021160 07/09/02 DAVIKK CIO SIDETRACK (07 -13B) ;05/31/09 ACB/TLH PB S(04/15/09) API No: 50-029-20338-02 11/06/02 ADKFTP FERF CORRECTION 102/13/11 JLJ /AGR GLV CIO (0128111) SEC 33, T11 N, R14E, 4651' FB- 8 290' FNL 05/30/06 DTM WELLHEAD CORRECTIONS 03/13/07 CJAIPAG SET CIBP ft 12065' CTMD BP Exploration (Alaska) — Transducers 0 1 V2 , Vt V 16 1c ,. .. coded lumina Ermine a 1111.* V17 NCR ��� IC 4i IK 4. Poor Boy Gas Buster V111 Vie I •,•r 2 tit - sow pi . cocas s.ee soon vi xpe ` Mr, ' 111111111111011P1111111114 Manual Choke •^ :: �w —1111 �w us hilik. 11111111111111111W1 II _ r Canavan 000070 s � JAI � � uu Valve +6oW psi !AEON /Diesel r P Line CoFles Hose .�.' ill . - 4 U I 1/4 Tom Halve 10W To Production Tree or Cross Over I ' ii r if e transducers CoFles Hose CV22 To Coded Tubing Bleed og Inner Rut Valve e CV23 Cement line In Ground Laval Tie-in I 1 �— 6 / Manual Choke T Stand Pip ti t ‘''''' -. — __ __ _'_ _ I ti C YST , 1 0 CV2 Mud Pump �` r r Alb, Baker — `/ ► v _ _ Choke _ - Kid MIMI -• CV14 — to Pits —""' a — Line STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ~~~~~s~~ +~AY ~ 2 2~Q9 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated - ~t1R3. IrOfnmiec~~ ft Performed: Alter Casing ~ Pull Tubing ~ .Perforate New Pool ~ Waiver Time Extensiop~~Of.~~s Change Approved Program ~ Operat. Shutdown ~ Perforate 0 Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development Exploratory 2o2-11so 3. Address: P.O. Box 196612 Stratigraphic I Service 6. API Number: Anchorage, AK 99519-6612 50-029-20338-02-00 7. KB Elevation (ft): 9. Well Name and Number: 52.26 KB PBU 07-136 8. Property Designation: 10. Field/Pool(s): ADLO-028309 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 12960 feet Plugs (measured) 12065' 3/13/07 true vertical 8995 feet Junk (measured) None Effective Depth measured 12928 feet true vertical 8999 feet Casing Length Size MD TVD Burst Collapse Conductor 108 20" 94# H-40 SURFACE - 108 SURFACE - 108 1530 520 Surface 2760 13-3/8" 72# L-80 SURFACE - 2760 SURFACE - 2728 4930 2670 Production 10005 9-5/8" 47# L-80 SURFACE - 10005 SURFACE - 7840 6870 4760 Scab Liner 204 7-5/8" 29.7# L-80 2312 - 2516 2309 - 2504 6890 4790 Liner 1568 7" 29# L-80/13CR 9796 - 11364 7675 - 8887 7240 5410 Liner 1875 3-3/8"X2-7/8" L-80 11085 - 12960 8685 - 8975 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1/2" 12.6# 13CR-80 SURFACE - 11287' 0 0 - Packers and SSSV (type and measured depth) 7"X4-1/2" BAKER SABL-3 PKR 11034' 7"X4-1 /2" BAKER SABL-3 PKR 11267' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measuredj: w~k~~~ t~~~ ~a~ r ; ~ ~ Y : UU U Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 744 24174 18 343 Subsequent to operation: 1610 17152 92 317 14. Attachments: 15. Well Class after proposed work: copies of Logs and surveys Run Exploratory Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas ~ WAG GINJ WINJ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 5/8/2009 Form 10-404 ReGised 04/2006 { "* p~ ~~_~~ a'ta . ~ I~IiV ~ 71J~~ Submit Original Only 07-136 202-116 PFRF OTTOC_HMFNT n U Sw Name Operation Date Perf Operation Code ----- --------------- Meas Depth Top -- Meas Depth Base Tvd Depth Top Tvd Depth Base 07-13B 7/8/02 PER 11,947. 12,051. 8,996.79 8,997.2 07-13B 7/8/02 PER 12,100. 12,230. 8,996.73 8,989.74 07-136 7/8/02 PER 12,255. 12,371. 8,989.61 8,988.75 07-136 7/8/02 PER 12,610. 12,695. 8,991.45 8,993.42 07-13B 7/8/02 PER 12,750. 12,805. 8,993.36 8,991.87 07-13B 7/8/02 PER 12,875. 12,925. 8,985.43 8,979.46 07-13B 3/13/07 BPS 12,065. 12,065. 8,997.21 8,997.21 07-13B 4/14/09 APF 11,845. 11,875. 8,996.42 8,996.16 07-13B 4/15/09 APF 11,675. 11,695. 8,992.02 8,994.47 07-13B 4/15/09 APF 11,810. -~/ 11,845. 8,996. 8,996.42 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 07-13B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/13/2009CTU #9 1.75" CT ((( Job Scope - Memory GR/CCL, Pertorate 11,675'-11,695' { sand 11,810' - 11,875' ))) «<InterAct Publishing»> MIRU, RIH w/ PDS Memory GR/CCL Tag CIBP at 12094' dwn , up 12089' up, Log up to 11,050, POOH ... *'"'"'`Job Continued on 04/14/09"**" l 4/14/2009 `CTU #9 1.75" CT ((( Job Scope -Perforate 11,675'-11,695' and 11,810' - 11,875' ))) Job Continued from 04/013/09. «<InterAct Publishing»> POOH, RD logging tools, good data, -29' correction (tied into SLB Memory GR/CCUCNL, July-08- ~2002. MU &RIH 30' guns and pert 11845' to 11875' (1st of 3 runs) POH and 'LD same, MU Gun run #3, Jet hydrates .POOH , MU &RIH 35' of guns and firing head.... "**''Job Continued on 04/15/09**** 4/15/2009 CTU #9 1.75" CT ((( Job Scope -Perforate 11,675'-11,695' and 11,810' - 11,875' ))) Job Continued from 04/014/09. «<InterAct Publishing»> RIH with 35' guns, Perforate 11810' to 11845', POOH. At surface, all shots fired. MU Gun #3. RIH w/ FGun #3. Correct to top shot at flag. Perforate interval from 11675' - 11695' MD (ref: (SLB Memory GR/CCUCNL, July-08-2002) w/ 2.00" Guns loaded with 6 spf-60 deg. phasing - 2006PJ HMX charge. POOH. At surface confirmed all shots fired. RDMO. Notify operator of well status. Final T/I/O = 1002 / 2100 / 400. ****Job Complete**** FLUIDS PUMPED BBLS 128 DIESEL W/2% LO TORQUE 338 50/50 METH 25 1 % KCL XS W/.6% SAFELUBE 41 NEAT METHANOL 532 Total Ta: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907} 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Catiper/ MTT) The technical data listed be{ow is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ~6~ - /~ ~-f-1~o ~~~4 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road ~, , ,... ,... Suite C --m~~~~~~ ~ F ~ ~ ~ ~ ~~ Anchorage, AK 99518 Fax: (907) 245-8952 1 J Leak Detection - WLD 07 Apr-09 K-09C ', 2] Coil Flag 13 Apr~09 07-13B ~, ~~ Signed: ~ /~~ ~~ ~--.~ Print Name: Color Log / EDE 50-029-21736-03 EDE Date : ~~~~' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907245-8951 FAX: (907245-88952 E-MAIL : _ __ _ ; _:~ _= WEBSITE : ;, C:\Documeals and Settings\Owner\Desk[op\Transmit_BP.docx 07-13B (PTD #2021160) Internal Waiver Cancellation - Normal Well . . All, An internal waiver was issued for a IAxOA communication on well 07-138 (PTD #2021160) on 12/12/05. The rate of communication has been reviewed and is manageable by bleeds. Gas lift may be used to put the well on production under normal operating pressure limits of 2000 psi on the IA and 1000 psi on the OA. The well is reclassified as a Normal well. Please remove all waivered well signs and the laminated copy of the waiver from the wellhouse. Thank you, )fnna (])u6e, Œ'.l£. Well Integrity Coordinator GP8 Wells Group Phone: (907) 659ø5102 Pager: (901) 659-5100 x1154 SCAJNNED APR 3 0 2007 1 of! 4/17/200712:32 PM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _lnserts\Microfilm _ Marlœr.doc ;3 ~~J\ DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021160 MD 12960 V .-- Well Name/No. PRUDHOE BAY UNIT 07-13B Operator BP EXPLORATION (ALASKA) INC 5(1 ¿< ¿ .3 J v ~ 4'"1'2- API No. 50-029-20338-02-00 TVD 8995-' Completion Date 7/8/2002--- Completion Status 1-01L REQUIRED INFORMATION Samples No Types Electric or Other Logs Run: Well Log Information: Logl Electr Data Digital Dataset Type Med/Frmt Number Name ...rLog- jJ.eg I ¡~ p.t.og i :ED.----D 409 iik15t~- ~og I . ¡~. --~-~--- DATA INFORMATION i !EDvEf I ~L09 t.Jßpt I qLog I I~~ i i ED L----G I I~ Mud Log No v11634 Log Log Run Scale Media No 25 Blu 1 25 Blu 25 Blu 25 Blu 25 Blu 25 Blu 25 Blu 25 Blu 25 Blu 25 Blu ~ Blu 2 Blu LIS Verification :rñjèction..Profile ¿)Péctional S~rvey I\.Spinrt~r DirêctiohalSUrY~Y . ,,-Pressure '~singcÞnårlþçåto~ / v11239 Neutron .....-Temperature ED _.C Asc ¿, 121 07 LlSVerification _.Log "'12107 4.5D -C Asc I ED .-c Pdf ~ ..G Pdf L--- ~11773 LIS Verification <-11773 Rate of Penetration -11773 InductioI1lR$$Î$ti\jity. 25 25 Current Status 1-01L UIC N -- ~-'-- ---, j Directional Survey (Yes_Æ_-"'- (data taken from Logs Portion of Master Well Data Maint) Interval OHI -/ Start Stop CH Received Comments ..!QZ-~.? 12916 Case 217/2003 /f0900 12919 Case 1 0/25/2002 -fú900 12919 Case 1 0/25/2002 /..J 0805 12923 Case 217/2003 11271 12916 Case 3/17/2003 ~~~ 12916 Case 217/2003 -H271 12916 Case 3/17/2003 A 10805 12923 Case 217/2003 1~Z 1Wß- Case 217/2003 11321 12960 Open 8/14/2002 i{I 0805 12923 Case 217/2003 11321 12960 Open 8/14/2002 - 1\:1 0805 12923 Case 217/2003 .,A'0900 12919 Case 1 0/25/2002 A0898 12923 Case 1 0/25/2002 1.Q?~ 12916 Case 217/2003 10792 12916 Case 5/30/2003 10792 12916 Case 5/30/2003 Borax CNL - Memory GRlCCUCNL 11246 12934 11332 12934 Open ROP, NGP, DGR, EWR 11332 12934 Open ROP, NGP, DGR, EWR DATA SUBMITTAL COMPLIANCE REPORT 8/2/2004 Permit to Drill 2021160 Well Name/No. PRUDHOE BAY UNIT 07-13B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20338-02-00 MD 12960 TVD 8995 Completion Date 7/8/2002 Completion Status 1-01L Current Status 1-01L UIC N Well Cores/Samples Information: Name Interval Start Stop Sent Received Sample Set Number Comments Well Cored? ADDITIONAL INFORMATION vG Daily History Received? "\ (j)/N " GJN ~/ Analysis Received? Chips Received? .- V / N - ý~ Formation Tops Comments: Compliance Reviewed By: )~ Date: /(') ~~'ù1 - ') à\j2 --~' ( ~'6 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 J\nchorage, AJaska 99501 RE: MWD Formation Evaluation Logs: 07-13B, 07-13B: Digital Log Images 50-029-20338-02 June 05, 2003 AK-MW~22110 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 Date: LO I f { /0'3 ð2~, Signed: Schlumbeflger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job# Log Description Date D.S.1-19A ðo.~'~ LDL D.S.13-19 -"5\1 - \ ~'l) - INJECTION PROFILE D.S. 7-13B $fr-"'rl.." \ \ In 23057 MCNL 05/11/03 05/07/03 01/15/03 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED MA'f 3 0 200:; .A.ia3ka OH &. Gas Cons. C-ommi5eion ,A.nchorage Blueline NO. 2785 Company: 05/15/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Endicott, Niakuk Color Prints 1 1 1 CD ~ ) & /6 ~ '- Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Received~d-~,~ 0-~j'i\ ) ) WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 33 3 West 7th Avenue, Suite :1 00 Anchorage, Alaska March 17, 2003 RE: MWD Formation Evaluation Logs 07-13B, AK-MW-22110 1 LDWG formatted Disc with verification listing. API#: 50-029-20338-02 QCB-.-I/() (.- ( ( ¿) \~3(1 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 Date: --,-,,"""~:::".~~£J Sign'0~ LJ,}¿~v RECE'VED 7 MAR 1 ~ 2.003 Ala.! OH & Gas Cons. Commis8ion Anchorage Schlumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well D.S.11-35 J YI./-Olo ~ D.S.4-09 ~u,- O..~O D.S.7-11A J ¡-15ft, 2-08/K-16 -C;Qa./ 2-18/L-16 J O-{)Ll~ D.S. 9-30 J ~ -/~ D.S. 13-34 I d - I\. ~ D.S. 7-13B ã()d-)) b D.S.7-13B j" 02/05/03 NO. 2838 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Job# Log Description Color Date Blueline Sepia Prints CD 01/17/03 1 01/15/03 1 01/22/03 1 01/07/07 1 01/14/03 1 01/14/03 1 12/29/02 1 01/13/03 1 01/15/03 1 INJECTION PROFILE INJECTION PROFILE CALIPERS LOG W/PRESSITEMP PROD PROFILE/DEFT PROD PROFILE/DEFT/GHOST PROD PROFILE/DEFT PSP PROD PROFILE/DEFT MEM PROD PROFILE INJECTION PROFILE ~. PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETUFiN~(. . ~ COpy EACH TO: BP Exploration (Alaska) Inc. RECElvr:u Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth FEB 07 2003 ,... Of¡ & Gas Cons. Co.mtitiln AnchorIge ReceiV~Ú ooo~ Schtumberger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503.5711 ATTN: Beth Well G-10B ~O;).-}JÎ D.S. 7-13B~Q,.;1- Jllo D.S. 11-24A J't~-~O" D.S.6-01 I í~" 04 g Job# 22332 MCNL 22333 MCNL 22381 RST 22378 RST 10/17/02 NO. 2488 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Sepia Prints CD 06/29/02 1 1 07/08/02 1 1 07/06/02 1 1 07/07/02 1 1 ....~/ -- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 :~~id~&Cb~ OCT 2 5 2002 AJsaAlc" O~ & GqS Coni. CQrmnillion Anchofage ') ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 181 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface rf,ÕMPL"frÎoÑ- \ rrõtAì_~ 628' SNL, 290' WEL, SEC. 33, T11 N, R14E, UM ~ DATE " r " Yo. ,/ ~,,' At top of productive intervalf '7, f ..0 z. ~. ~ ; 3854' NSL, 4143' WEL, SEC. 28, T11 N, R14E, UM: VER)Jl~O ", " S ,'. ,. . ,Y.", ',~ ~ 5~~~~kf~~~81' WEL, SEC. 28, T11 N, R14E, UM '::....¿!::.-:::;.:-:::', t~:~..~{~ '" I J Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 52.26' ADL 028309 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 7/3/2002 7/6/2002 7/8/2002 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 12960 8995 FT 12928 8999 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, GR, ROP, Memory CNL, GR, CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE CEMENTING RECORD 20" 94# H-40 Surface 108' 30" 243 sx Arcticset 13-3/8" 72# L-80 Surface 2760' 17-1/2" 5600 sx Arcticset II 9-5/8" 47# L-80 Surface 1005' 12-1/4" 1400 sx Class 'G' 7-5/8" 29.7# L-80 2312' 25161 13-3/8" (Scab Liner) 7" 29# L-80 / 13Cr 9796' 11364' 8-1/2" 500 sx Class 'G' 3-3116" x 2-7/8" 8.81#/6.16# L-80 11085' 12960' 3-3/4" 98 sxClass 'G' 24. Perforations open to Production (MD+ TVD of Top and 25. Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD 11947' -12051' 9013' - 9014' 12100' - 12230' 9014' - 9008' 12255' - 12371' 9007' - 9006' 12610' -12695' 9007' - 9010' 12750' -12805' 9011'- 9010' 12875' - 12925' 9005' - 9000' Classification of Service Well 7. Permit Number 202-116 8. API Number 50- 029-20338-02 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number 07-138 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2059' MD 1900' (Approx.) MD TVD SIZE 4-1/2", 12.6#, L-80 & 13Cr80 26. AMOUNT PULLED TUBING RECORD DEPTH SET (MD) 11287' PACKER SET (MD) 11034' & 11267' ACID, FRACTURE, CEMENT SaUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with MeOH 27. Date First Production July 23, 2002 Date of Test Hours Tested 8/5/2002 6 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 2274 GAs-McF 23,929 GAs-McF WATER-BBL 28 WATER-BBL Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE OIL -BBL CHOKE SIZE 85° I ¡ i GAS-OIL RATIO 10,523 OIL GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. No core samples were taken. ~¡ ':~ ~. " ' ,( ~- ~ ......: T '-" J'i' GY Form 10-407 Rev. 07-01-80 0 RIG ¡ r,j A ~BnMS B:~:d)i~~;~p::;'!,~¡~~:,~~ate ') ) 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 22TS 11293' 8841' 21TS I Zone 2A 1137T 889T Zone 1 B 11586' 8984' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the foryoin? is t~u~ and correct to the best of my knowledge Signed Terrie Hubble -'10Jú\J..q.J ~ ~ Title Technical Assistant 07-13B 202-116 Well Number Permit No. I Approval No. Date 06.~~.o~ Prepared By Name/Number: Terrie Hubble, 564-4628 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none', Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Operations Summary Report Page "1""" of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-13 B 07-13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Date From "- To Hours 'Task Code NPT Phase Description ofOþerations 7/1/2002 00:00 - 05:00 5.00 MOB P PRE Move Nordic Rig #1 from G-10B to OS 07-13B. No incidents. 8 hour rig move. 05:00 - 06:45 1.75 MOB P PRE On OS 7 at 05:00 hrs. Raise Mast and windwalls. Back rig in front of well. 06:45 - 07:00 0.25 MOB P PRE SAFETY MEETING. Review procedure, hazards and mitigation for backing rig over well. WHP = 0 psi, lAP = 0 psi, Flowline = 0 psi. 07:00 - 08:00 1.00 BOPSURP DECOMP ACCEPT RIG AT 07:00 HRS, 07/01/02. N/U BOPE. Pick injecter head out of pipe bay and set on rig floor. 08:00 - 08: 15 0.25 RIGU P PRE SAFETY MEETING. Review procedure, hazards and mitigation for picking CT reel out with Peak Crane. Determine radio procedure for safe operations. 08:15 - 09:00 0.75 RIGU P PRE Pick 2" CT reel with Peak crane. No problems. Continue general rig up of tanks, berms, hardline and trailers. 09:00 - 13:45 4.75 RIGU P PRE Set 2-3/8" CT reel in reel house. Found reel support bushings to be slightly small. Pick reel and set on ground while removing bushings and replacing with slightly larger 00 bushing. Unable to remove bushings. Cut off with torch. 13:45 - 14:00 0.25 BOPSUR P DECOMP SAFETY MEETING. Review procedure, hazards and mitigation for BOP pressure testing. Review SIMOPS with reel installation. No conflict expected. Nordic to perform BOP test and OS personnel to do reel swap. 14:00 - 17:00 3.00 BOPSURP DECOMP Perform initial BOPE pressure and function test. Witness waived by AOGCC inspector, Jeff Jones. Continue with installation of new bushings. Install new 2-3/8" CT reel with no problems. Reel installation completed at 17:00 hrs. 17:00 - 19:45 2.75 BOPSURP DECOMP Continue with BOP pressure test. Change out injecter gripper blocks from 2" to 2-3/8". Fill rig pits with 300bbls of 1 ppb, 2% KCL milling fluid. 19:45 - 20:00 0.25 RIGU P PRE PJSM for M/U guide arch & stabbing CT. 20:00 - 23:30 3.50 RIGU P PRE P/U injector head & M/U guide arch. Stab CT & observe -8k stack wt with CT across injector blocks. Check pack-off - correct size. Troubleshoot - nothing amiss. Looks like lots of friction from used pipe against new gripper blocks or some wt calibration anomaly. SIB injector. 23:30 - 00:00 0.50 RIGU P PRE Line up & PlTest wellbore/abandoned perfs to 2000psi - leaked 230psi in 30 mins. Meanwhile finish hooking-up hardline to CT reel. 7/2/2002 00:00 - 00:15 0,25 RIGU P PRE Held pre-operations safety meeting with crew. Reviewed well plan, potential hazards & M/U window milling BHA. 00: 15 - 00:45 0.50 STWHIP P WEXIT M/U D/S dimple CTC. Pull test - OK. 00:45 - 01 :20 0.58 STWHIP P WEXIT Load dart & chase/fill CT with bio-KCL water. Saw little pressure rise after 59 bbls (calculated CT vol - 60 bbls). Pump 65bbls & observe no dart bump. B/O dart catcher & see dart inside. 01 :20 - 01 :45 0.42 STWHIP P WEXIT PlTest CTC to 3500 psi. PlTest inner reel valve & CT hardline to 500 psi, 3500 psi. 01:45 - 02:15 0.50 STWHIP P WEXIT M/U window milling BHA#1. Tag up @ tree valve. Troubleshoot observe SSV closed Call out DSO. 02:15 - 03:00 0.75 STWHIP N SFAL WEXIT DSO pump open SSV & hook-up line for any future pumping. 03:00 - 03:30 0.50 STWHIP N SFAL WEXIT Repressure test wellbore/abandoned perfs to 2000psi - held steady for 20 mins. Will use this as baseline for future PlTests. Printed: 7/10/2002 12:24:04 PM ) ) BP EXPLORATION OperatIons Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-13 B 07-13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Date Frohl- To Hours Task Code NPT Phase 7/2/2002 03:30 - 03:40 0.17 STWHIP P WEXIT 03:40 - 05:50 2.17 STWHIP P WEXIT 05:50 - 08: 1 0 2.33 STWHIP P WEXIT 08: 1 0 - 11 :00 2.83 STWHIP P WEXIT 11 :00 - 13:00 2.00 STWHIP P WEXIT 13:00 - 15:00 2.00 STWHIP P WEXIT 15:00 - 15:45 0.75 STWHIP P WEXIT 15:45 - 17:30 1.75 STWHIP P WEXIT 17:30 - 18:30 1.00 STWHIP P WEXIT 18:30 - 18:45 0.25 STWHIP P WEXIT 18:45 - 20:15 1.50 STWHIP P WEXIT 20:15 - 22:10 1.92 STWHIP P WEXIT 22:10 - 00:00 1.83 STWHIP P WEXIT Page 2 of9 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 DescriptiOrtof Operations Continue MIU window milling BHA#1 with DSM, string mill, straight motor & 2 jts of 2-3/8" PH6 tbg (OAL- 85.12'). RIH window milling BHA#1 with negative wt to 2000'. Observe break over to positive RIH wt @ 2000'. Check up wt @ 4000'- +12k (should be @ +15k & with any friction should be more). Continue RIH & tag with minimum rate @ 11360'. Up wt check = 43klbs. Kick pumps on, free spin @ 2.5bpm = 1200psi CTP. Re tag @ 11357 & begin milling cement. Milled cement to pinch point on whipstock at 11362.4 ft CTD. Correct depth to 11,364 ft, reference top of whipstock setting depth at 11,360 ft.. Mill window thru 7", 29#, 13CR liner. 2.4/2.4 bpm, 1200 psi, 1500-2000 WOB, Milled to 11,366 ft. Mill window thru 7" Liner. 2.4 12.4 bpm, 1300 psi, 1500-3000# WOB, Milled to 11,367.2 ft. Mill window thru 7" Liner. 2.4 1 2.4 bpm, 1400 psi, 1500-3000# WOB, Milled to 11,370 ft. Mill window thru 7" Liner. 2.4 / 2.4 bpm, 1600 psi, 1500-3000# WOB, Drilling formation at 11,370 ft. Window top at 11364 ft, bottom at 11370 ft. Milled to 11,371 ft. Milling formation, Zone 2, clean sand. 2.6/2.6 bpm, 2200 psi, 3500# WOB, Stacking wt up to 4500# WOB. Back ream thru window twice with little motor work. Mill formation to 11,372 ft. Circ. well to re-conditioned FloPro while drilling formation. Milling formation. 2.6/2.6 bpm, 1600 psi, 3500# WOB, Stacking wt up to 4500# WOB. No Progress. Backream across window. Continue milling formation. Free spin 3020 psi at 2.7 bpm. 100% returns. Depth=11370.5'. (No stacked weight). Saw motor work increase 200# on bottom. Made 0.5', but then couldn't make any more. String wt=15500#, WOB=3350#, CTP=3130 psi. Not seeing any drilloffs, or any more motor work for last hour. Mill is just outside window at this point. String reamer should be just at bottom of window. Caught sample. Geo reports mostly cement and metal cuttings, some formation sand present however. 11372' (Stacked weight on pipe). Unable to make any significant progress in last 4 hours. Trip to examine mill and reamer. Need more rathole prior to picking up drilling BHA. Tag up at surface. Lay down BHA #1, inspect same. Found formation mill in gauge (passes 3.80", no-go's 3.79"). Found string mill in gauge, (passes 3.81", no-go's 3.80"). Motor appears tight. No apparent swirl wear pattern on face of mill, but obvious wear on gauge and cutting lip section. No apparent wear on string mill. Pick up Baker MMlcutrite 4 bladed mill gauged at 3.80", run in combination on same string reamer as previous run, PU new motor. PT MHA to 3500 psi passed ok. Re-run same MHA, Printed: 7/10/2002 12:24:04 PM ') ) BP EXPLORATION OperationsSummary~.eport Page 3 öf9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-13 B 07 -13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/3/2002 00:00 - 00:20 0.33 STWHIP WEXIT Continue making up BHA#2 to dress window. 00:20 - 02:30 2.17 STWHIP WEXIT RIH with BHA #2 to dress window and drill 1 0' of formation. 02:30 - 03:30 1.00 STWHIP WEXIT Kick pumps on. Free spin=3010 psi at 2.6 bpm. Tie into flag at 11364.0'. (+12.7' correction). Begin milling. Saw first motor work and stall at flag, then went thru easily. This is spot on depth to top of window. Continue milling. 03:30 - 04: 15 0.75 STWHIP WEXIT Saw significant motor work 11369.4'-11371.5', Probably lip at bottom of window. Had to work it for a while, then broke thru. 04:15 - 06:00 1.75 STWHIP WEXIT Drill formation to 11374 ft. Very slow progress. 2.5 1 2.5 bpm, - 3000 psi, several stalls. 06:00 - 09:30 3.50 STWHIP WEXIT Drill formation to 11375 ft. Less stalls. Back ream, stall at top of window at 11,364'. RIH and stall at top of window again. Ream top of window area. Ream to TO. Tag TO at 11375 ft. Geologist saw mostly chert in formation sample. 09:30 - 10:00 0.50 STWHIP WEXIT Back ream up thru window at 0.5 fpm. Clean window. Stop pump, RIH clean to TO of 11,375.6'. Pull thru window clean. 10:00 - 12:00 2.00 STWHIP WEXIT POH for MWD drilling BHA. 12:00 - 12:30 0.50 STWHIP WEXIT Layout milling BHA. 12:30 - 12:45 0.25 STWHIP PROD1 SAFETY MEETING. Pre-Spud meeting with day crew. Review well plan and hazards. Review procedure, hazards and mitigation for MWD BHA make up. 12:45 -13:15 0.50 STWHIP PROD1 M/U Sperry MWD BHA #3. 2.29 deg BHI motor and M09 Bit #3 [re-run] 13:15 - 15:30 2.25 STWHIP PROD1 RIH with MWD build BHA #3. Shallow hole test Sperry tools. OK. RIH. 15:30 - 16:20 0.83 STWHIP PROD1 Correct to CT flag. [+16 ft]. Log up with GR and tie-in with BHCS/GR. [-16 ft correction]. 16:20 - 16:40 0.33 STWHIP PROD1 Orient TF to high side. 16:40 - 18:30 1.83 STWHIP PROD1 RIH thru window, Clean window. Tag TO at 11,356 ft. Tied in depth, whipstock appears to be off depth. Drilling, 2.5 / 2.5 bpm, 3380 psi, TF = 20-60R, 42 fph, Drilled to 11,405 18:30 - 21 :00 2.50 DRILL PROD1 11402', Drilling ahead 2.5/2.5/3640 psi. Pit vol=329 bbls. ROP=35 fph at 74R tool face. 21 :00 - 22:20 1.33 DRILL PROD1 10509', Orient to 60R. Only getting 10 deg clicks. Orienter not working 100% (Possibly in a bind?). Tried orienting at TO, with poor success, try pulling up to just below window to orient, got 20 deg clicks there. Orient, run back to TO. 22:20 - 00:00 1.67 DRILL PROD1 Resume drilling. 2.5/2.5/3900. Free spin 3600 psi. Pit Vol=326 bbls. ROP=60 fph at 69R TF. 7/4/2002 00:00 - 00:50 0.83 DRILL PROD1 Drilling ahead at 11625', 2.7/2.7/4250 psi. 324 bbls in pits, 00:50 - 02:00 1.17 DRILL PROD1 11663', orient around to 50R, short trip to shoe to get clicks, 02:00 - 02:40 0.67 DRILL PROD1 Resume drilling. 02:40 - 03:40 1.00 DRILL PROD1 11715', Pull up to casing shoe, and orient to high side. 03:40 - 03:45 0.08 DRILL PROD1 Resume drilling. 03:45 - 05: 15 1.50 DRILL PROD1 11718', tool face flopped around to 70R, pick up to orient. Got back to bottom and it flopped again. Pull up to shoe and re-orient. 05: 15 - 06:45 1,50 DRILL PROD1 Resume drilling, TF=90R. Drilled to 11,775 ft. Finished build section. 312 bbls in pit. 06:45 - 09:00 2.25 DRILL PROD1 POH for lateral 1 resistivity BHA. 09:00 - 09:45 0,75 DRILL PROD1 Layout build BHA. M09 bit still in good condition [1 cutter chipped on side] Printed: 7/10/2002 12:24:04 PM ) ) BP EXPLORATION Operations Summary Report Page4-of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -13 B 07 -13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/4/2002 09:45 - 10:00 0.25 DRILL PROD1 SAFETY MEETING. Review CT cutting procedure, hazards and mitigation. 10:00 - 11 :00 1.00 DRILL PROD1 Cut off 450 ft of CT for fatigue life maintenance. M/U CTC and pull 1 press test. 11 :00 - 13:00 2.00 DRILL PROD1 M/U Sperry Resistivity MWD BHA #4 with 1.04 deg motor and used DS49 Bit #4. 13:00 - 14:15 1.25 DRILL PROD1 Test resistivity tool at surface. OK. 14:15 - 16:15 2.00 DRILL PROD1 RIH with Res. MWD lateral BHA #4. Shalllow test tools, OK. RIH. 16:15 - 16:30 0.25 DRILL PROD1 Orient TF to high side. RIH to 11385 ft. 16:30 - 17:00 0.50 DRILL PROD1 Log GR tie-in with MWD GR. [-3 ft CTD). 17:00 - 17:15 0.25 DRILL PROD1 RIH and tag TO at 11,774 ft. 17:15 - 18:30 1.25 DRILL PROD1 Log MAD pass with RES 1 GR, up at 150 FPH. 2.5/2.5 bpm, 3240 psi. 18:30 - 18:50 0.33 DRILL P PROD1 Orient to 1 OOL. 18:50 - 19:20 0.50 DRILL P PROD1 11774', Begin drilling lateral section. 2.7/2.7/3500 free spin. Pit vol=309 bbls. Drilled to 11785', heavy pickup. Pulled to 65klbs prior to pulling free. 19:20 - 19:45 0.42 DRILL N DFAL PROD1 Not getting good surveys from MWD tools. PUH and circulate until they get problem sorted. Overpull at 11685'. Sperry has apparently sorted out problems, RIH and attempt to drill. 19:45 - 20:30 0.75 DRILL N DFAL PROD1 Swap rig pumps, attempt to resume drilling. Sperry MWD tool still not giving good surveys or Inc. TF appears good. Still can't manage to drill. G totals out of tolerance. Wait on Sperry to work on problems. 20:30 - 20:35 0.08 DRILL P PROD1 Orient to 70L. Sperry tool working. 20:35 - 20:50 0.25 DRILL P PROD1 Resume drilling. Having to pickup and get surveys off bottom. 20:50 - 20:55 0.08 DRILL P PROD1 Orient to 50L. Getting 20 deg clicks, and seem to be getting 1 for 1. Orienter working much better than yesterday. 20:55 - 21 :20 0.42 DRILL P PROD1 11860', resume drilling. 2.4/2.4/3150 psi free spin. Pit vol=301 bbls. Drilling at 3620 psi, 130 fph. 21:20 - 23:10 1.83 DRILL N DFAL PROD1 11894', MWD again giving unrelaible surveys, an Inc's. Investigation of biit record shows that the last time this bit was run they had the same problems. (X-31 , 4-3-2002). It could be that this bit is causing too much vibration downhole. Trip for new bit. 23: 10 - 00:00 0.83 DRILL N DFAL PROD1 Tag up at surface, stand back injector. Pull pulser, check Sperry MWD tool. Appears ok. Change out bit. 7/5/2002 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Continue with BHA swap. Sperry tool checked out fine at surface. Old bit graded at 1/1. No wear or chipped cutters to explain the vibration we had down hole. New bit will eliminate the question of rebuilt bit, and hopefully the vibration. Stab on injector. 01 :00 - 03:00 2.00 DRILL N DFAL PROD1 RIH with BHA #5, 1.04 deg motor, new Hycalog DS49 bit. Shallow hole test @700' passed ok. G totals are within tolerance. Continue RIH to TO. Check G totals and surveys at window. Check ok. 03:00 - 04:15 1.25 DRILL N DFAL PROD1 Tag bottom at 11904' CTM. Make -10' correction to get on depth. PUH to get survey missed on previous run at 11750'. Can't get azimuths. G total now too high. #$*&%$ Same problem as last run. Drop down to TO to attempt to get a good survey at bottom. Can't get good surveys, inc's, G totals bad. Try at different pump rates. Try with more C pump pressure. Printed: 7/10/2002 12:24:04 PM ) ) BP EXPLORATION Q.peratlonsSummary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-13 B 07 -13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Date From - To Hours Task Code NPT Phase 7/5/2002 03:00 - 04: 15 1.25 DRILL N DFAL PROD1 04:15 - 06:05 1.83 DRILL N DFAL PROD1 06:05 - 08:30 2.42 DRILL N DFAL PROD1 08:30 - 10:30 2.00 DRILL N DFAL PROD1 10:30 - 10:45 0.25 DRILL N DFAL PROD1 10:45 -11:20 0.58 DRILL N DFAL PROD1 11 :20 - 12:00 0.67 DRILL N DFAL PROD1 12:00 - 13:00 1.00 DRILL P PROD1 13:00 - 13:50 0.83 DRILL P PROD1 13:50 - 14:40 0.83 DRILL P PROD1 14:40 -16:15 1.58 DRILL P PROD1 16:15 -17:00 0.75 DRILL P PROD1 17:00 - 17:15 0.25 DRILL P PROD1 17:15 -18:10 0.92 DRILL P PROD1 18:10 -18:30 0.33 DRILL P PROD1 18:30 - 18:45 0.25 DRILL P PROD1 18:45 - 19:30 0.75 DRILL P PROD1 19:30 - 20:15 0.75 DRILL P PROD1 20:15 - 21 :20 1.08 DRILL P PROD1 21 :20 - 21:40 0.33 DRILL P PROD1 21:40 - 22:10 0.50 DRILL P PROD1 22:10 - 23:15 1.08 DRILL P PROD1 23: 15 - 23:25 0.17 DRILL P PROD1 23:25 - 00:00 0.58 DRILL P PROD1 7/6/2002 00:00 - 00:20 0.33 DRILL P PROD1 00:20 - 00:35 0.25 DRILL P PROD1 00:35 - 00:50 0.25 DRILL P PROD1 00:50 - 01 :05 0.25 DRILL P PROD1 Page 5 of 9 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Description of Operations Try with different Sperry surface transducers. All unsuccessful. Try at different tool faces, orient from high side to low side, and try at 2.2 bpm. Finally got a good survey at 11750'. Run to bottom and try a survey at 11860'. Can't get a survey. Try at different pump rates and tool faces. No success. There is some sort of problem. Can't drill blind, or taking 1.25 hours per survey. Note - This MWD probe is different than the one used to drill the lateral section POOH to change out all Sperry MWD eq. below the orienter, including probes, housings, EWR. G totals looked good in casing while POOH, but we have to come out to do something different. Tag up at surface, stand back injector. Lay down Sperry MWD/EWR tools and motor. Pick up same DS49 bit just run, a new motor, new Sperry MWD/EWR tools, same orienter and MHA. Test tools at surface. OK. RIH with RES MWD BHA #6 with 1.04 deg motor, DS49 bit. Shallow hole test. OK. RIH. Orient TF to high side. Log tie-in with MWD GR. [-5 ft CTD]. RIH. Tag TO at 11,895 ft. Make check shot surveys. Drilling, Good G Totals, lower probe in RES tool appeared to be the problem on earlier 2 runs. 2.5 / 2.5 bpm, 3300 psi, 84L, Drilled to 11970 ft. Drilling, TF = 46L, 2.51 2.5 bpm, 3300 psi, Try to hold 91 deg incl. Drilled to 12050' Wiper trip to window. Clean hole. RIH to TO. Drilling, TF = 70L, 2.5/2.5 bpm, 3300 psi, 92 deg incl, Drilled to 12,200 ft. Wiper trip to window. Clean hole. RIH to TO. Orient TF to 140L. Drilling, TF = 140-100 L, 2.5/2.5 bpm, 3400 psi, 92 deg incl, Drilled to 12,300 ft. Drilling, TF = 90 L, 2.5/2.5 bpm, 3400 psi, 90 deg incl, Drilled to 12, ft. 12335', Drilling ahead. 2.7/2,7/3890 psi. Pit vol=283'. Wiper trip to shoe. Clean PU off bottom at 36klbs. Resume drilling. ROP=80 fph. 12390', Continue drilling, begining mud swap to new mud system. 12467', Orient around. Resume drilling. 12498', Wiper trip to shoe. Clean PU off bottom. 36klbs. Orient Resume drilling 2.5/2.5/3450 psi. Drilling ahead from 12535'. 2.5/2.5/3600 psi. TF=176R 12560', Orient to 75L Resume drilling. 2.4/2.4/3500 psi. Free spin=31 00 psi at 2.5 bpm. 12581', orient around. Printed: 7/10/2002 12:24:04 PM ) ') BP EXPLORATION Q:perations SurrrmaryReport Page6of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -13 B 07-13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/6/2002 01 :05 - 02:45 1.67 DRILL P PROD1 Resume drilling. 02:45 - 04:00 1.25 DRILL P PROD1 12642', Wiper trip to shoe. PU a little ratty. 10-15 klbs over pull for 40'. Time to wipe the hole. Clean to window and back down after pickup. 04:00 - 05:50 1.83 DRILL C PROD1 Resume drilling. TF=60R, Free spin 3200 psi at 2.5 bpm. Pit vol=273 bbls. ROP=120 fph. 05:50 - 07:10 1.33 DRILL C PROD1 12776', Wiper trip to shoe. Sticky pickup off bottom. Clean hole up to window. RIH, Clean trip to bottom. 07:10 - 08:20 1.17 DRILL C PROD1 Drilling, 2.6/2.6 BPM, 3400 PSI, TF = 94R, Drilled to 12,826 ft. 08:20 - 08:45 0.42 DRILL C PROD1 Orient TF to 70R. 08:45 - 11 :45 3.00 DRILL C PROD1 Drilling, 2.6/2.6 BPM, 3400 PSI, TF = 70-90R, Drilled to 12,950 ft. 11 :45 - 12:45 1.00 DRILL C PROD1 Wiper trip to window. Some overpull/ motor work in shales at 12730' and 12510'. 12:45 - 13:30 0.75 DRILL C PROD1 Log Tie-in with MWD GR. Added 15 ft to CTD. 13:30 - 15:00 1.50 DRILL C PROD1 RIH to TO. Sat down at 12730', and 12830 ft. Ream shales. RIH and tag Final TO at 12,960 ft. 15:00 - 16:00 1.00 DRILL C PROD1 Short trip up to 12,430 ft to ream shales again. RIH to TO. Ream shales at 12730 and 12870 ft. Tag TO at 12,960 ft. 16:00 - 18:55 2.92 DRILL P PROD1 POH to run liner. Flag CT at 9,000 ft EOP for running liner. POH. 18:55 - 19:15 0.33 DRILL P PROD1 Tag up at surface. Stand back Injector. 19:15 - 19:35 0.33 DRILL P PROD1 Safety meeting prior to rigging down BHA and rig bridle line. 19:35 - 21 :20 1.75 DRILL P PROD1 Lay down BHA, read MWD tool. 21 :20 - 21 :45 0.42 CASE P COMP Safety meeting prior to running liner. Discuss kick potential, liner talley, MU torque, handling safety. 21 :45 - 00:00 2.25 CASE P COMP Make up 2-7/8" STL x 3-3/16" TCllliner as per proceedure. Check MU torque on both using 1. Stagg method. Stopped at top of pup joint to fill liner. 7/7/2002 00:00 - 00:20 0.33 CASE P COMP Continue running liner as per proceedure. 00:20 - 01 :40 1.33 CASE P COMP MU Baker CTLRT, PU Injector. MU CTC. Pull Test to 35klbs, ok. PT to 3500 Ibs, ok. MU CTC to top of CTLRT-DISC-XO. 01 :40 - 03:30 1.83 CASE P COMP RIH with liner string. Stop at flag, make -15' correction. RIH to window. RIH wt at window=19klbs, PU weight at window=39klbs. Continue RIH. Made it to 11404', and hung up. Saw pump pressure increase at set down. Kick pumps on to 1.1 bpm, 1970 psi. Try to wash down, made it thru after a few minutes. 03:30 - 04:35 1.08 CASE P COMP Tag up at 12500', work thru. Hit at 12520', pressured up, had to pick up to work thru. Continued to RIH, setting down every 10-30'. Set down at 12875', pressured up. Tagged numerous times. Kept working it. Lost hole. Set down at 12845'. Worked it, set down numerous times at different pump rates, could not make it past. Can still pick up, can't get past this spot. Consult with town. While waiting, mix up 6% lubtex pill and pump. 04:35 - 05:35 1.00 CASE P COMP Recieved word from town that this TO is acceptable if needed. Finish pumping 6% lubetex pill. Call for cementers. Got lubetex pill around float shoe, work coil, finally got it to fall thru 12845'. Had to work it hard, but finally made it to bottom, 12960'. Hurray!!! Made it to TO, Printed: 7/10/2002 12:24:04 PM ) ') BP EXPLORATION Operations _Summary Report Page? of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07 -13 B 07 -13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Date From- To Hours Task COde NPT Phase Descriþtion Of Operations 7/7/2002 05:35 - 06:30 0.92 CASE P COMP Drop 5/8" ball to release from liner. Chase with mud. Ball on seat at 46.5 bbls (Coil vol=58.2 bbls). Circ pres=1500 psi, ball sheared at 4000 psi (Should have been 2000 over). Pick up, confirm free. PU at 35klbs, (Was 40klbs prior to releasing liner). 06:30 - 08: 15 1.75 CASE P COMP Swap to 2% KCL. Circ to swap well to water. 100% returns when on mud. 2.9 I 2.9 bpm, 3150 psi, 0.1 bpm loss with 2% KCL water on formation. 08:15 - 08:45 0.50 CEMT P COMP R/U OS cement van. Batch mix cement Cement at wt at 0830 hrs. 08:45 - 09:00 0.25 CEMT P COMP SAFETY MEETING. Review cementing procedure, hazards and mitigation. 09:00 - 09: 15 0.25 CEMT P COMP Press test cement line. 09:15 - 09:55 0.67 CEMT P COMP Stg 20 bbls, 15.8 PPG, G Cement with Latex. 1.5 I 1.2 bpm at 800 psi. Stop pump at 20.0 bbls thru micromotion meter. Pumped Cement thru OS in line screen. Clean cement lines. Insert Baker latch dart. Pump 0.3 bbl, stop and check for dart. Dart gone. 09:55 - 10:25 0.50 CEMT P COMP Displace cement with 25 bbls of 2 PPB Biozan water with rig pumps. 2.9/2.7 bpm, 2300 psi, Switch to 2% KCL water and displace at 2.7 /2.4 bpm, 2200 psi, Zero out-totalizer with cement at shoe [49.4 bbls displ]. Slow pump at 54 bbls displ to 1.6 bpm at 1400 psi. Dart on LWP at 58.0 bbls. [58.2 bbls calc CT Vol.]. LWP sheared at 3500 psi, displace at 2.9/2.8 bpm at 3600 psi. Slow rate to 0.8 bpm at 67 bbls, LWP landed at 68.9 bbls [0.3 bbls early]. PIT with 1500 psi. OK. Check floats. OK - no flow. Good Cement Job, 18.4 bbls cement returns measured with out-totalizer micromotion meter. Should have about 3 bbls cement above liner top. 10:25 - 10:45 0.33 CEMT P COMP Press CT to 1500 psi, sting out top of liner. Circ at liner top for 25 bbls, 2.5 I 2.5 bpm, full returns. 10:45 - 12:00 1.25 CEMT P COMP POH with CT. Circ. 2.4 bpm with 1.8 bpm returns while pull at 100 fpm. Dispose of returned cement 12:00 - 12:30 0.50 CEMT P COMP Layout BKR CTLRT. M/U side jetting nozzle. 12:30 - 13:30 1.00 CEMT P COMP Close swab valve. Jet BOP stack with 2% KCL water. 13:30 - 14:00 0.50 EVAL P COMP Pick up SWS memory CNUGRlCCL, carrier and tools. 14:00 - 14:15 0.25 EVAL P COMP SAFETY MEETING. Review memory CNUGR logging tool M/U procedure, hazards and mitigation. 14:15 -16:00 1.75 EVAL P COMP Clear floor of people and pick up source, RIH with SWS logging tools. M/U BKR hyd discon, circ sub, XO. P/U 64 jts of 1-1/4" CSH. Drift with 0.90" rod, Hammer each jt to remove as much rust as possible. This workstring has not been used since Feb and had internal rust Stop at 32 jts and circ. OK. 16:00 -17:15 1.25 EVAL P COMP RIH with last 32 jts of CSH. Circulate string again to check for circ sub plugging. OK. 17:15 -18:50 1.58 EVAL P COMP RIH with SWS Memory CNUGRlCCL. BHA = 2025.3 ft. Circ, 0.6 bpm at 350 psi. 18:50 - 20:00 1.17 EVAL P COMP 10900', begin down logging pass with MCNL-GR-CCL. Pumping mud at 1.5 bpm, CTP=1830psi. 20:00 - 21 :00 1,00 EVAL P COMP Tag PBTD at 12,933 ft. Lay in high vis New FloPro pill from Printed: 7/10/2002 12:24:04 PM ') ') BP-EXPLORATION Operations Summary Report Page 8 of9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 7/7/2002 7/8/2002 07-13 B 07-13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 From- To Hours Task Code NPT Phase Description - of Operations 20:00 - 21 :00 1.00 EVAL P COMP PBTD. Log up at 30 fpm to 10,900 ft. 21 :00 - 23:00 2.00 EVAL P COMP POH with SWS memory CNLlGR/CCL tools. 23:00 - 23: 15 0.25 EVAL P COMP SAFETY MEETING. Review procedure to LIO SWS tools, hazards and mitigation. 23:15 - 00:00 0.75 EVAL P COMP Stand back 32 stds of CSH workstring. 00:00 - 00:45 0,75 EVAL P COMP Layout SWS CNLlGR logging tools. 00:45 - 01 :30 0.75 CEMT P COMP Pressure test liner lap with 2000 psi for 30 min. lost 60 psi in 30 min. Good Test. 01 :30 - 02:00 0.50 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for running perf guns. 02:00 - 02:30 0.50 PERF N WAIT COMP Geologist determined it was necessary to change upper perf intervals due to CNLlGR information. 02:30 - 04:45 2.25 PERF N WAIT COMP Give SWS new perf interval information. Wait on perf guns from SWS shop. 04:45 - 06:00 1.25 PERF P COMP Deploy SWS, 2", Power Jet Perf guns loaded at 4 SPF, 60 deg phasing. 06:00 - 06: 15 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for running perf guns with day crew. 06:15 - 07:00 0.75 PERF P COMP Deploy SWS, 2", Power Jet Perf guns loaded at 4 SPF, 60 deg phasing. 07:00 - 08:00 1.00 PERF P COMP M/U 15 stds of CSH workstring and Baker deployment tools. BHA total length = 1,948.77 ft. 08:00 - 10:15 2.25 PERF P COMP RIH with 2" Perforating BHA. Circ. at min. rate, 0.2 bpm at 200 psi. No wt loss entering top of liner. Circ. at 0.7 bpm at 300 psi inside 2-7/8" liner. 10:15 - 10:50 0.58 PERF P COMP Tag PBTD at 12,927 ft. Correct depth to 12,933 ft BKB. [+6 ft CTD]. Pump 5 bbls high Vis FloPro perf pill, insert 5/8" steel ball. Pump 8 bbls HV FloPro behind ball and displace with 2% KCL water. Position bottom perf charge at 12,925 ft BKB, as per perf program. Circ. 2.5 bpm at 2800 psi. Ball on seat at 49.7 bbls, firing head sheared at 3200psi. No extra overpull after firing. 10:50 - 13:30 2.67 PERF P COMP POH with perf guns. Circ down CT at 0.5 bpm while pulling out of 2-7/8" liner. Fill well down backside while POH inside 4-1/2" tubing. 13:30 - 13:45 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for laying down CSH workstring. 13:45 -14:30 0.75 PERF P COMP Layout 30 jts of CSH. 14:30 - 14:45 0.25 PERF P COMP SAFETY MEETING. Review procedure, hazards and mitigation for laying out perf guns and blank guns with possible trapped pressure inside. 14:45 - 17:45 3.00 PERF P COMP Layout perf guns and blanks, 47 total. All shots fired. PERFORATED INTERVALS: 11947 - 12051' 12100 - 12230' 12255 -12371' 12610 -12695' 12750 - 12805' 12875 - 12925' TOTAL OF 540' OF PERFS Printed: 7/10/2002 12:24:04 PM ') ) BP EXPLORATION Operations'Summary Report Page 9 ef9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 07-13 B 07 -13 B REENTER+COMPLETE NOBLE DRILLING CO. NORDIC 1 Start: 7/1/2002 Rig Release: 7/8/2002 Rig Number: Spud Date: 4/23/1979 End: 7/9/2002 Date From - To Hours Task Code NPT Phase Description of Operations 7/8/2002 17:45 - 18:00 0.25 PERF P COMP Remove guns from pipe shed and clear rig floor of perf equipment. 18:00 - 18:35 0.58 PERF N WAIT COMP Tech Limit meeting in toolpusher shack and crew change. Crew changes seem to be taking much longer now that SWS CTU crews are living at Deadhorse SWS camp instead of BOC. Tech limits meetings on the rig floor are not the most productive. While the BP Co. Reps enthusiastically endorse Tech limits meetings, they should take place before crew change, and in a local seperate from the rig. 18:35 - 19:00 0.42 PERF P COMP Rig down SWS perf guns out of pipe shed. 19:00 - 19:25 0.42 RIGD P COMP PU injector with nozzle. 19:25 - 20:30 1.08 RIGD P COMP RIH with nozzle to FP well. Can't get thru tree, PU stingers. 20:30 - 20:45 0.25 RIGD P COMP POH from 2000', laying in neat methanol at 50%. 20:45 - 21 :00 0.25 RIGD P COMP Tag up at surface, finish displacing methanol from coil. Begin rig down. 21 :00 - 22:10 1.17 RIGD P COMP Blow down reel with air. Got 7 bbls of water out of reel. 22:10 - 22:30 0.33 RIGD P COMP Cut coil, unstab from injector, pull back on reel, prepare reel to be pulled for summer shutdown maintenance. 22:30 - 22:50 0.33 RIGD P COMP Safety meeting prior to unstabbing coil from injector. 22:50 - 00:00 1.17 RIGD P COMP Unstab coil, secure reel prior to pulling for summer shutdown maintenance. Rig release 23:00 hrs on 7-8-2002. 7/9/2002 00:00 - 01 :00 1,00 RIGD COMP Rig down gooseneck, stab injector in stabbing box. 01 :00 - 02:30 1.50 RIGD COMP Nipple down stack, nipple up swab cap. PT, ok. 02:30 - 03:30 1.00 RIGD COMP Prep for move to side of OS 7 for summer maintenance shutdown. 03:30 - 04:00 0.50 MOB PRE Safety meeting prior to moving rig off well. 04:00 - 05:00 1.00 MOB PRE Prep to move off well. 05:00 - 06:00 1.00 MOB PRE Move off OS 7-13, position rig to off side of OS 7, begin summer maintenance. Printed: 7/10/2002 12:24:04 PM ) AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definitive Re: Distribution of Survey Data for Well 7-138 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,321.00' MD Window / Kickoff Survey 11,345.00 I MD (if applicable) Projected Survey: 12,960.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager AUachment( s) Qt0a-lllo 11-Aug-02 RECEIVED I~ r 1('.- 'I " 2002 f . ,.,' ',.7 I '.. ;.jaSKë' )1, "~"~ '.,jon~ vommlSSior ,) n,"'rll"\ragt OJI:: 1:-:' tfTH:E North Slope Alaska BPXA PBU_EOA DS 07, Slot 07-13 07-13 - 7-13B Job No. AKMW22110, Surveyed: 6 July, 2002 -~' SUR VE Y R EP 0 R T 11 August, 2002 Your Ref: API 500292033802 Surface Coordinates: 5950290.00 N, 675896.86 E (700 16'11.2832" H, 148034' 38.6939" W) Kelly Bushing: 52. 26ft above Mean Sea Level SpE!i....-Y-SLJI! DRILLING SeRVices A Halliburton Company Survey Ref: svy11266 Sperry-Sun Drilling Services . Survey Report for 07-13 - 7-138 Your Ref: API 500292033802 Job No. AKMW22110, Surveyed: 6 July, 2002 BPXA North Slope Alaska PBU_EOA DS 07 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Nòrthlngs Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) r/100ft) 11321.00 46,600 353.700 8808.52 8860.78 4440.25 N 3863.22 W 5954638.75 N 671930.93 E 1619.84 Tie On Point 11345.00 49.155 354.092 8824.62 8876.88 4457.94 N 3865.11 W 5954656.40 N 671928.62 E 10.713 1633.66 Window Point 11379.80 56.510 2.100 8845.65 8897.91 4485.61 N 3865.94 W 5954684.04 N 671927.15 E 27.956 1656.40 11407.46 59.770 7.930 8860.26 8912.52 4508.99 N 3863.87 W 5954707.46 N 671928.68 E 21.427 1677.14 11443,53 62.490 14.980 8877.69 8929.95 4539.91 N 3857.57 W 5954738.52 N 671934.24 E 18.699 1706.50 "---- 11472.31 63.810 20.010 8890.69 8942.95 4564.38 N 3849.85 W 5954763.17 N 671941.39 E 16.252 1731.24 11521.77 68,030 33.020 8910.94 8963.20 4604.63 N 3829.68 W 5954803.87 N 671960.62 E 25.469 1775.97 11555.42 72.860 44.800 8922.23 8974.49 4629.21 N 3809.77 W 5954828.91 N 671979.94 E 35.957 1807.43 11594.85 72.860 52.530 8933.87 8986.13 4654.07 N 3781.51 W 5954854.43 N 672007.62 E 18.732 1843.68 11640.02 77.420 63.410 8945.48 8997.74 4677.15 N 3744.54 W 5954878.36 N 672044.04 E 25.367 1883.16 11673.22 79.980 74.150 8952.01 9004.27 4688.90 N 3714.24 W 5954890.82 N 672074.06 E 32.641 1909.52 11722.10 83.910 82.450 8958.87 9011 . 13 4698.69 N 3666.90 W 5954901.71 N 672121.16 E 18.633 1943.51 11752.29 90.370 82.820 8960.37 9012.63 4702.55 N 3637.01 W 5954906.27 N 672150.95 E 21.433 1963.03 11807.35 90.150 82.490 8960.12 9012.38 4709.59 N 3582.40 W 5954914.58 N 672205.37 E 0.720 1998.68 11854.10 88.990 76.910 8960.47 9012.73 4717.94 N 3536.43 W 5954924.01 N 672251.14 E 12.190 2030.72 11887.48 90.750 71.980 8960.55 9012.81 4726.89 N 3504.28 W 5954933.71 N 672283.07 E 15.682 2055.74 11918.50 90.480 67.930 8960.22 9012.48 4737.52 N 3475.15 W 5954945.01 N 672311.95 E 13.084 2080,52 11952.77 88.460 61.940 8960.53 9012.79 4752.03 N 3444.12 W 5954960.24 N 672342.63 E 18.444 2109.59 11985.52 88.900 59.470 8961.29 9013.55 4768.05 N 3415.57 W 5954976.93 N 672370.80 E 7.659 2138.57 12021.45 90.220 54.180 8961.57 9013.83 4787.70 N 3385.51 W 5954997.28 N 672400.39 E 15.174 2171.43 12056.87 90.130 49.950 8961.46 9013.72 4809.47 N 3357.58 W 5955019.69 N 672427.80 E 11.945 2204,89 '~ 12086.87 89.960 45.730 8961.43 9013.69 4829.60 N 3335.35 W 5955040.34 N 672449.56 E 14.078 2233.89 12124.02 91,370 39.730 8961.00 9013.26 4856.88 N 3310.15W 5955068.19 N 672474.11 E 16.589 2270.48 12156.25 93.480 36.390 8959.64 9011.90 4882.23 N 3290.30 W 5955094.00 N 672493.36 E 12.249 2302.55 12188,25 94.980 33.570 8957.28 9009.54 4908.37 N 3272.01 W 5955120.56 N 672511.04 E 9.960 2334.44 12231.50 92,160 30.570 8954.58 9006.84 4944.94 N 3249.10 W 5955157.66 N 672533.09 E 9.510 2377.59 12266.72 90.130 23.350 8953.88 9006.14 4976.31 N 3233.14 W 5955189.39 N 672548.30 E 21.290 2412.59 12309.60 90.400 17.880 8953.68 9005.94 5016.43 N 3218.05 W 5955229.85 N 672562.45 E 12.772 2454.45 12342.10 90,310 13.830 8953.48 9005.74 5047.68 N 3209.18 W 5955261.31 N 672570.60 E 12.464 2485.50 12377.85 90,660 10.480 8953.18 9005.44 5082.62 N 3201.65 W 5955296.41 N 672577.31 E 9.421 2518,90 --._----------- ---- --- - 11 August, 2002 - 21:45 Page 20f4 DrillQ( est 2.00.09.003 Sperry-Sun Drilling Services . Survey Report for 07-13 - 7-138 Your Ref: API 500292033802 Job No. AKMW22110, Surveyed: 6 July, 2002 BPXA North Slope Alaska PBU_EOA DS 07 Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northlngs Eastlngs Northlngs Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/1 OOft) 12406.64 90.480 4.670 8952.89 9005.15 5111.15N 3197.86 W 5955325.02 N 672580.43 E 20.189 2544.89 12440.04 90.750 0.620 8952.53 9004.79 5144.50 N 3196.32 W 5955358.40 N 672581.19 E 12.152 2573.71 12475.60 94.360 356.210 8950.95 9003.21 5180.00 N 3197.30 W 5955393.87 N 672579.38 E 16.016 2602.94 12505.79 93.040 356.030 8949.00 9001.26 5210.06 N 3199.33 W 5955423.87 N 672576.64 E 4.413 2627.04 12537.77 86.610 356.210 8949.09 9001.35 5241.95 N 3201.50 W 5955455.70 N 672573.74 E 20.114 2652.61 -~' 12574.16 86.260 351.280 8951.36 9003.62 5278.04 N 3205.45 W 5955491.69 N 672568.94 E 13.556 2680.72 12604.70 85.640 348.100 8953.52 9005.78 5308.01 N 3210.90 W 5955521.52 N 672562.79 E 10.583 2702.89 12635.93 86.340 345.110 8955.70 9007.96 5338.31 N 3218.12W 5955551.65 N 672554.86 E 9.810 2724.37 12674.08 89.430 348.630 8957.11 9009.37 5375.43 N 3226.78 W 5955588.55 N 672545.34 E 12.272 2750.78 12715.85 89.250 352.330 8957.59 9009.85 5416.61 N 3233.68 W 5955629.56 N 672537.48 E 8.868 2781.56 12750.03 90. 130 357.800 8957.78 9010.04 5450.65 N 3236.62 W 5955663.52 N 672533.74 E 16.209 2808.51 12779.39 90.840 0.260 8957.53 9009.79 5480.00 N 3237.12W 5955692.86 N 672532.56 E 8.720 2832.86 12806,17 91.280 3.080 8957.03 9009.29 5506.77 N 3236.34 W 5955719.63 N 672532.71 E 10.656 2855.73 12854.50 94.890 8.190 8954.43 9006.69 5554.77 N 3231.61 W 5955767.73 N 672536.32 E 12.931 2898.56 12886.77 96.480 12.770 8951.23 9003.49 5586.33 N 3225.77 W 5955799.42 N 672541.42 E 14.957 2928.21 12922.98 96.920 16.300 8947.01 8999.27 5621.14 N 3216.75 W 5955834.43 N 672549.63 E 9.758 2962.32 12960.00 96.920 16.300 8942.54 8994.80 5656.41 N 3206.43 W 5955869.94 N 672559.12 E 0.000 2997.52 Projected Survey All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative to Well. The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from Well and calculated along an Azimuth of 33.000° (True). "~/ Based upon Minimum Curvature type calculations, at a Measured Depth of 12960.000., The Bottom Hole Displacement is 6502.02ft., in the Direction of 330.453° (True). ---. .----------------- 11 August, 2002 - 21 :45 Page 30f4 DrillQuest 2.00.09.003 North Slope Alaska Comments Measured Depth (ft) 11321.00 11345.00 12960.00 Sperry-Sun Drilling Services Survey Report for 07-13 - 7-138 Your Ref: API 500292033802 Job No. AKMW22110, Surveyed: 6 July, 2002 Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 8860.78 8876.88 8994.80 4440.25 N 4457.94 N 5656.41 N Survey tool program for 07-13 - 7-138 From Measured Vertical Depth Depth (ft) (ft) 0.00 11 August, 2002 - 21:45 To Measured Vertical Depth Depth (ft) (ft) Comment 3863.22 W 3865.11 W 3206.43 W Tie On Point Window Point Projected Survey Survey Tool Description 0.00 12960.00 8994.80 MWD Magnetic (7-138) - - --------~----- Page 4 0'4 . BPXA PBU_EOA DS 07 ---' ---- ----~----- DrillQuest 2.00.09.003 ) ~~fÆ~~=} !Æ~!Æ~~~!Æ / AI~ASKA. OIL AND GAS / CONSERVATION COMMISSION / TONY KNOWLES, GOVERNOR 333 W. PH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit 07-13B BP Exploration (Alaska), Inc. Permit No: 202-116 Surface Location: 628' SNL, 290' WEL, Sec. 33, TIIN, RI4E, UM Bottomhole Location: 4755' NSL, 3523' WEL, Sec. 28, TIIN, RI4E, UM Dear Ms. Sherwood: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Ûv~.~.~'~ Cammy <ðechsli Taylo;- ð- Chair BY ORDER 011 THE COMMISSION DATED thisJpll day of June, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALAS\ " STATE OF ALASKA )OIL AND GAS CONSERVATION CO. -)ISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well [J Exploratory [J Stratigraphic Test II Development Oil [J Service [J Development Gas [J Single Zone [J Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 52.26' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028309 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number , 07-138 ./ 9. Approximate spud date 06/17/02 f Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 12650' MD 189451 TVDss /'0 17. Anticipated pressure {~e 20 AAC 25.035 (e) (2)} 95 Maximum surface 2194 psig, At total depth (TVD) 88001 I 3250 psig Setting Depth Too Bottom Quantity of Cement Lenath MD TVD MD TVD (include staae data) 1550' 111001 8695' 12650' 89451 64 sx Class 'G' ~ WJ 6/\-' tvi t/ /p <L h-~ I~ -a~~ 1 a. Type of work [J Drill II Redrill [J Re-Entry [J Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 6281 SNL, 2901 WEL, SEC. 33, T11 N, R14E, UM At top of productive interval 3489' NSL, 4112' WEL, SEC. 28, T11 N, R14E, UM At total depth 4755' NSL, 3523' WEL, SEC. 28, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well ,/ ADL 028306,525' MD No Close Approach' 16. To be completed for deviated wells Kick Off Depth 113501 MD Maximum Hole Angle 18. Casin~ Program Specifications Size Hole Casina Weight Grade Couolina 3-3/4" 3-3/16" x 2-7/8" 8,81#/6.16# L-80 ST-L 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner Scab Liner Slotted Liner 12458 feet 8991 feet 12434 feet 8991 feet Length Plugs (measured) ~ULt ~".. 1;1"" W:.: f¡ r 1~ ;j' "r:;-t' ':} F Junk (measured) Size 1081 20" 2760' 13-3/8" 100051 9-5/8" 18961 7" 2041 7-5/8" 873' 4-1/2" 243 sx Arcticset 5600 sx Arcticset II Cemented MD Alaska Oil d,i: (:Ii;;. :'. ;,;¡m¡W¡Mj¡U~ Anchoragt;08' 2760' TVD 1081 27281 1400 sx Class IG' 500 sx Class 'G' Not Cemented Uncemented Slotted Liner 10005' 7841' 97961 - 11692' 7675' - 8994' 2312' - 25161 2309' - 25041 11585'-12458' 8981'- 89911 Perforation depth: measured Slotted Liner: 11685' - 12435' Squeezed: 11239' - 11244', 11478' - 11498' true vertical Slotted Liner: 89931 - 8991' Squeezed: 8802' - 8805', 8949' - 8957' II Filing Fee [J Property Plat II BOP Sketch II Drilling Fluid Program [J Time vs Depth Plot [J Refraction Analysis [J Diverter Sketch II Drilling Program [J Seabed Report [J 20 AAC 25.050 Requirements 20. Attachments Contact Engineer Name/Number: Alistair Sherwood, 564-4378 21. I hereby certify that the fO":¡JfrJ-. is 4:ue and co~rect to tho e bes. t 0, f. m.y, k. ,n,~,w.. led,g., e . Signed Alistair Sherwood ~(""-L-'ifi..;t~. Title CT Dnlllng Engineer .. Commission Use Only '. Permit Number API Number ~ppÞOval (j~o/J See cover letter 202-- //h 50- 029-20338-02 L2 U U:I\ for other requirements Conditions of Approval: Samples Required 0 Yes 111 No Mud Log ReqUlre:i 0 Yes EI No Hydrogen Sulfide Measures a Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: \ ~aISlgrjcfb) {.o '5 S DO r' Ç,: . Cammy Qechsli T aylol Prepared By Name/Number: Terrie Hubble, 564-4628 Date 5~z., . Approved By Form 10-401 Rev. 12-01-85 by order of 0' ~,. ". f, }.~.. iqn~r i. ',J; J the commission ¡ ~< I ,.~ ~ ~,~ t \ .. ""' ~ \, ~ l:,.) ~ ~ \3 t" f..... DateU U~r] Submit 1~4r~l~ate ) BPX 7 -13b CrD Sidetrack ') Summary of Operations: A CTD ¡sidetrack of production well 7 -13a will be drilled. Specific prep work, (Phase 1) and drilling operations, (Phase 2) are detailed below. Prep will begin June 10th, drilling is scheduled to begin June 17th, 2002. Phase 1: Screen & Prep Well: Screen - MIT-IA. PPPOT-tbg hanger seals. MIT-OA and pressure test tree valves. . Mill Camco 3.5" DB nipple to 3.80" . Drift with a BHA representative of the subsequent CIBP & WS runs . Run & set cast iron bridge plug, (CIBP) at top of 4Y2" slotted liner . Run & set 4¥2"x7"thru/bg whipstock in 7" liner below the tailpipe . Downsqueeze 15bbls cement to P&A perfs below WS and behind a straddle in the upper completion Phase 2: Drill and Complete CrD sidetrack / 2%" coil will be used to drill a -1300ft, 3%" open hole sidetrack, (as per attached plan) from a window cut through 7" liner. The sidetrack will be completed with 1 ,550ft of solid, cemented & perforated, 33/16" x 2Ys" liner. Mud Program: . Phase 1: Seawater . Phase 2: Seawater and Flo-Pro (8.6ppg).I'''' Disposal: . No annular injection on this well. . All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. . All Class I wastes will go to Pad 3 for disposal. Casing Program: . 33/16" X 2Ys", L-80, liner will be run from 11,100' md ~695' TVDss) to TD at 12,650'. The completion will be cemented in place with approximately 13 bbls (annular volume +400/0 excess in OH) of 15.8 ppg class G latex cement. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 300 psi and to 3,500 psi. . The annular preventer will be tested to 400 psi and 2,200 psi. Directional . See attached directional plan. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging / . Real time MWD & Gamma Ray logs will be run while drilling the open hole section. / . A memory CNUGR/CCL will be run inside the 33116" x 2Ys" liner prior to perforating. Hazards / . H2S was last sampled at 23ppm on 2/23/01. . The sidetrack will be drilled through an area with a moderate risk of lost circulation. It will also cross a 30' throw fault perpendicularly adding additional risk. If losses are expriencd they will be dealt with appropriately. Reservoir Pressure Reservoir pressure is estimatyd to be 3,250 psi at 8,800ss. Maximum surface pressure with gas (0.12 psi/ft) to surface is 2,194 psi. TREE = GRA Y GEN 2 WELLHEAD = FMC Aë:;fûÄfoR;" 'ÄXELSÒN ká' ËlË\T;;'" ","d. ""W'54; i3F~8..ËV '~ ' ? KOP= 2190' ~~~'~;:'.,'...9.'~.~',r~'~~t-: I TOP OF 7-5/8" LNR 1-1 2312' ~ oafùïTîW b '~. "'''''àãöÖi'ss ) 7-5/8" LNR-SCAB, 47#, L-80, --I 2516' 0.0459 bpf, 10 = 6.875" \13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2760' I TOP OF 7" LNR 1-1 9796' 1 I TOP OF CEMENT 1-1 9798' 1 19-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10005' Minimum ID = 3.5" @ 11282' 4..1/2" DB NIPPLE 17" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" 1-1 10970' 1 I TOP OF 7" LNR 1-1 10970' 1 I EZSV 1-1 1021 0' ~ 14-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 11038' I TOP OF 4-1/2" TBG 1-1 11038' 07 -13A ') I SAFETY NOTES ~ H4-1/2" CAMeo TRDP-4A SSSV NIP, ID = 3.812" 1 H 7-5/8" CPH LNR PKR, 10 = 6.875" 1 H7-5/8" HY-FLO 3D HGR/PKR, ID = 6.75" 1 GAS LIFT MANDRELS TVD DEV TYPE VLV LATCH PORT DATE 4089 46 KBMG-M BK-5 6147 51 KBMG-M BK-5 7613 36 KBMG-M BK-5 PRODUCTION MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 11173 8752 41 KBMG-M DV BEK-3 0 04/28/95 5 11199 8772 41 KBMG-M DV BEK-3 0 04/28/95 I 2059' ~ 2312' ~ I 2516' ~ ST MD ~ 1 4487 2 7665 3 9719 L II MILLOUT WINDOW: 10005' I 10983' l-t 4-1/2" OTIS X NIP, ID = 3.813" 1 11034' 1-1 7" x 4-1/2" BAKER SABL-3 PKR, 10 = 3.83" 1 I 11216' 1-1 4-1/2" BLAST RINGS (38.83') 1 11267' l-t 7" x 4-1/2" BAKER SABL-3 PKR, ID = 3.83" 1 11282' H 4-1/2" CAMCO DB NIP, 10 = 3.5" 1 11287' 1-1 4-1/2" TUBING TAIL WLEG 1 1-1 ELMO TT NOT LOGGED 1 14-1/2" TBG, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.958" 1-1 11287' 1 I TOP OF 4-1/2" LNR 1-1 11585' 1 11585' 1-1 7" x 4-1/2" TIW SS PKR 1 ~ 11646' r 4-1/2" PORTED PIPE, ID = 5.992" I 12430' 1-1 CA-BKFS-BEK-3 1 TOPOF 4-1/2" LNR- SLTD 1-1 11685' 1 14-1/2" LNR, 12.6#, 13CR-80, 0.0152 bpf, 10 = 3.958" 1-1 11685' 1 17" LNR, 29#, 13CR, 0.0371 bpf, 10 = 6.184" 1-1 11692' TOPOF 4-1/2" LNR 1-1 12435' 1 14-1/2" LNR-SL TD, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.958" H 12435' 1 PERFORA TION SUMMARY REF LOG: A WS BHCA ON 09/13/94 ANGLE AT TOP PERF: 41 @ 11239' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4" 2 11239-11244 S 09/20/94 2-7/8" 6 11478-11486 S 08/15/96 2-1/2" 2 11486-11496 S 06/02/96 2-7/8" 8 11486-11496 S 08/15/96 2-7/8" 6 11496-11498 S 08/15/96 4" 32 11685-12435 0 09/20/94 I PBTD 1-1 14-1/2" LNR, 12.6#, 13CR-80, 0.0152 bpf, 10 = 3.958" 1-1 12458' 1 DATE 05/13/79 09/27/94 12/13/00 02/09/01 09/22/01 REV BY DA TE REV BY COMMENTS PRUDHOE BAY UNIT WB...L: 07-13A PERMIT No: 94-1030 API No: 50-029-20338-01 SEC 33, TUN, R14E 4194.64 FEl. 368.02 FNL BP Exploration (Alaska) SIS-MD SIS-LG RNITP COMMENTS ORIGINAL COMA..ETION SIDETRA CK CONVERTED TO CANVAS REVISION CORRECTIONS TREE = WELLHEAD = 'AciÜATOR; ",., 'RB'.^EL§];;"" ".' ............... ....." ................ BF. ELEV = KOP= \,,,,,,,,,,,,....,,,,,,,,,,, "..",.."........" Max Angle = ""',.".,,......... ... ......, ....", Datum MD = 'oatUml\i6;" , GRAYGEN2 FMC "AX'ELSÖN '", ,., ""sLF ? 2190' ...., 9.~ @).~.f~!.!i' 1 TOP OF 7-5/8" LNR 1-1 11311' "''''áäóõí'ss 7-5/8" LNR-SCAB, 47#, L-80, -I 0.0459 bpf, ID = 6.875" ) 07-138 ) SAFETY NOTES J----x I 2059' H4-1/2" CAMeo TRDP-4A SSSV NIP, 10 = 3.812" 1 2312' ~ 2312' H 7-5/8" CPH LNR PKR, 10 = 6.875" 1 5< ~ 1 2516' H7-5/8" HY-FLO 3D HGR/PKR, 10 = 6.75" 1 2516' 113-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1 2760' 1 TOP OF 7" L-80 LNR 1-1 9796' I TOP OF CEMENT 1-1 9798' 19-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1 10005' I EZSV 1-1 10210' 17" LNR, 29#, L-80, 0.0371 bpf, 10 = 6.184" 1-1 10970' I I TOP OF 7" 13CR LNR 1-1 10970' 1 4-1/2" TBG, 12.6#, L-80, 0.0152 bpf, 10 = 3.958" 1-1 11038' 1 I TOP OF 4-1/2" TBG 1-1 11038' 1 4-1/2" TBG, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.958" 1-1 11287' 1 ÆRFORA TION SUMMARY REF LOG: A WS BHCA ON 09/13/94 ANGLEATTOPÆRF: 41 @ 11239' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4" 2 11239-11244 S 09/20/94 2-7/8" 6 11478-11486 S 08/15/96 2-1/2" 2 11486-11496 S 06/02/96 2-7/8" 8 11486-11496 S 08/15/96 2-7/8" 6 11496-11498 S 08/15/96 4" 32 11685-12435 isolated proposed I TOP OF 4-1/2" LNR 1-1 11585' 17" LNR, 29#, 13CR, 0.0371 bpf, ID = 6.184" 1-1 11692' 1 TOP OF 4-1/2" LNR - SL TO 1-1 11685' Proposed CTD Sidetrack ~ ~ L "'- ST ."'- 1 ~ ~ ST MD lVD 4 11173 8752 5 11199 8772 .. MD lVD 4487 4089 7665 6147 9719 7613 I )< GAS LIFT MANDRELS DEV TYÆ VLV LATCH 46 KBMG-M BK-5 51 KBMG-M BK-5 36 KBMG-M BK-5 PRODUCTION MA NDRELS DEV TYÆ VLV LATCH 41 KBMG-M DV BEK-3 41 KBMG-M DV BEK-3 PORT DATE PORT DATE 0 04/28/95 0 04/28/95 MILLOUT WINDOW: 10005' I 1 I ~ ~ 10983' 1-1 11034' 1-1 11100' - 11100' - 4-1/2" OTIS X NIP, ID = 3.813" 1 7" X 4-1/2" BAKER SABL-3 PKR, ID = 3.83" 1 3-3/16" liner top 1 Cement top 1 "",. I 11216' 1-1 4-1/2" BLAST RINGS (38.83') 1 11267' 1-17" X 4-1/2" BAKER SABL-3 PKR, 10 = 3.83" 1 11282' H 4-1/2" CAMeO DB NIP, (Milled to 3.8") 1 11287' - 4-1/2" TUBING TAIL WLEG 1 - ELMD IT NOT LOGGED 1 11400'1-13-3/16" X 2-7/8" XO I.,/' 12-7/8" Liner, Cemented & Perf'd 1-112650' ",.- 13-3/4" Hole In,,, "J'."":::"""'I 11350' 1-1 Mechanical Whipstock 1 /' 11585' 1-1 7" X 4-1/2" Tm SS PKR 1 11600' 1-1 Bridge plug 1 11646' r 4-1/2" PORTED PtÆ, 10 = 5.992" .. 4-1/2" LNR-SL TO, 12.6#, 13CR-80, 0.0152 bpf, ID = 3.958" H 12435' 1 DATE 05/13/79 09/27/94 12/13/00 02/09/01 09/22/01 REV BY SIS-MD SIS-LG RNITP COMMENTS ORIGINAL COMA-ErION SIDETRACK CONVERTED TO CANVAS REV ISION CORRECTIONS DA TE REV BY 1-1 CA-BKFS-BEK-3 1 COMMENTS 4-1/2" LNR, 12.6#, 13CR-80, 0.0152 bpf, 10 = 3.958" 1-1 12458' 1 PRUDHOE BAY UNrr WELL: 07-13A ÆRMrr No: 94-1030 API No: 50-029-20338-01 SEC33. TIIN, R14E 4194.64 FEL 368.02 FNL BP Exploration (Alaska) BP Amoco WlLLPATH HTAlLS ,..... 07-U. 1002t20U102 ,..,...1 Weapatll: Tie o. MD ~~;1ll:oo Nontk: 1 221138/111"" 00100 IU" Ref, Dat8wu v.s= ~1t: ~m; DAD ::::~ O.DO REFERENCE INFORMATION Co-ordinate (NÆ¡ Reference: Wetl Centre: 07-13, True North v=~ ~:::=: w~~ro~~~)et Measured Depth Reference: 22: 139/8/1994 00:00 52,26 Calculation Method: Minimum CUlVature aKT10N DnA'" liD ... ! UiSã i~ä !iJï 5* a 1 tY02.lI ~.OO .7.ao 88-'" ! ~æt::: =:: '::: =~ . 12807.14 10.00 18.&8 .......71 10 12810.00 10.00 1UI .......13 +a1-W DL.. TFace VS8c TWin 4440.28 -3&U20 0.00 0.00 181.... 4481.7. -»8&48 10.72 8.82 1838.85 4.477.oe..-...." 8.00 4&00 1848.7. ~ 5: :i: 28:t~ 5: 4781.0. aa.)"'~ 14.00 U8.10 2181.03 &141.13 ~211.88 14.00 no.oo 25U.11 042.71 42...,' 14.00 80.00 27Ø1.J.J 5J,U..51 .U4&.n 14.00 ..00 2747.83 ANNOTATIONS TVD liD "..bltIo8 HO..II 11U1.oo TIP ..27.17 11SSO.oo KOP _.I' 11S70.oo 1 "".11 11_.00 2 ....M 11712.1' . ''''.77 11102.1' . ......71 U007", . ''''''71 1_7'" . ''''''71 UH7... 7 ......71 U.IO.oo TO TW t'N/-S +EJ..W 5/'wpe 07,'3Ø~1 000 04-$3908 -329105 Pdygon 2~:i¡fff' =~ ~-~ i!-~ 5r' g~:~=f:~ =~ lli~~ ~~ = ---.---- 8300 8350 8400 8450 - - .5 8500 j; 8550 - II) - ': .c 8600 .. Do - . 8650 Q D 8700 1: 8750 \ . -, > 8800 . e 8850 to- \ \ \ \ ~ ",I .ŒQf] "\:~ C,JIJ. ~~. \ \ ì , \ \ i =..'~~---~~- 8950 ' 8900 9000 \ \ i \ \ ~07~¡}:@7-:-~l \ 9050 ObP ..i~~~ LEGEND - 07-10A(07-10A) - - 07-13 (07-13) 07-13 (07-13A) - 07-28 (07-28A) - Plan#6 07-13B - Plan #6 T ^M é Direct: (907) 267-6613 E-mail: brii.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 li~TEQ 7000-::----- 6800-- - Azimuths to True North Plan: Plan #6 (07-131Plan#6 07-13B) Magnetic North: 26.40. Created By: Brij Potnis Date: 5/2/2002 Magnetic Field Contact Information: Strength: 57509nT Dip Angle: 80,80. Date: 5/1/2002 Model: BGGM2001 , . , . ~,,~~". .~~......-:! ',..... ,- j 07-28 (07-28A):::"='="'" --~ ------,-- ----- --- --- - ------------------ --- ------------ -----------~- -~~--- , -- - - ----- - ----~~~ :=~-=-=-- , - ì - -- ----:t , m ,~ . ,"~~!-""M("~'""",\ -C~C-L~C-~- =~!' _"~'m~ Ie /'~ ~ - --~ '-'~--'-'-"- - ~¡F\-~-~=~'-- ~ ~~ ----t --- ~\ ~ \ - \ - \\ .\ .'.-,'-,,-. ,.,' ~ -. -=- ,-. .--= --~ - -- --- \ --- -. - . \- ~- \-- ---_u_,- \ --- -,---\ \ .. \ -. v_m_n\.-~_- ~-.l \ -~- ~__l_~-- -- -- - ,-- - 66~--- --- ----"-- 62C>O--= --- - - -- -6(){)()---- C : æ 5800 ::----- !~~-~--, - - +54~--=- ~ =--,-- 1:: 5200-=:-- ~ 0 - ~ 5000~ - I ~ 4800-=-=--:- .. .- :I -,- --- 04600--==:- -- en -- 4400-.::---- - - - --- 4200---:.--------- 4000 - -------- ------ 38C>O--= - - - 3600......--' ,- ¡ 07-13B T6,2! -6000 -5800 -5600 -5400 -5200 -5000 -4800 -4600 -4400 -4200 -4000 -3800 -3600 -3400 -3200 -3000 -2800 -2600 -2400 -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 West(-)/East(+) [100ft/in] .~ ----- - ------"- -- - - -j 0!,:1~ (07-13_AH -.-- i - ------1. - '6l ir ----=:; 07-10A (07-10A)¡::; --- ----- ---- :3[- ~ ,- ( -~~~T6,1: ~-, ~ 07-13~62~- - --1 Plan#6 07-13BI ffm--- - ----- "-- -f\.\ i 07-13B T6.31 l, '¡ 07-13B T6,4i --~----- 1400 1450 1500 1550 1600 1650 1700 1750 1800 1850 1900 1950 2000 2050 2100 2150 2200 2250 2300 2350 2400 2450 2500 2550 2600 2650 2700 2750 2800 2850 2900 2950 3000 3050 3100 3150 3200 3250 3300 Vertical Section at 33.00D [50ft/in] 5/2/2002 10:5-1 AM BP Baker Hughes INTEQ Planning Report :G,',.:!,..::..',b......P' I .:!II:." 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" , -~.:=::::::::::.::-~ ,,1,,1 Prudhoe 8ay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Field: P8 OS 07 TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Site: 5948144.78 ft 677382.28 ft '~-'-'-'-"--'.'-""--'--------"--_._-,---~-,-,-,-,,,- 07-13 07-13 Well Position: Well: Map Zone: Coordinate System: Geomagnetic Model: Latitude: Longitude: North Reference: Grid Convergence: Slot Name: +N/-S 2179.76 ft Northing: 5950290.00 ft Latitude: +E/-W -1434.56 ft Easting: 675896.86 ft Longitude: Position Uncertainty: 0.00 ft --""'--'-"---'-'-'-"'---'-----"-'--'--'-"--'--"_W-------- ~.._---_._.._------_.._.._._---- Wellpath: Plan#6 07-138 500292033802 Current Datum: 22 : 13 9/8/1994 00:00 Magnetic Data: 5/1/2002 Field Strength: 57509 nT Vertical Section: Depth From (TVD) ft 0.00 Height 52.26 ft +N/-S ft 0.00 -'--'--'-----'-' -----~---- -'-'-"--'---~--,."",_._--- Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Alaska, Zone 4 Well Centre 8GGM2001 70 15 49.847 N 148 33 56.934 W True 1.35 deg 13 70 16 11.283 N 148 34 38.694 W .--.,.,.-.,.-..-..--..-- 07-13A 11321.00 ft Mean Sea Level 26.40 deg 80.80 deg Direction deg 33.00 ----"---.---.....,------------------------ Targets '-:;ë:;-':''";''\,:",~~~'--''''''''r--:--:''''r'''''''--;::-,,""'r'~'''T''-''''''''-'''~:-~''''-'T-:-'-.~~~ I," " I ,I I I I I I II I . "(""",,':.,',, """:',,;,' ... ,DeS~~i~tio~"i .. ': .,,' :Di~: ',', ,,»i... 07-138 Polygon5.1 -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 07-138 Fault 1 -Polygon 1 -Polygon 2 I I I I , :::1 :,',.' .~~~;,;" :"1, I,":" ,I,:; i.':I,:,,:'::,,:iI.~'i.' (..::: ,Ii;:; 1':"':'11':'1 ,I'" ' L..;',: I ,'1"" ¡I,.,:",' 1'::1 j,. I: "7ÇTI~:;~~~~~;.';-~;~~~~.';~-:;~--'~~'~~ , ,,'" ",,'," !I"::' ,', :', ";",':':I"~,....R""':'::"".d" """''''','~''':.''~''&,. ". :DI:'.r"'.:.:""'''':''','~~~atMl. ~e:'~., . ,~.'.::' :'~."".,I'lWon2.,~,'. ue,.,:",,",,>,'.,". 'tEi~~,' ,: I...: '.,N~II~"ili~I'::I,,'::'E¡$t~gil, I,: '.,"'D~" Migl' "ISet":::, :'":.,':,))eg':MiI1~,,Seç , ; ':, . . 1,;I,lfti::<' 'i',ft,,I,:;;,:,,,:!t3_L~~:,~_,..';::,:,.'i,'~:~~~'..'" 'i',':'" ", ".' ': , " "'1,:,,/,111 " ""T~"!' ",', \. .~f~S::',;,', '.#, ,._~~~ ..ft. :'.', 0.00 4539.08 0.00 4539.08 0.00 4582.00 0.00 5686.48 0.00 5692.37 -3291.05 -3291.05 -2989.94 -3163.98 -3413.92 0.00 5551.54 -4017.45 0.00 5551.54 -4017.45 0.00 4487.81 -3662.39 8945.00 4938.50 -3287.56 07-138 T6.3 07-138 T6.4 8945.00 5637.77 -3246.21 07-138 T6.2 07-138 T6.1 8950.00 4718.52 -3476.89 8960.00 4672.32 -3668.91 _.~ --'---- . -~,.- _..,--~-_._,-~, '~'--, ---~,,------ ~ --_.~.---- ------------ 5954750.64 672500.85 70 16 55.918 N 148 36 14.555 W 5954750.64 672500.85 70 16 55.918 N 148 36 14.555 W 5954800.58 672800.85 70 16 56.341 N 148 36 5.785 W 5955900.62 672601.06 70 17 7.203 N 148 36 10.868 W 5955900.67 672351.07 70 17 7.260 N 148 36 18.149 W 5955745.78 671751.04 70 17 5.872 N 148 36 35.729 W 5955745.78 671751.04 70 17 5.872 N 148 36 35.729 W 5954690.71 672130.84 70 16 55.412 N 148 36 25.370 W 5955150.00 672495.00 70 16 59.846 N 148 36 14.458 W 5955850.00 672520.00 70 17 6.724 N 148 36 13.262 W 5954925.68 672310.88 70 16 57.682 N 148 36 19.970 W 5954875.00 672120.00 70 16 57.227 N 148 36 25.563 W ------,--_._--,~~--------,----"._,-------"--_.._--~---'--~.__._-,------ ,,----------------- - .--------.---.- "-- --.--,.- Annotation ,_.._--------"------,_.__._."-----_._"--_.._.~----_._..-- I MD TVD ! ft ft 1..._-_----------- I 11321.00 8808.52 ,11350.00 8827.87 '11370.00 8840.63 r 11420.00 8869.81 11702.18 8959.48 11902.18 8949.77 '12007.54 8944.73 12407.54 8944.73 12607.54 8944.73 --------- --------------~--'_._----~.--------_._--_._._-----'.'-~~--" ,--_._,-_._,-,,-,--'.._--- ."--"------- ~ -.,'- TIP KOP 1 2 3 4 5 6 7 '- ._--------"----- --.----- ----------- _._----,~-- -- -------------"._-~-- -,_. ,-,~-----_._----- .'---'---- "--.-,--"-~ -.-,----.--.--..-------.-,--- - -"~------'--'- bp , , ç~ll1p.~y:: BPAmoco ' Fiel~: ',Rrudho~:6ay S~~~;' PB'ÐS 07 ,,'Well:' 07~13 , ..J¥!1l.~.~~,~.:__~,làn~B!.~138~__- Annotation ) ) BP Baker Hughes INTEQ Planning Report .,.".",..',...,iI..,.,!8..., I; ,......--- -,,,",---..--.--..-- IN'IEQ .-.------.-,......---..-- , I>~te: .5/2/2002 . "Tlm~: ..': 10:56:11 " , Påg~: C()~fdin~~e(~E)Re(erence:,I, vVen:07~1,3, 'Tru~ North' , ¥eriic~l (T¥QlQeference: 1 1 System:'MeanSEl~ J.:ev~1 Section,'(VS),Referenee~ '.'...,.,VVElII(b.OON,O~00E,33,00Azi). .,.'.. ..':. --,------,--_._-_._--,------_._-~~ sutj;~£!~ulati~nMe~hod: 1 MinimumCurv~ture ,._~-~.I2~.~L.' O~~~~:__--C-_.~- 2 12650.00 8944.73 TO -'--"'---'-- Plan: Plan #6 Identical to Lamar's Plan #5, shortened to 12650' Principal: Yes ---_._--_.~._.--- --""--,.--.----.------...-.,,..-------------.---,---.. ...---------.----- Plan Section Information -...''''.--"... ---------'--'."_W'-"-'--'--_.'.'_h_"'__-"'---'___m."'-----"--.'--'-------'------'--'----'.----'--"------'______M._'___-----'--..---.-.-.------.-.-------..-.--"-'-----" .,~':-"--:-';n--'"'''-:-'"~''''''''~'' MD. ' ...cI ' ,;\zhn --,-,~~,!~.,-.__.~,.--.,--~~~"-_~~__~e~- 11321.00 46.60 353.70 11350.00 49.69 354.17 11370.00 50.97 355.81 11420.00 57.89 10.81 11702.18 90.00 87.80 11902.18 95.46 60.30 12007.54 90.00 46.58 12407.54 90.00 350.58 12607.54 90.00 18.58 12650.00 90.00 12.63 .. ........---...--.-.--..---.----..---.------.- TV» . ft 8808.52 8827.87 8840.63 8869.81 8959.48 8949.77 8944.73 8944.73 8944.73 8944.73 ""+NI-S, , +E/;;W , . . "ft~~~~~n_~ ~', " 4440.28 -3863.20 4461.76 -3865.48 4477.09 -3866.83 4517.47 -3864.26 4664.30 -3668.87 4718.54 -3478.68 4781.08 -3394.40 5145.33 -3271.98 5342.71 -3256.18 5383.59 -3244.77 Date Composed: Version: Tied-to: 5/1/2002 1 From: Definitive Path ...........:........:.... ...I..~ -_._'-'---'-"--"'-----'----'-_~'___M__"_'_.'--"-"-'-'-_.____."'M_'_"__M'_____-"'''~''''-'-'-'-----'.''.----'-M"__"_'--''''___'M~''''_'''.'._'' I)1.S', , '''~Uild:','l'1Ï;;r:'~TFO,1 ' rr~fg~~ ~eg/1ItOft,.d~9{10qft'degI.1'9~ff: . q~~:. " ._~~.:~~_.~,-_. 0.00 0.00 0.00 0.00 10.72 10.66 1.62 6.62 9.00 6.42 8.19 45.00 28.00 13.83 30.00 65.00 28.00 11.38 27.29 83.00 14.00 2.73 -13.75 281.70 14.00 -5.19 -13.02 248.70 14.00 0.00 -14.00 270.00 14.00 0.00 14.00 90.00 14.00 0.00 -14.00 -90.00 Survey , "~:-~"MD--"'7-;"--'"'''''i~~I'-C"''c'---A;i;----''''c-''''S:S¡Vii:;"'ï--"--"~'í~ïS'-~-:-'-~~-;TE;\\ï'~'-"c;--'-'-r'~M~~N:'-"--;7:"-;~;;~~-':-;:""'~';7'vs--C'-i~---'-:ÕL~:r"---'Tii()-'---;'~'-~:--'T~~í"-: ....",:...-,,~,-- .._--,.,-,-,---:.--..~:!~-,.,' ~,.'-~-~~,- "-----"-_:'~~~--~'::~_~__--L~~':"_._~:~".c_.:.,:_!!_,~,..._._-~.:_-~,":~.~~--,",:,,-~~-_.c.:~--,~!!_~_.I:~:~,:- -~~_.~ ~_L,...:',~-~~~~"!.?~?~;,:,..~~.~~:,--,-L_.--_.~,-_:~- n 11321.00 46.60 353.70 8808.52 4440.28 -3863.20 5954638.50 671931.20 1619.88 0.00 0.00 TIP 11325.00 47.03 353.77 8811.26 4443.18 -3863.52 5954641.39 671930.81 1622.14 10.72 6.62 MWD 11350.00 49.69 354.17 8827.87 4461.76 -3865.48 5954659.92 671928.41 1636.65 10.72 6.58 KOP 11370.00 50.97 355.81 8840.63 4477.09 -3866.83 5954675.22 671926.71 1648.78 9.00 45.00 1 11375.00 51.58 357.43 8843.76 4480.99 -3867.06 5954679.11 671926.39 1651.92 /28.00 65.00 MWD 11400.00 54.90 11420.00 57.89 11425.00 58.07 11450.00 59.29 11475.00 60.99 11500.00 63.12 11525.00 65.64 11550.00 68.50 11575.00 71.62 11596.37 74.47 11600.00 74.97 11616.90 77.34 11625.00 78.50 11650.00 82.15 11675.00 85.89 11700.00 89.67 11702.18 90.00 11725.00 90.65 11750.00 91.35 11775.00 92.06 11800.00 92.75 11825.00 93.44 11850.00 94.11 11875.00 94.77 11900.00 95.41 11902.18 95.46 11925.00 94.30 11950.00 93.00 5.12 8858.73 4500.98 -3866.58 5954699.10 671926.40 1668.95 28.00 10.81 8869.81 4517.47 -3864.26 5954715.64 671928.33 1684.04 28.00 12.45 8872.46 4521.62 -3863.41 5954719.81 671929.09 1687.99 28.00 20.52 8885.47 4542.07 -3857.35 5954740.39 671934.67 1708.44 28.00 28.35 8897.93 4561.78 -3848.38 5954760.30 671943.18 1729.85 28.00 35.90 8909.66 4580.45 -3836.63 5954779.25 671954.48 1751.91 28.00 43.14 8920.48 4597.81 -3822.29 5954796.94 671968.41 1774.28 28.00 50.09 8930.23 4613.60 -3805.56 5954813.11 671984.77 1796.64 28.00 56.75 8938.76 4627.59 -3786.70 5954827.53 672003.30 1818.64 28.00 62.25 8945.00 4637.95 -3769.09 5954838.30 672020.66 1836.92 28.00 63.17 8945.96 4639.56 -3765.98 5954839.98 672023.73 1839.96 28.00 67.39 8950.00 4646.41 -3751.08 5954847.18 672038.46 1853.82 28.00 69.38 8951.70 4649.33 -3743.71 5954850.27 672045.76 1860.28 28.00 75.44 8955.90 4656.76 -3720.23 5954858.25 672069.06 1879.31 28.00 81.39 8958.51 4661.75 -3695.89 5954863.80 672093.28 1896.74 28.00 63.99 MWD 59.38 2 83.00 MWD 82.13 MWD 77.93 MWD 74.03 MWD 70.48 MWD 67.35 MWD 64.64 MWD 62.36 07-138 T 60.76 MWD 60.52 07-138 T 59.51 MWD 59.09 MWD 58.07 MWD 87.29 8959.48 4664.21 -3671.05 5954866.84 672118.05 1912.34 28.00 57.45 MWD 87.80 8959.48 4664.30 -3668.87 5954866.99 672120.23 1913.60 28.00 57.22 3 84.67 8959.35 4665.80 -3646.10 5954869.02 672142.95 1927.26 14.00 281.70 MWD 81.25 8958.92 4668.86 -3621.30 5954872.66 672167.68 1943.34 14.00 281.68 MWD 77.82 8958.17 4673.40 -3596.73 5954877.77 672192.13 1960.53 14.00 281.62 MWD 74.38 8957.12 4679.40 -3572.49 5954884.33 672216.23 1978.76 14.00 281.52 MWD 70.94 8955.77 4686.84 -3548.66 5954892.33 672239.87 1997.97 14.00 281.38 MWD 67.50 8954.13 4695.69 -3525.34 5954901.72 672262.98 2018.10 14.00 281.19 MWD 64.05 8952.19 4705.91 -3502.61 5954912.47 672285.46 2039.05 14.00 280.96 MWD 60.60 8949.98 4717.47 -3480.56 5954924.54 672307.23 2060.75 14.00 280.70 MWD 60.30 8949.77 4718.54 -3478.68 5954925.65 672309.09 2062.68 14.00 280.39 4 57.31 8947.83 4730.32 -3459.23 5954937.88 672328.26 2083.15 14.00 248.70 MWD 54.05 8946.24 4744.38 -3438.63 5954952.42 672348.52 2106.16 14.00 248.45 MWD ~~!bp W'. ) -) ..: IN!'iãd, BP Baker Hughes INTEQ Planning Report -,":'7"'..-:-._-",:,""",'~-:-,1';'- I I I I I I I I . I Cqm~~~y~' 1,3~:.Är'J)~9~' I Da~:5(2I2002' I ". 'i. Time,:10:S6.:11 I " .. . '. ,''',Påge: xrield~' .Rq~çJ9q~ß~Y I Co~~di~~t~(1~i1;'),'~t\ferepce:' I ,'W.~II: Q7--13.rruèt-JQrth', ' I Si~e:, I BS',.DS07, :Vertical(TVD)'Refel'ence:, System:',Mean Sealevel ~éll:, 07~t3' Section(VS)'R~fel'enc~: ., '. I Well(p,OON,O.oq :,33.00Azi) I -_~!!!R~mL~'åp#607~13~~,_._-~---,-~-----------~~~,---,-.---.:_'Sua:vey Cakula:ti()n~ethod: ~~~L,:!,~m 'Curvature ''----'-.,---'" Db-=-~~~.__.,- Survey ~ '-'---;-MD-~----.~êI-'---Azi... SSTVÕ---'~- N/S I EIW 'MapN, ,~~pE 'vs ,.,. ''Dts--'--Tèo---;------~'.T-~óï--~ -------~,--"-,~-- I 'deg ",--,.~eg-~~-,-----~~_c.,~- ft" , ,tt, I ,ft I " I 1ft tt" , 'd~gl1'dQtt, ,-~!3g ..'...~._-'-~--_..:._~ 11975.00 91.70 50.80 8945.21 4759.61 -3418.83 5954968.11 672367.96 2129.72 14.00 248.24 MWD 12000.00 90.39 47.56 8944.75 4775.95 -3399.92 5954984.88 672386.48 2153.72 14.00 248.10 MWD 12007.54 90.00 12025.00 90.00 12050.00 90.00 12075.00 90.00 12100.00 90.00 12125.00 90.00 12150.00 90.00 12175.00 90.00 12200.00 90.00 12225.00 90.00 46.58 8944.73 4781.08 -3394.40 5954990.14 672391.88 2161.03 ~4.00 248.05 5 44.13 8944.73 4793.35 -3381.98 5955002.70 672404.01 2178.09 /14.00 270.00 MWD 40.63 8944.73 4811.82 -3365.13 5955021.55 672420.42 2202.75 14.00 270.00 MWD 37.13 8944.73 4831.27 -3349.44 5955041.37 672435.65 2227.61 14.00 270.00 MWD 33.63 8944.73 4851.65 -3334.96 5955062.08 672449.64 2252.59 14.00 270.00 MWD 30.13 8944.73 4872.88 -3321.76 5955083.61 672462.35 2277.58 14.00 270.00 MWD 26.63 8944.73 4894.87 -3309.88 5955105.87 672473.71 2302.49 14.00 270.00 MWD 23.13 8944.73 4917.55 -3299.36 5955128.78 672483.69 2327.24 14.00 270.00 MWD 19.63 8944.73 4940.82 -3290.25 5955152.26 672492.26 2351.72 14.00 270.00 MWD 16.13 8944.73 4964.61 -3282.57 5955176.22 672499.38 2375.86 14.00 270.00 MWD 12250.00 90.00 12.63 8944.73 4988.82 -3276.37 5955200.57 672505.02 2399.54 14.00 270.00 MWD 12275.00 90.00 9.13 8944.73 5013.37 -3271.65 5955225.22 672509.16 2422.70 14.00 270.00 MWD 12300.00 90.00 5.63 8944.73 5038.16 -3268.44 5955250.08 672511.79 2445.24 14.00 270.00 MWD 12325.00 90.00 2.13 8944.73 5063.10 -3266.74 5955275.05 672512.90 2467.08 14.00 270.00 MWD 12350.00 90.00 358.63 8944.73 5088.09 -3266.58 5955300.04 672512.48 2488.13 14.00 270.00 MWD 12375.00 90.00 355.13 8944.73 5113.05 -3267.94 5955324.96 672510.54 2508.32 14.00 270.00 MWD 12400.00 90.00 351.63 8944.73 5137.88 -3270.82 5955349.71 672507.08 2527.58 14.00 270.00 MWD 12407.54 90.00 350.58 8944.73 5145.33 -3271.98 5955357.13 672505.74 2533.18 14.00 270.00 6 12425.00 90.00 353.02 8944.73 5162.61 -3274.47 5955374.35 672502.85 2546.32 14.00 90.00 MWD 12450.00 90.00 356.52 8944.73 5187.50 -3276.75 5955399.18 672499.99 2565.96 14.00 90.00 MWD 12475.00 90.00 12500.00 90.00 12525.00 90.00 12550.00 90.00 12575.00 90.00 12600.00 90.00 12607.54 90.00 12625.00 90.00 12650.00 90.00 ~--"--'-',".'----._.~ .. 0.02 8944.73 5212.49 -3277.51 5955424.14 672498.65 2586.50 14.00 3.52 8944.73 5237.47 -3276.73 5955449.13 672498.84 2607.88 14.00 7.02 8944.73 5262.36 -3274.44 5955474.06 672500.55 2630.00 14.00 10.52 8944.73 5287.07 -3270.62 5955498.85 672503.79 2652.80 14.00 14.02 8944.73 5311.49 -3265.31 5955523.39 672508.53 2676.18 14.00 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 17.52 8944.73 5335.55 -3258.52 5955547.60 672514.76 2700.05 14.00 90.00 MWD 18.58 8944.73 5342.71 -3256.18 5955554.81 672516.92 2707.33 14.00 90.00 7 16.13 8944.73 5359.38 -3250.97 5955571.60 672521.74 2724.15 14.00 270.00 MWD 12.63 8944.73 5383.59 -3244.77 5955595.95 672527.38 2747.83 14.00 270.00 TO -.. --.-.. - ~-. --- '"'''--'---''' -."-"- ~_...., "-'__0"" "'-_~.___n_-'._- ~._---,- -._n____- ----_.~,~._. ----.-- ._...--~..._,_.-._. ,---_.. _'n_____~---""""'-- '.'---'-'..-",,'-'-.---.-.----.,-....'----- .~_.. '--'-'.""-"-~_._"" -,-,-_,...,_n ..,_. ~.,-,- ..--- --.-------------.--..--....---- -- - ,---,- - ,---_u- BOP-Tree ) KB Elevation Well l 7-13B I Rig Floor I I '" ~¡;¡¡:¡"¡¡¡¡I¡!ñ!:I'11 L. .. .'. uUI """', ........ uu ,.i}m,~ :f~ ~Ubncator ID = 6375' wnh 6- Otis Un~ns . L. L 'I . ...:.' rir~'..~. t.1'1I~""I".'~II~.'''''''.'. . Ir 1/16" '5000 psi SOP's. 10 = 7.06ð I ~ I ~:,':::','::', ~71/16" 5000 psi, AX-46 I / ,~~~::i.=¡~;~,' .' " ',,' ,".I L-- t~~:::;æ::ij~I:~::::::1 I , L .. In:~~:~~ tl4TurnLTVaJve I ." . U ... ". I .l:' "~' ',. ¡I 7~/16' 5000 pSI RX.46 '. .. . ... . ~àó~g:.,' ITII . I ... . .. ...~ L.,.":,,.,:.::...J @ [[] ~ [ "'1''' "'" , l ~ 'II i II In¡~~~i#j~e.1 ~ t;~i~~~J~ :i::1~~n: p:¡ 'RX.J .f I' / :~:~:~{ I I I I. 2 tF8~:~~mb1 .1(' , -- ' I £1 - .: "1'Ó1'":.' 1 }' 'f 71/16" 6000 psi (RX-46) or . :':". :..~. : +-- 41/16" 5000 psi (RX-39) 2. tll ;~:~~~~~~~~~~% J¡.....;!.-:-.........¡m!~!....,~ r.Wt~$i~~11~j .g ~ííí?-m~íí~Ñi'í~ rl-1f:Brr~ ; ç;,..~~.:~~.:.~:~}::~ LJ..~-L¡'::. :::~::::. '.: ~ " ...... - .. r .. .. ..'. I ~ Swab Valve I Tree Size I SSV I I I Master Valve I I tubing x 9-5/811 Annulus I .. . -.. . .. .. . . y ~ ... .. . .. .,! I '. ~ .': 0::: ~:.: ':' .;:::' ". . 1JGtQ~.::....: '.:~.~':~.JEItU I . ~~::.\:::¡);.:;.:': '. . :I . ."'. I Base FlanQe 19-5/811 X 13-3/811 Annulus I ... .. ... .. .. I . . ............."."...._"..."." Page 1 H 206711 DATE INVOICE I CREDIT MEMO DESCRIPTION 040902 CK040902M PYMT COMMENTS: HANDL!NG INST: GROSS PERMIT TO DRILL FEE S/H - TERRIE HUBBLE X4628 iOO.OO R, E C,' F ( \J 'r. :-c \2.'2:<3 (]:! ~!;~:~L¡:~;~'~l~;.l~:"'::'; ,t;, ¡~ ';;¡V THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAG E, ALASKA 99519-6612 PAY To The ORDER Of 0'1 / \~ ioo.ool DATE CHECK NO, ()4l/ i 1,/()2 \J02()I~ 7 i 1 VENDOR DISCOUNT ALAS¥'.AO I LA NET iOO.OO iOO.OO No. H 206711 FIRST NATIONAL BANK OF ASHLAND AN AFFIUATE OF NATIONAL CITY BANK CLEVELAND. OHIO DATE 04i 11 /02 III 2 0 b 7 ¡. *111 I: 0 L, ¡. 2 0 ~ B g 5 I: 0 0 B L, ~ ¡. g III 56-389 -¡:j2 CONSOLIDATED COMMERCIAL ACCOUNT 00206711 ONE HUNDRED & 00/100************************************* US DOLLAR AMOUNT $100.00 NOT VALID AFTER 120 DAYS Ç( <t~ !h.. 'fI . . .n, .. AI.ti/L A .. . ~.Vt v ~-:r~~. ~ ---. L__._~'- ~. = -..:..---- ALASKA OIL AND GAS CONSERVATION COMMISSION 333 WEST 7TH AVENUE SUITE 100 ANCHORAGE AK 99501 00 H --- CHECK 1 ST ANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL V EXPLORA TION INJECTION WELL INJECTION WELL REDRILL Rev: 5/6/02 C\jody\templates ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAMEf.fi¿~ Q7~/3ß CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT HOLE (PH) "CLUE" The permit is for a new wellbore segment of existing well ----' Permit No, API No. Production should continue to be reported as a function of the original API number stated above. In accordance with 20 AAC 25.005(1), 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). ANNULAR DISPOSAL Please note that an disposal of fluids generated. . . INTO ANNULUS OF ANOTHER WELL ON SAME PAD L-) SPACING EXCEPTION Enclosed is the approved application for permit to drill the above referenced well. 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. (Companv Name) will assume the liability of any protest to the spacing exception that may occur. WELLPERMITCHECKLlST COMPANY .£~)( WELLNAME07-!~~..ß PROGRAM: Exp- Dev~ Redrll~ Se~- Wellboreseg- Ann. disposal parareq- FIELD & POOL (;'Olt)ð INITCLASS ./J¡øJ/ /-ð~)J GEOLAREA cg-5ì~ UNIT# //6S6 ON/OFFSHORE ON ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . PN 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. .. . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N APPR DATE 12. Permit can be issued without administrative approval.. . . . . Y N tfr: c;/~~2. 13. Can permit b~ approv~d before 15-day wait.. . . . . . . . .. ~. Y N ENGINEERING 14. Conductor stnng provided. . . . . . . . . . . . . . . . . . . - N. 15. Surface casing protects all known USDWs. . . . . . . . . . . I /;1 16. CMT vol adequate to circulate on conductor & surf csg. . . . . -¥----N-ß/ IT 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . i 18. CMT will cover all known productive horizons. . . . . . . . . . N 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . . ,N C-T D u.. 21. If a re-drill, has a 10-403 for abandonment been approved. .. ¥- Y N 22. Adequate wellboreseparation proposed.. . . . . . . . . .-. . éí2 N 23. If diverter required, does it meet regulations. . . . . . . . . . -¥---N-.I-I/A- 24, Drilling fluid program schematic & equip list adequate. . . . . !3 N ~~: ~g~~spr~~~~:~:e:~~~;~~i~~~~t~sit~ .3500. . . . . . psig: ø ~ t~ ~ I) 7,1 CJ tf r 5. ,~ , 27. Choke manifold complies w/API RP-53 (May 84). . . . . . . . ~ N 28. Work will occur without operation shutdown. . . . . . . . . . . ,N 29. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . N 30. Permit can be issued wlo hydrogen sulfide measures. . . . . Y (ßj) 31. Data presented on potential overpressure zones. . . . . .. Z //1 ~ /J, 32. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y prv "rt . AP-PR QJ>.~9 33. Seabed condition survey (if off-shore). . . . . . . . . . . . . N XII' ~~/'-'?.2.. 34. Contact namelphone for weekly progress reports [exploratory onl Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . . . (B) will not contaminate freshwater; or cause drilling waste. .. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 MC 25.252 or 20 MC 25.412. Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: RP~ APPR DA T~ \W4A- 6(L//tJ'l-- 4~ ~{b"0 GEOLOGY APPR DATE 4t ø~~ ( ( ,/lAA. .~~~ ~ G~1: {?~ ~ Com mentsllnstructions: JDH WGA ;¡..JC;1~ ~~"1W\.. 4/ ~ COT DTS \36 f (} 6 10"0 G :\geology\permits\checklist.doc ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special' effort has been made to chronologically organize this category of information. ') Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Mar 14 12:45:36 2003 Reel Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... .UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Services ') ,a (J;{--II~). II (a ,,3(1 Writing Library. Scientific Technical Tape Header Service name. . . . . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/03/14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Services Writing Library. Scientific Technical Physical EOF Comment Record TAPE HEADER Prudhoe Bay MWD / MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 1 AK-MW-22110 B. JAHN R. WHITLOW / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWDRUN 4 AK-MW-22110 B. JAHN G. SARBER / # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: 07-13B 500292033802 BP Exploration Sperry Sun 14-MAR-03 MWDRUN 2 AK-MW-22110 B. JAHN R. WHITLOW / 33 11N 14E 628 (Alaska) Inc. MWDRUN 3 AK-MW-22110 B. JAHN G. SARBER / ) ') FEL: FWL: ELEVATION (FT FROM KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 290 MSL 0) 52.26 .00 .00 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 3.750 4.500 11287.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS (TVD). 3. WELL KICKED OFF FROM 7-13A WITH TOP OF WHIPSTOCK SET AT 11348' MD, 8830' TVDSS. 4. MWD RUN 1 WAS DIRECTIONAL WITH PRESSURE CASE GAMMA ( PCG ) UTILIZING SCINTILLATION DETECTORS. 5. MWD RUNS 2-4 WERE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). 6. RESISTIVITY DATA IN THE INTERVAL 11522' MD TO 11715.5' MD, WAS ACQUIRED ON A MEASUREMENT AFTER DRILLING (MAD) PASS PRIOR TO MWD RUN 2. 7. DIGITAL AND LOG DATA ARE DEPTH SHIFTED TO THE PDC GR LOG, (SCHLUMBERGER LOG RUN 07/08/2002) PER 10/21/2002 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 8. MWD RUNS 1-4 REPRESENT WELL 7-13B WITH API # 50-029-20338-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12960'MD / 8943'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRD = SMOOTHED GAMMA RAY - SCINTILLATION DETECTORS SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) SEXP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (EXTRA SHALLOW SPACING) SESP = SMOOTHED PHASE SHIFT DERIVED RESISTIVITY (SHALLOW ) SPACING) SEMP = SMOOTHED SPACING) SEDP = SMOOTHED SPACING) SFXE = SMOOTHED $ ) PHASE SHIFT DERIVED RESISTIVITY (MEDIUM PHASE SHIFT DERIVED RESISTIVITY (DEEP FORMATION EXPOSURE TIME File Header Service name............ .STSLIB.OOl Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE SGRD SROP SFXE SEDP SEMP SESP SEXP $ 1 clipped curves; all bit runs merged. .5000 START DEPTH 11271.5 11355.0 11546.5 11546.5 11546.5 11546.5 11546.5 STOP DEPTH 12916.5 12961.5 12928.0 12928.0 12928.0 12928.0 12928.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE 11271.5 11273.0 11280.5 11285.5 11294.0 11331.0 11379.0 11399.5 11405.0 11433.0 11460.5 11466.5 11479.5 11491.0 11504.0 11512.5 11520.5 11549.5 11552.0 11605.5 11612.0 11637.0 11654.0 DEPTH GR 11246.0 11247.5 11254.5 11258.0 11266.5 11307.5 11356.5 11377.5 11382.5 11410.5 11437.5 11446.0 11457.5 11468.0 11480.0 11489.0 11495.5 11525.0 11529.0 11583.5 11589.5 11618.5 11631.0 ) ) 11660.5 11744.0 11799.0 11820.5 11837.5 11888.5 11916.5 11940.5 12047.0 12060.5 12068.0 12123.0 12133.0 12143.0 12149.5 12215.0 12231.0 12232.5 12239.5 12246.5 12280.0 12359.5 12368.5 12402.5 12409.0 12418.0 12429.5 12433.0 12448.5 12455.0 12467.5 12543.5 12549.5 12557.0 12598.5 12631.5 12634.5 12641.0 12656.0 12671.0 12673.0 12676.5 12698.5 12701.0 12703.5 12716.5 12727.5 12745.0 12754.5 12768.0 12776.5 12785.0 12802.5 12828.5 12836.0 12840.5 12849.5 12852.0 12854.0 12859.0 12870.5 11636.5 11718.5 11776.0 11794.5 11813.5 11868.0 11896.5 11920.0 12027.5 12043.5 12049.0 12100.5 12110.0 12122.0 12127.5 12192.5 12207.5 12209.0 12217.5 12224.5 12258.5 12335.5 12345.5 12380.5 12386.5 12394.0 12406.0 12410.0 12423.5 12431.5 12445.0 12518.5 12526.0 12533.0 12574.0 12608.5 12610.5 12616.5 12631.0 12645.0 12647.5 12655.0 12677.0 12680.0 12683.5 12693.5 12704.0 12721.0 12730.0 12743.5 12750.5 12758.5 12776.0 12804.0 12811.5 12815.5 12823.5 12827.0 12828.5 12833.0 12843.5 ) ) 12874.0 12876.5 12879.5 12882.5 12885.5 12888.5 12894.5 12908.5 12912.5 12915.0 12961.5 $ 12847.5 12849.0 12850.5 12855.0 12858.5 12861.5 12868.5 12881.0 12885.0 12887.5 12934.0 # MERGED DATA PBU TOOL MWD MWD MWD MWD $ SOURCE CODE BIT RUN NO 1 2 3 4 MERGE TOP 11246.0 11522.0 11824.0 11828.0 MERGE BASE 11749.0 11868.5 11872.5 12934.0 # REMARKS: MERGED MAIN PASS. $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction....... . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value..................... .-999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11271.5 12961.5 12116.5 3381 11271.5 12961.5 ROP MWD FT/H 0 1428.02 98.0786 3214 11355 12961.5 GR MWD API 15.31 272.87 58.0327 3245 11271.5 12916.5 RPX MWD OHMM 6.64 33.48 15.4189 2764 11546.5 12928 RPS MWD OHMM 7.83 37.32 16.7299 2764 11546.5 12928 ) ) RPM MWD OHMM 8.19 40.22 17.1867 2764 11546.5 12928 RPD MWD OHMM 10.03 35.5 16.7378 2764 11546.5 12928 FET MWD HOUR 0.2345 19.6385 3.62429 2764 11546.5 12928 First Reading For Entire File......... .11271.5 Last Reading For Entire File.......... .12961.5 File Trailer Service name............ .STSLIB.OOl Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.OOl Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11246.0 ROP 11332.0 $ 2 header data for each bit run in separate files. 1 .5000 STOP DEPTH 11720.0 11749.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 04-JUL-02 Insite 4.3 Memory 11775.0 11271.5 11775.0 56.5 83.9 ) # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE PCG Natural gamma ray $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER 72829 3.750 11287.0 Flo-Pro 8.70 7.0 8.5 25000 6.8 .000 .000 .000 .000 .0 145.9 .0 .0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD010 FT/H 4 1 68 4 2 GR MWD010 API 4 1 68 8 3 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11246 11749 11497.5 1007 11246 11749 ROP MWD010 FT/H 0 1428.02 78.2415 835 11332 11749 GR MWD010 API 15.31 162.51 36.699 898 11246 ) 11720 ) First Reading For Entire File........ ..11246 Last Reading For Entire File......... ..11749 File Trailer Service name............ .STSLIB.002 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . .LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE RPM RPD RPS RPX FET GR ROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 11522.0 11522.0 11522.0 11522.0 11522.0 11705.0 11749.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11835.0 11835.0 11835.0 11835.0 11835.0 11823.5 11868.5 04-JUL-02 Insite 4.3 Memory 11894.0 11775.0 11894.0 90.2 90.2 '} # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O ) TOOL NUMBER 72829 153949 3.750 11287.0 Flo Pro 8.70 7.0 8.0 26000 7.2 .160 .079 .300 .180 68.0 144.0 68.0 68.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 Name Service Unit Min Max Mean Nsam First Reading Last ) ) Reading DEPT FT 11522 11868.5 11695.3 694 11522 11868.5 ROP MWD020 FT/H 1.65 199.78 112.867 239 11749.5 11868.5 GR MWD020 API 28.61 71.12 50.7203 238 11705 11823.5 RPX MWD020 OHMM 6.64 33.48 14.743 627 11522 11835 RPS MWD020 OHMM 8.12 37.32 17.5192 627 11522 11835 RPM MWD020 OHMM 8.89 40.22 18.6739 627 11522 11835 RPD MWD020 OHMM 11.08 35.5 19.6926 627 11522 11835 FET MWD020 HOUR 0.2727 19.6385 11.9724 627 11522 11835 First Reading For Entire File........ ..11522 Last Reading For Entire File.......... .11868.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name..: Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type. . . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR FET RPD RPM RPS RPX 4 header data for each bit run in separate files. 3 .5000 START DEPTH 11824.0 11835.5 11835.5 11835.5 11835.5 11835.5 STOP DEPTH 11827.0 11839.0 11839.0 11839.0 11839.0 11839.0 ) ROP $ 11869.0 11872.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER ( FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value............ . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . ) 05-JUL-02 Insite 4.3 Memory 11898.0 11894.0 11898.0 90.2 90.2 TOOL NUMBER 72829 153949 3.750 11287.0 Flo Pro 8.70 7.0 8.0 26000 7.2 .160 .079 .300 .180 68.0 144.0 68.0 68.0 ) ) Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11824 11872.5 11848.3 98 11824 11872.5 ROP MWD030 FT/H 0 565.52 185.32 8 11869 11872.5 GR MWD030 API 36.09 39.47 37.77 7 11824 11827 RPX MWD030 OHMM 10.88 11.3 11.105 8 11835.5 11839 RPS MWD030 OHMM 13.2 13.58 13.4063 8 11835.5 11839 RPM MWD030 OHMM 13.65 14.34 13.98 8 11835.5 11839 RPD MWD030 OHMM 14.58 14.72 14.65 8 11835.5 11839 FET MWD030 HOUR 6.5313 6.5433 6.53699 8 11835.5 11839 First Reading For Entire File......... .11824 Last Reading For Entire File.......... .11872.5 File Trailer Service name............ .STSLIB.004 Service Sub Level Name. . . Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type................LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 File Type.... . . . . . . . . . . . .LO Previous File Name...... .STSLIB.004 ) Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPD RPM RPS RPX FET ROP $ 5 ,) header data for each bit run in separate files. 4 .5000 START DEPTH 11828.0 11839.5 11839.5 11839.5 11839.5 11839.5 11873.0 STOP DEPTH 12889.0 12900.5 12900.5 12900.5 12900.5 12900.5 12934.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RESIS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # 06-JUL-02 Insite 4.3 Memory 12960.0 11898.0 12960.0 85.6 96.9 TOOL NUMBER 72830 125631 3.750 11287.0 Flo-pro 8.60 7.0 8.5 23000 7.2 .110 .050 .200 .150 69.0 158.9 69.0 69.0 ) ) TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11828 12934 12381 2213 11828 12934 ROP MWD040 FT/H 1.8 694.68 104.217 2123 11873 12934 GR MWD040 API 25.02 272.87 67.3501 2123 11828 12889 RPX MWD040 OHMM 6.97 30.87 15.6671 2123 11839.5 12900.5 RPS MWD040 OHMM 7.83 26.66 16.5546 2123 11839.5 12900.5 RPM MWD040 OHMM 8.19 26.66 16.8057 2123 11839.5 12900.5 RPD MWD040 OHMM 10.03 21.31 15.9019 2123 11839.5 12900.5 FET MWD040 HOUR 0.2345 15.4109 1.19232 2123 11839.5 12900.5 First Reading For Entire File......... .11828 Last Reading For Entire File.......... .12934 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/03/14 Maximum Physical Record. .65535 ') ) File Type. . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.006 Physical EOF Tape Trailer Service name... . . . . . . . . . .LISTPE Da t e. . . . . . . . . . . . . . . . . . . . . 03 / 03 / 14 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name. . . . . . . . . . . . . . . . UNKNOWN Continuation Number..... .01 Next Tape Name.......... . UNKNOWN Comments................ .STS LIS Services Writing Library. Scientific Technical Reel Trailer Service name. . . . . . . . . . . . .LISTPE Date. . . . .. . . . . . . . . . . . . . . .03/03/14 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Services Writing Library. Scientific Technical Physical EOF Physical EOF End Of LIS File
