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201-129
• • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other [bandoned ''+spended 1b. Well Class: 20AAC 25.105 7 , 25.110 ❑ Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ® Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 1/18/2012 201 - 129 311 - 285 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 8/13/2001 50 029 - 23030 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 8/24/2001 S -110 4481' FSL, 4498' FEL, SEC. 35, T12N, R12E, UM 8. KB (ft above MSL): 69.55' 15. Field / Pool(s): Top of Productive Horizon: 1520' FSL, 811' FEL, SEC. 26, T12N, R12E, UM GL (ft above MSL): 36.4' Prudhoe Bay Field / Aurora Pool Total Depth: 9. Plug Back Depth (MD +TVD): 1529' FSL, 798' FEL, SEC. 26, T12N, R12E, UM 3180' 2682' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 618930 y - 5980685 Zone ASP4 8792' 7116' ADL 028257 TPI: x- 622577 y- 5983062 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 622589 Y 5983071 Zone- ASP4 None 18. Directional Survey: ❑ Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: MWD, GR, Gyro, RES, NEU, DEN, CMR, MDT, RFT, USIT, CBL, Temp, CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H -40 Surface 115' Surface 115' 30" 260 sx Arctic Set (Approx.) 9 -5/8" 40# L -80 , 34' 3466' 34' 2883' 12-1/4" 577 sx AS I I I . 298 sx 'G'. 658 sx AS I I I 7" 26# L -80 3188' 8773' 2687' 7097' 8 -3/4" 390 sx LiteCrete 24. Open to production or injection? ❑ Yes w No 25. TUBING RECORD If Yes, list each interval open .SIZE DEPTH SET (MD) PACKER SET (MD / TVD) (MD +TVD of Top & Bottom; Perforation Size and Number): 3-1/2" 9.3# L -80 8151' - 8528' 8305' / 6630' MD - MD MO Tvn RECEIVED 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 8312' - 8314' Tubing Punch FEB 10 2012 8131' P&A w/ 19 Bbls cmt (8237') and Set EZSV (8131') 5789' 45.1 Bbls and 47.2 Bbls Class 'G' i, Alaska Oil & Gas Cnnt Commission 3180' Set EZSV w/ Whipstock on Top 27. Anchnrarfp PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Production Date of Test: Hours Tested: Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No Sidewall Core(s) Acquired? ❑ Yes 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 AAC 250.071. None SLANNEDFEB 2 8 2012 RSOMS FEB 1 20 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE � „�� -2/Z � /( L � �Syi��ngmal Only / �'- Y /Z l� • 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. RMATION TESTS NAME MD TVD Well Tested? ❑ Yes No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Schrader Bluff M 6393' 4857' None Schrader Bluff N 6677' 5075' Schrader Bluff 0 6808' 5186' Colville Mudstone 7132' 5481' HRZ 8463' 6787' Kalubik 8476' 6800' Kuparuk C 8480' 6804' LCU / Kuparuk B 8535' 6859' Kuparuk A 8562' 6886' Base Kuparuk / Top Miluveach 8621' 6945' Formation at Total Depth (Name): Base Kuparuk / Top Miluveach 8621' 6945' 31. List of Attachments: Summary of Pre -Rig Work and, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that th regoing is rue Correct to the best of my knowledge. n /� Signed: Joe Lastufk _ , Title: Drilling Technologist Date: hI "r II S - 110 201 - 129 311 - 285 Prepared By Name/Number. Joe Lastutka, 564 -4091 Well Number Permit No. / Approval No. Drilling Engineer: Kris Hones, 564 -4841 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10 -407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 12/2009 Submit Original Only • • S -110, Well History (Pre Rig Sidetrack) Date Summary 08/26/11 WELL SHUT IN ON ARRIVAL. CURRENTLY RUNNING DRIFT W/ 10" x 1 -7/8" STEM, XO, 2.25" CENT & 1 -1/2" SAMPLE BAILER. 08/27/11 DRIFT W/ 10" x 1 -7/8" STEM, XO, 2.25" CENT & 1 -1/2" SAMPLE BAILER, S/D ©1 1,728' SLM (HYDRATES IN BAILER). B &F W/3 -1/2 BLB & 2.30 GAUGE RING, S/D Q 8,385' SLM / 8,379' MD ON 3- 1/2 x 2 -7/8 XO. BEGIN RUNNING PDS 24 ARM CALIPER AS PER PROGRAM. 08/28/11 RAN PDS 24 ARM CALIPER AS PER PROGRAM. WELL LEFT S /I, DSO NOTIFIED. 11/09/11 WELL S/I ON ARRIVAL. DRIFT TO TUBING W/ 2.25" CENT, S.BAILER (BAILER EMPTY). LOCATE TT 8395' SLM / 8404' MD. TAG TD © 8511' SLM / 8520' MD 4' OF FILL. RAN SBHPS PER PROGRAM (GOOD DATA). 11/10/11 WELL SHUT IN ON ARRIVAL. INITIAL T /1 /O= 1000/200/0 RIG UP 1.56" HSD TUBING PUNCH. 11/11/11 RIH WITH MH22 / SWIVL / ERS / 2XEQF43 / MPD / FH / 1.56" 6' HSD GUN /BOWSPRING, OAL= 26.9', OAW =260 #, FISHING NECK SIZE= 1.38 ". TIE IN TO TUBING TALLY DATED AUG 25, 2001. TUBING PUNCH TUBING TAIL AT 8312' MD (2' BELOW BOTTOM OF PACKER). VISUAL INDICATION OF SHOTS FIRED AT SURFACE RIG DOWN UNIT. FINIAL T /I /O= 1000/200/0 WELL LEFT SHUT IN, DSO AND PE NOTIFIED OF DEPARTURE. JOB COMPLETE. 11/13/11 MIRU. During rig up, went to Phase 2. Secure well by installing and testing nite cap on BOP's. Set injector on back deck. Monitor weather conditions. 11/14/11 MU 7.9' of 1.93" OD drift assembly, w /BDN. Pump down Tbg w /1% KCL, 150 bbl's © 4 BPM x 1830 psi. c pfk:( RIH w /drift assembly. Tag fill © 8507.3' CT depth, reset tag depth to corrected depth using SL/TT depth, 8511'. Est rate & pressure down CT C© 8450', 1BPM © 1280 WHP. Pump down coil w/ KCL CO min rate. Re- correct depth © flag to corrected S/L depth of 8520'. Pump 19 bbls cement. Lay in to 8460', put 4 bbls cement behind pipe, lay in cement to 7500'. 11/15/11 FP coil © safety. Hesitate. Emergency H2S /Man -down drill. Hesitate to end of set time w/ 4.3 bbl. Got 500 psi bump. (Total 8.3 bbl behind pipe) Release pressure to 400 psi, drop 3/4" ball. Jet w/ bio © max rate to target depth of 8225'. Jet back up to 7278' and back to target 8225' w/ bio. Jet slick water out of of hole © max rate. Freeze protect welibore from 3000' w/ water /meth. Recover ball. RDMO. MONTHLY BOP CHANGE OUT. Job is complete. 11/16/11 WELL S/I ON ARRIVAL. DRIFTED TUBING W/ 2.25" CENT & 1.50" S- BAILER ( RETURNS OF CEMENT) TAG TD © 8237' SLM. DRIFTED TUBING TO TD © 8237' SLM W/ 2.80" CENT & 2.50" S- BAILER, RETURNS OF CEMENT & FLO PRO. WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS. 11/17/11 WELL SHUT -IN UPON ARRIVAL. INTIAL T /1 /0 = 25/200/0 PSI. ARRIVE AND BEGIN RIGGING UP. FINAL T /I /O = 25/200/0 PSI. 11/18/11 INTIAL T /I /O = 25/200/0 PSI. BEGIN RIH. NEEDLE VALVE STEM ON SSV CONTROL LINE LEAKING. POOH AND CHANGE NEEDLE VALVE OUT. RIH AGAIN. TIE INTO TUBING TALLY DATED AUG 25, 2001. CUT TUBING AT 8151' WITH 2.75" POWERCUTTER. POOH. FINAL T /I /O = 900/900/0 PSI. JOB COMPLETE. NOTIFY DSO. LEAVE LOCATION. 11/20/11 T /I /0= 825/810/0 temp =SI Circ Out, CMIT -TxIA PASSED to 4000 psi. Pumped 5 bbls neat meth & 426 bbls of 1% KCI down Tbg taking returns up IA to well S -119 Flowline. Pumped 105 bbls 80 °F diesel down IA taking returns up Tbg to well S -119 Flowline. Pumped 2 bbls 80 °F diesel down jumper line to well S- 119 for hardline freeze protect. U -Tubed IA to Tbg for 78 min. Pressured up TxIA to 4000 psi for CMIT- TxIA. T /IA lost 73/70 psi in the 1st 15 min and lost 30/30 psi in the 2nd 15 min for a total pressure loss of 103/100 psi in 30 min test. Bled back 3.5 bbls. Page 1 of 2 • • S -110, Well History (Pre Rig Sidetrack) Date Summary 11/21/11 MIT -OA PASSED to 2000 psi., Pumped 0.72 bbls diesel down OA to reach 2000 psi for MIT -OA. OA lost 70 psi in the 1st 15 min and lost 31 psi in the 2nd 15 min for a total pressure loss of 101 psi in 30 min test. Bled WHP's to 0 psi. FWHP's= 0 /0 /0. Page 2 of 2 • • .North-America = ALASKA - BP Page 1 e operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12/27/2011 21:00 - 00:00 3.00 MOB P -_ PRE PREPARE AND SKID THE RIG FLOOR FOR MOVING RIG OFF WELL Z -116. 12/28/2011 00:00 - 11:00 11.00 MOB P ._ PRE MOVE OFF OF WELL Z -116. MOVE RIG DOWN S -PAD ACCESS ROAD. 11:00 - 00:00 13.00 MOB N PRE LEFT REAR PORTION OF THE RIG ENTERED THE DITCH ON THE S -PAD ACCESS ROAD. - DEVELOP RIG ACTION PLAN WITH TOWN AND RIG TEAM FOR RIG EXTRACTION. - WAIT ON ORDERS FROM TOWN FOR AUTHORIZATION TO PROCEED. - SHOVEL OUT LEFT REAR OF RIG - PLACE SILLS AND PLYWOOD FOR STRUCTURAL SUPPORT OF THE RIG. 12/29/2011 00:00 - 12:00 12.00 MOB N HMAN PRE CONTINUE WITH WORK TO GET RIG BACK ONTO ROADWAY. - SHOVEL SNOW TO PLACE RIG MATTING - LAY MATTING BOARDS - SHORE UP LEFT REAR CORNER OF RIG. ** INITIAL 24 HR NOTIFICATION FOR BOPE TEST GIVEN TO AOGCC AT 08:00 HRS 12/29/2011 ** 12:00 - 00:00 12.00 MOB N HMAN PRE RIG EXTRACTION. - PLACE PLYWOOD UNDER LEFT REAR TIRE AND CORNER OF THE RIG. - DEFLATE LEFT REAR INNER TIRE TO 40 -PSI TO WORK PLYWOOD UNDER. - STABILIZE LEFT REAR TIRE. - REMOVE PLYWOOD AND REPLACE WITH MATTING BOARDS. - SHIM UP WITH 2" COMPOSITE MATTING BOARDS UNDERNEATH TIRES - RIG UP LINES AND DOZERS TO SECURE RIG FROM SHIFTING TOWARDS DITCH. ** UPDATE FOR BOPE TEST GIVEN TO AOGCC AT 17:00 HRS 12/29/2011 ** 12/30/2011 00:00 - 03:00 3.00 MOB N HMAN PRE RIG EXTRACTION - CONTINUE TO SHORE UP LEFT REAR OF RIG. 03:00 - 08:00 5.00 MOB N HMAN _ PRE DRIVE RIG FROM DITCH - INSPECT RIG EQUIPMENT FOR DAMAGE. 08:00 - 10:00 2.00 MOB N RREP - PRE LAYING DOWN REAR WINDWALL TO GAIN ACCESS WITH CRANE FOR LIFTING AND CHANGE OUT OF BAYLOR BRAKE 10:00 - 15:00 5.00 MOB P PRE CONTINUE WITH RIG MOVE TO S -PAD - MOVE RIG ONTO S -PAD - LAY DOWN REAR WIND WALL TO GAIN ACCESS WITH CRANE FOR LIFTING AND CHANGE OUT OF BAYLOR BRAKE. 15:00 - 18:00 3.00 MOB P -_ PRE MOVE OVER WELL S -110 - SHIM AND LEVEL RIG 18:00 - 21:00 3.00 MOB N RREP _ PRE SKID RIG FLOOR INTO DRILLING POSITION - RIG UP SERVICE LINES TO THE RIG FLOOR 21:00 - 22:00 1.00 MOB N RREP _ PRE RIG FLOOR DOWN AND SKID FOR ACCESS WITH CRANE TO LIFT BAYLOR BRAKE. Printed 1/23/2012 11:33:57AM • Worth America - ALASKA - BO' Page ,2eft1 Operation Summary Report ; Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 23:30 1.50 MOB N RREP PRE CRITICAL LIFT OF DYNAMATIC - HOLD PJSM WITH PERSONNEL INVOLVED. WSL, TOOLPUSHER, TOURPUSHERAND DOYON SAFETY. - FINALIZE LIFT PLAN, COMPLETE LIFT PERMIT AND NECESSARY DOCUMENTS. - REMOVE BAYLOR BRAKE WITH CMH2HILL CRANE. 23:30 - 00:00 0.50 MOB N RREP - PRE SKID RIG FLOOR INTO DRILLING POSITION TO HEAT FOR TUBOSCOPE INSPECTION OF DEADMAN ANCHOR. 12/31/2011 00:00 - 03:00 3.00 MOB N RREP PRE CONTINUE WITH BAYLOR BRAKE CHANGE OUT AND RIG MAINTENANCE. - CONTINUE TO SKID RIG FLOOR INTO DRILLING POSITION. - COVER REAR WIND WALL OPENING TO WARM RIG FLOOR TO ACCEPTABLE LEVEL FOR API INSPECTIONS - TUBOSCOPE INSPECT DEADMAN DRILL -LINE ANCHOR. - PREP FLOOR FOR DRILLING OPERATIONS. WELLS SUPPORT RIG UP 500 -BBL OPEN TOP TANK, HARLINE AND CHOKE MANIFOLD TO CELLAR AREA. 03:00 - 04:30 1.50 MOB N RREP PRE TUBOSCOPE INSPECT DEADMAN DRILL -LINE ANCHOR AND HUB - INSPECT DRAWWORKS BRAKE BANDS. - LAY OUT HERCULITE FOR SPOTTING ROCKWASHER MODULE. 04:30 - 06:30 2.00 MOB N RREP PRE BAYLOR BRAKE INSTALATION. - BLOW DOWN LINES TO RIG FLOOR. - PREP AND SKID RIG FLOOR FORWARD FOR LIFTING BAYLOR BRAKE INTO PLACE. 06:30 - 07:00 0.50 MOB N RREP PRE CRITICAL LIFT FOR BAYLOR BRAKE - PJSM WITH ALL PARTIES INVOLVED. - LIFT BAYLOR BRAKE INTO POSITION INSIDE OF DRAWWORKS. 07:00 - 07:30 0.50 MOB P PRE SKID RIG FLOOR BACK INTO DRILLING POSITION. ** ACCEPT RIG FOR OPERATIONS AT 07:00 HRS 12/31/2011 ** 07:30 - 08:00 0.50 MOB P -_ PRE PLACE REAR RIG FLOOR WINDWALL INTO DOWN POSITION. 08:00 - 10:30 2.50 MOB P -_ PRE RIG UP STEAM, WATER AND AIR LINES TO RIG FLOOR. 10:30 - 13:00 2.50 MOB P PRE RIG UP FLOOR. - GET LIGHTS AND CAMERAS RIGGED UP FOR FLOOR. - RIG UP DEADMAN ANCHOR TO HUB, SECURE DRILLING LINE TO ANCHOR. 13:00 - 17:00 4.00 MOB P PRE CONTINUE WITH RIG UP - HOOK UP CHOKE LINE, MUD LINE, BLEEDER LINE AND MUD BUCKET LINE. - UNLOCK BLOCKS TO STRAIGHTEN - SPOT ROCKWASHER AND BERM UP WITH CONTAINMENT. - TAKE ON SEA -WATER TO MUD PITS 15:00 HRS. Printed 1/23/2012 11:33:57AM torth:America - ALASKA -.BP Page 3-e04;` Mir Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:00 - 23:30 6.50 RIGU P PRE VERIFY ALL PRESSURES ON IA AND OA ARE ZERO. - INSTALL DOUBLE VALVES ON OA, IA . "" AOGCC JEFF JONES WAIVED WITNESS OF BOPE TEST 17:10 12/31/2011 "" - INSTALL 1502 FLANGE AND RIG UP TO TEST OA AND IA - PRESSURE TEST OA WITH DIESEL 250 -PSI LOW, 5 CHARTED MINUTES. 2,000 -PSI 30 CHARTED MINUTES. 23:30 - 00:00 0.50 RIGU P PRE SAFETY STAND DOWN. DISCUSS SAFETY AND UPCOMING 2012 HSE CONCERNS. 1/1/2012 00:00 - 05:30 5.50 RIGD P PRE PRESSURE TEST IA 250 -PSI LOW 5 CHARTED MINUTES. 2,000 -PSI HIGH FOR 30 CHARTED MINUTES. TEST GOOD. - RIG UP AND TEST TWC 250 -PSI LOW 5 CHARTED MINUTES. 4,000 -PSI HIGH FOR 5 CHARTED MINUTES. TEST GOOD. - BLOW DOWN LINES 05:30 - 07:00 1.50 RIGD P PRE SUCK OUT EXCESS FLUID IN THE TREE AND NIPPLE DOWN THE TREE AND ADAPTOR FLANGE. 07:00 - 08:00 1.00 BOPSUR P PRE TIE TREE BACK IN THE CELLAR AND MOBILIZE SPACER SPOOL TO THE CELLAR. 08:00 - 11:00 3.00 BOPSUR P PRE NIPPLE UP THE BOP STACK TO THE SPACER SPOOL. 11:00 - 12:00 1.00 BOPSUR P PRE SAFETY STAND DOWN FOR THE RIG CREW TO HAVE TIME TO EAT NEW YEARS MEAL. 12:00 - 22:00 10.00 BOPSUR P PRE CONTINUE TO NIPPLE UP THE ROP STACK TO THE WELLHEAD. TORQUE ALL BOLTS TO SPEC. ATTACH THE CHOKE LINE TO THE MUD CROSS. CALIBRATE AND TEST GAS DETECTION ALARMS. INSTALL THE TURN BUCKLES. MEASURE RISER TO MODIFICATIONS. HAVE 18" CUT OFF OF THE RISER AND INSTALL. INSTALL THE MOUSEHOLE, COVERS, HOLE FILL, AND BLEED OFF LINES. - LUSCHE'S CREW HELD SPILL DRILL, CRT 102 SEC - LUSCHE'S CREW HELD FIRE DRILL, CRT 87 SEC 22:00 - 23:00 1.00 BOPSUR P PRE INSTALL 3.5" TEST JOINT AND RIG UP TO TEST BOPE. 23:00 - 23:30 0.50 BOPSUR P PRE HOLD PJSM FOR TESTING BOPE AND FILL UP STACK, CHOKE MANIFOLD AND GAS BUSTER. GAS BUSTER TOOK 6 BBLS TO FILL. - LUSCHE'S CREW HELD KICK DRILL, CRT 85 SEC. 23:30 - 00:00 0.50 BOPSUR P PRE TROUBLE SHOOT TEST MANIFOLD TO FIND BLOCKAGE. 1/2/2012 00:00 - 00:30 0.50 BOPSUR N SFAL PRE CHANGE OUT SWAGELOK VALVE ON BOP TEST MANIFOLD. 00:30 - 03:00 2.50 BOPSUR N RREP PRE DURING BODY TEST NOTICED A LEAK COMING FROM THE DRILLERS SIDE OF THE SHEAR RAM DOOR. SUCKED OUT THE STACK AND CHANGED OUT THE SEAL IN THE SHEAR RAM DOOR. Printed 1/23/2012 11:33:57AM orth.Americ a - ALASKA - BP Page 4 ef.'11' Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 10:00 7.00 BOPSUR P PRE _ BEGIN BOP TEST WITH 3.5" TEST JOINT TESTING THE ANNULAR TO 350 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES EACH TEST. CHARTED. TEST LOWER AND UPPER RAMS 'f WITH 3.5" TEST JOINT TO 350 PSI LOW / 4000 PSI HIGH FOR 5 MINUTES EACH TEST. CHARTED. TEST UPPER AND LOWER RAMS 1C WITH 4.5" TEST JOINT TO 350 PSI LOW / 4000 PSI HIGH FOR 5 MINUTES EACH TEST. CHARTED. TEST BLIND SHEARS TO 350 PSI LOW / 4000 PSI HIGH FOR 5 MINUTES EACH TEST. CHARTED. TEST CHOKE MANIFOLD AND ALL ASSOCIATED BOPE TO 350 PSI LOW / 4000 PSI HIGH FOR 5 MINUTES EACH TEST. CHARTED. WITNESSED BY BP WSL CHRIS KOBUCK AND DOYON TOUR PUSHER MIKE SMITH. STATES RIGHT TO WITNESS WAIVED BY JEFF JONES ON 12/31/11 AT 17:10. 10:00 - 10:30 0.50 BOPSUR P PRE RIG DOWN TEST EQUIPMENT AND BLOW DOWN THE LINES. 10:30 - 12:00 1.50 CLEAN P DECOMP MOBILIZE 3.5" TUBING CASING EQUIPMENT TO THE RIG FLOOR. 12:00 - 13:00 1.00 CLEAN P DECOMP RIG UP CIRCULATING LINES IN THE CELLAR. 13:00 - 16:00 3.00 DHB P DECOMP RIG UP THE DUTCH SYSTEM TO THE STACK, CLOSE THE ANNULAR, MOBILIZE THE LUBRICATOR TO THE RIG FLOOR AND TEST TO 250 PSI LOW / 3500 PSI HIGH. REMOVE THE TWC AND LAYDOWN THE LUBRICATOR. 16:00 - 16:30 0.50 CLEAN P DECOMP PICK UP 1 JT OF 4" DRILL PIPE AND CROSS OVER. SCREW INTO THE HANGER AND RIG UP TO REVERSE CIRCULATE. 16:30 - 21:00 4.50 CLEAN P DECOMP FILL UP THE OUTSIDE HARDLINE AND TEST TO 2500 PSI. GOOD TEST. REVERSE CIRCULATE 40 BBLS AT 3 BPM WITH 810 PSI STAGING UP TO 4 BPM WITH 1600 PSI. BLOW DOWN THE LINES. RIG UP AND CIRCULATE DOWN THE TUBING AND TAKING RETURNS OUT THE IA TO THE OPEN TOP OUTSIDE TANK. CIRCULATE A SAFE - SURF -0 PILL SURFACE TO SURFACE AT 3 BPM WITH 380 PSI STAGING UP TO 3.5 BPM WITH 1060 PSI. CIRCULATED A TOTAL OF 350 BBLS TO THE OUTSIDE TANK. RECOVERING APPROX. 150 BBLS OF DIESEL. 21:00 - 22:00 1.00 WHSUR P DECOMP BACK OUT LOCKDOWN SCREWS MAKE UP THE TOP DRIVE AND PULL THE HANGER TO , THE FLOOR WITH A MAX PULL OF 117K. 22:00 - 23:00 1.00 CLEAN P DECOMP BREAK OUT THE LANDING JOINT AND LAY DOWN THE HANGER, 1 X0 JT OF 4.5" TUBING, X0, AND 2 PUP JTS. 23:00 - 23:30 0.50 CLEAN N RREP DECOMP SUCK OUT THE STACK, REMOVE THE LEAKING DUTCH RISER PIN AND REPLACE THE 0 -RING SEAL AND RE- INSTALL. 23:30 - 00:00 0.50 CLEAN P DECOMP SERVICE AND INSPECT THE TOP DRIVE, BLOCKS, DRAWWORKS, AND STAND PIPE. 1/3/2012 00:00 - 01:00 1.00 CLEAN P DECOMP RIG UP THE CEMENT LINE AND CIRCULATE A BOTTOMS UP AT 299 GPM WITH 830 PSI. 01:00 - 01:30 0.50 PULL P DECOMP FLOW CHECK THE WELL. STATIC. BLOW DOWN THE CHOKE AND KILL LINES. Printed 1/23/2012 11:33:57AM Jorth America- ALASKA - BP Page 5 erg Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 11:00 9.50 PULL P DECOMP LAYDOWN 3.5" TUBING. FROM 8,151' -2.16' MD. (D -1) KICK WHILE TRIPPING DRILL. CREW RESPONDED IN 3 MINS 19 SEC. 11:00 - 12:00 1.00 PULL P DECOMP CLEAR RIG FLOOR OF TUBING SPOOL. 12:00 - 15:00 3.00 PULL P DECOMP CONTINUE TO CLEAR RIG FLOOR, AND LOAD PIPESHED WITH DRILL COLLARS, DRILL PIPE, SAFETY JOINT, AND TEST JOINT. 15:00 - 16:00 1.00 CLEAN P DECOMP MOBILIZE BAKER BHA TO THE RIG FLOOR. 16:00 - 16:30 0.50 CLEAN P DECOMP INSTALL WEAR RING AND HOLD FIRE DRILL. CREW RESPONDED IN 2 MINS. 16:30 - 18:30 2.00 CLEAN P DECOMP PJSM. MAKE UP BAKER CLEAN OUT BHA AS FOLLOWS: - 6.125" USED BIT -BIT SUB - CROSSOVER -ULTRA CLEAN SCRAPER -ULTRA CLEAN BRUSH -NOV BUMPER JAR -NOV HYD JARS 18:30 - 19:30 1.00 CLEAN P DECOMP ATTEMPT TO RUN IN HOLE WITH BHA. TAG UP ON BLIND SHEAR RAM. OFF DRILLER SIDE NOT OPENING. LAY DOWN BHA AND TROUBLESHOOT BLIND RAM, DRAIN STACK, ATTEMPT TO FUNCTION BLIND RAMS SEVERAL TIMES WITH NO SUCCESS, CHECK HYDRAULIC FITTINGS.DISCUSS WITH WTL, ODE, AND DRILLING SUPERINTENDENT ON PLAN TO SECURE WELL TO CHANGE BLIND RAM ACTUATOR. 19:30 - 21:00 1.50 CLEAN N RREP DECOMP MOBILIZE KELLY HOSE TO RIG FLOOR AND WARM UP, PJSM, HANG KELLY HOSE IN THE DERRICK . 21:00 - 22:30 1.50 CLEAN N RREP DECOMP HANG KELLY HOSE ONTO THE TOP DRIVE. PJSM. USE HIGH PRESSURE BYPASS AND ATTEMPT TO FUNCTION RAMS. WITNESSED TROUBLESOME RAM OPEN —2" UNABLE TO FULLY OPEN OFF DRILLER SIDE BLIND RAM. INSTALL 2 -7/8" TEST JOINT WITH FOSV ON TOP. CLOSE LOWER 2 -7/8" X 5 -1/2" VBR ON 2 -7/8" TEST JOINT. TWO MECHANICAL BARRIERS ARE TESTED CEMENT PLUG AND LOWER PIPE RAMS CLOSED ON A JOINT OF 2 -7/8" WITH FOSV. 22:30 - 00:00 1.50 CLEAN N RREP DECOMP PJSM. REMOVE BLIND RAM BONNET, MOUSE HOLE, TURNBUCKLES, TURN STACK YOLK, REMOVE HYDRAULIC LINES FROM BLINDS, OPEN TOP RAM DOOR, REMOVE BOLTS FROM BLIND RAM HINGES. 1/4/2012 00:00 - 04:00 4.00 CLEAN N RREP DECOMP DISCONNECT CHOKE LINE TO MAKE ROOM, REMOVE REMAINING BOLTS ON BLIND RAM DOOR. LAY DOWN DUNNAGE OUTSIDE OF CELLAR IN PREPARATION TO SLIDE NEW BLIND RAM DOOR INTO THE CELLAR. CONTINUE TO LAY DOWN BLIND RAMS. Printed 1/23/2012 11:33:57AM r forth America - ALASKA - BP Page 61'5' Operation Summary Report . Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 06:30 2.50 CLEAN N RREP DECOMP ENSURE ALL LIFTING STRAPS AND CHAINS WERE IN THE PROPER POSITION AND RATED FOR THE LIFT. BLOCK OFF THE CELLAR AREA. REMOVE THE HINGE BOLTS AND SLIDE ACTUATOR OUT OF THE RAM BODY AND LOWER TO THE GROUND. REMOVE THE BLIND SHEAR FROM THE ACTUATOR _ 06:30 - 07:30 1.00 CLEAN P DECOMP LUBRICATE AND INSPECT THE TOP DRIVE, DRAW WORKS, AND RE- INSTALL THE MOUSE HOLE. 07:30 - 12:00 4.50 CLEAN P DECOMP PICK UP 4" DRILLPIPE FROM THE PIPESHED USING THE MOUSEHOLE AND RACKING BACK IN THE DERRICK. 12:00 - 14:00 2.00 CLEAN N RREP DECOMP BUILD A SLIDE AREA FOR BRINGING IN BLIND RAM ACTUATOR, BLEED OFF THE PRESSURE ON WELL S -109. 14:00 - 16:00 2.00 CLEAN N RREP DECOMP BRING ACTUATOR INTO THE CELLAR. 16:00 - 17:30 1.50 CLEAN N RREP DECOMP RIG UP AND LIFT ACTUATOR BACK INTO THE RAM BODY. 17:30 - 19:30 2.00 CLEAN N RREP DECOMP INSTALL THE SHEAR RAM AND ACTIVATE TO ENSURE PROPER MOVEMENT. CLOSE THE DOORS AND INSTALL THE PROPER GASKETS AND O- RINGS. RE- INSTALL THE RAM DOOR BOLTS. 19:30 - 22:00 2.50 CLEAN N RREP DECOMP PJSM. REINSTALL THE CHOKE LINE TO THE MUD CROSS, TURNBUCKLES, AND BOTH MOUSEHOLES. 22:00 - 00:00 2.00 BOPSUR N DECOMP RIG UP AND PREPARE TO TEST BOPE. 1/5/2012 00:00 - 01:00 1.00 BOPSUR N RREP DECOMP FILL THE PILL PIT WITH WATER FOR THE BOP TEST. HOLD A BOP DRILL AND FILL THE GAS BUSTER (6 BBLS). 01:00 - 01:30 0.50 BOPSUR N RREP DECOMP TEST THE ANNULAR WITH THE 3.5" TEST JOINT TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES EACH TEST. GOOD TEST. CHARTED. 01:30 - 03:30 2.00 BOPSUR N RREP DECOMP BLEED OFF PRESSURE AND SHUT DOWN TO TIGHTEN LEAKING BLIND /SHEAR HINGES. 03:30 - 09:00 5.50 BOPSUR N RREP DECOMP CONTINUE BOP TEST AS FOLLOWS: - CHOKE VALVES 1, 12, 13, 14, TOP RAMS, HCR KILL, AND IBOP - CHOKE VALVES 9, 11, AND MANUAL IBOP - CHOKE VALVES 5, 8, 10 AND 4" FOSV - CHOKE VALVES 4, 6, 7 AND 4" FOSV - CHOKE VALVE 12 AND 4" DART VALVE Ai - ALL TEST PERFORMED WITH 3.5" TEST 1 JOINT IN THE HOLE AND TO 250 PSI LOW /2� 4000 PSI HIGH FOR 5 MINUTES EACH TEST. CHARTED. - TESTS WITNESSED BY BP WSL CHRIS KOBUCK AND DOYON TOUR PUSHER HARRY GOUCHENAUER. STATES RIGHT TO WITNESS WAIVED BY MATT HERRERA AT 08:00 ON 1/4/2012. 09:00 - 12:00 3.00 BOPSUR N RREP DECOMP BLOW DOWN CHOKE AND KILL LINES AND PERPAIR FOR REMOVEAL OF HCR CHOKE VALVE. 12:00 - 14:30 2.50 BOPSUR N RREP DECOMP CONTINUE TO INSTALL HCR CHOKE VALVE, AND CHOKE LINE ONTO THE STACK, HELD TABLE TOP DIVERTER DRILL. Printed 1/23/2012 11:33:57AM •othAmericakLASKA-.BF' Pag 7 rrs Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 16:30 2.00 BOPSUR N RREP DECOMP PJSM, FILL EVERYTHING WITH WATER AND CHECK FOR LEAKS, TEST HCR CHOKE LINE 250 PSI 5 MIN, AND 4000 PSI HIGH FOR 5 MIN. GOOD TEST. RIG DOWN TEST EQUIPMENT. 16:30 - 17:00 0.50 BOPSUR N RREP - DECOMP DRAIN STACK AND INSTALL WEAR RING. 17:00 - 18:00 1.00 CLEAN N RREP DECOMP PJSM. MAKE UP BAKER CLEAN OUT BHA AS FOLLOWS: - 6.125" USED BIT -BIT SUB -ULTRA CLEAN SCRAPER -ULTRA CLEAN BRUSH -NOV BUMPER JAR -NOV HYD JARS - CROSSOVER -6 4-3/4" SPIRAL DRILL COLLARS 18:00 20:30 2.50 CLEAN P ■- DECOMP RUN IN THE HOLE PICKING 4" DRILL PIPE. FROM M 225' -- 2094' FILL PIPE. KELLY HOSE LEAKING. 20:30 - 21:30 1.00 CLEAN P DECOMP PJSM. REMOVE KELLY HOSE. 21:30 - 23:30 2.00 CLEAN P -_ DECOMP CONTINUE TO RUN IN HOLE PICKING UP 4" DRILL PIPE FROM 2094'- 3276'. 23:30 - 00:00 0.50 CLEAN P DECOMP RIG UP CEMENT LINE TO FILL PIPE. 1/6/2012 00:00 - 00:30 0.50 CLEAN P DECOMP FILL PIPE AT 82 GPM AND 50 PSI. 00:30 - 01:30 1.00 CLEAN P DECOMP REPLACE PULL BACK CABLE ON SKATE. 01:30 - 03:30 2.00 CLEAN N RREP _ DECOMP FINISH REPAIRING PULL BACK CABLE, AND INSTALL KELLY HOSE. 03:30 06:30 3.00 CLEAN P ■- DECOMP SINGLE IN THE HOLE FROM - ESMAILK A'S CREW HELD D-1 -1 DRILL, CRT 133 SEC. 06:30 - 09:00 2.50 CLEAN P DECOMP RUN IN THE HOLE WITH 4" DRILL PIPE FROM THE DERRICK SCRAPPING THE FOLLOWING AREAS 2 TIMES. 7990' - 8030' AND 8090' - 8130'. TAGGED UP AT 8152'. 09:00 - 12:30 3.50 CLEAN P DECOMP DISPLACE THE WELL OVER TO 10.5 PPG LSND. UP WT 170K / DOWN WT. 130K/ ROT. WT. 145K ROTATING AT 60 RPM WITH 5K FREE TQ. PUMP A Hl-VIS SPACER FOLLWED BY 10.5 PPG LSND AT 6.5 BPM WITH 1280 PSI. OBTAIN SLOW PUMP RATES. MUD PUMP 1 AT 8152' MD - 20 SPM WITH 400 PSI - 30 SPM WITH 400 PSI 12:30 - 15:30 3.00 CLEAN P DECOMP PULL OUT OF THE HOLE FROM 8152' - 225'. ■- - LUSCHE'S CREW HELD KICK WHILE TRIPPING G DRILL, 60 CRT 60 SEC. 15:30 - 16:00 0.50 CLEAN P DECOMP RACK BACK 4.75" DRILL COLLARS, LAY DOWN CROSS OVER, BIT SUB AND BIT TO THE RIG FLOOR AND THE REMAINDER OF THE BHA TO THE PIPESHED. 16:00 19:00 3.00 EVAL P ■- DECOMP STAGE THE E-LINE UNIT NEXT TO THE RIG AND ND MOBILIZE THEIR TOOLS TO THE RIG FLOOR. 19:00 - 00:00 5.00 EVAL N DFAL DECOMP RUN IN THE HOLE ON E -LINE WITH U, S `` IBC /GPIT /GR/CCL TO LOG FOR CEMENT W BOND QUALITY AND TOC. Printed 1/23/2012 11:33:57AM . orth Ame[iti - ALASKA ;SP ., - yM �+ FW a Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 1/7/2012 00:00 - 07:00 7.00 EVAL N DFAL DECOMP CONTINUE TO RUN ON E -LINE WITH IBC /GPIT /GR/CCL TO LOG FOR CEMENT BOND QUALITY AND TOC. - CARLOS CREW HELD A TABLE TOP H2S DRILL. te:,k, o 07:0 0 - 10:00 3.00 EVAL N DFAL DECOMP DOWNLOAD E -LINE LOGS AND SEND TO ' TOWN. 10:00 - 11:00 1.00 EVAL N DFAL DECOMP CHANGE OUT E -LINE TOOL FROM THE ISOLATION SCANNER TO THE USIT, BECAUSE OF TOOL MALFUNCTION. 11:00 - 15:00 4.00 EVAL P DECOMP RUN IN HOLE WITH USIT TOOL. 15:00 - 22:00 7.00 EVAL P DECOMP LOG WITH USIT TO SURFACE, DOWN LOAD USIT DATA. RUN IN THE HOLE WITH EZSV AND SET AT 8131' MD. PULL OUT OF HOLE WITH E -LINE AND CONFIRM EZSV SET 5� FIRE DRILL CREW RESPONDED IN 1 MIN 12 �'G SEC. 22:00 - 23:00 1.00 DHB P DECOMP RIG DOWN E -LINE. 01;, 23:00 - 00:00 1.00 DHB P DECOMP RIG UP AND TEST EZSV 250 PSI 5 MIN AND 3500 PSI30 MIN. GOOD TEST BLOW DOWN CHOKE AND KILL LINES. 1/12/2012 00:00 - 00:30 0.50 PXA P DECOMP 00:30 - 02:00 1.50 PXA P DECOMP 02:00 - 03:00 1.00 PXA P DECOMP 03:00 - 06:30 3.50 PXA P DECOMP 06:30 - 08:30 2.00 PXA P DECOMP 08:30 - 09:30 1.00 PXA P DECOMP V 09:30 - 10:30 1.00 PXA P DECOMP 10:30 - 16:00 5.50 PXA P DECOMP ,J 16:00 - 18:00 2.00 PXA P DECOMP 18:00 - 19:00 1.00 PXA P DECOMP / / I 19:00 - 20:00 1.00 PXA P DECOMP 20:00 - 20:30 0.50 PXA P DECOMP 20:30 - 00:00 3.50 PXA P DECOMP 1/13/2012 00:00 - 01:00 1.00 TA P DECOMP 01:00 - 02:00 1.00 PXA P DECOMP 02:00 - 02:30 0.50 PXA P DECOMP 02:30 - 03:00 0.50 PXA P DECOMP 03:00 - 03:30 0.50 PXA P DECOMP 03:30 - 04:00 0.50 PXA P DECOMP 04:00 - 04:30 0.50 PXA P DECOMP 04:30 - 05:00 0.50 PXA N DPRB 3,187.99 DECOMP 05:00 - 05:30 0.50 PXA N DPRB 3,187.99 DECOMP 05:30 - 06:00 0.50 PXA N DPRB 3,187.99 DECOMP 06:00 - 07:00 1.00 PXA N DPRB 3,187.99 DECOMP 07:00 - 08:00 1.00 PXA N DPRB 3,187.99 DECOMP 08:00 - 08:30 0.50 PXA N DPRB 3,187.99 DECOMP 08:30 - 09:30 1.00 PXA N DPRB 3,187.99 DECOMP Printed 1/23/2012 11:33:57AM Vryr t Al�r - ALASI{A - BP ' , Page, 9 eft '.Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:30 - 10:00 0.50 PXA N DPRB 3,187.99 DECOMP 10:00 - 12:30 2.50 PXA N DPRB 3,187.99 DECOMP 12:30 - 13:00 0.50 PXA N DPRB 3,187.99 DECOMP 13:00 - 14:00 1.00 PXA N DPRB 3,187.99 DECOMP 14:00 - 14:30 0.50 PXA N DPRB 3,187.99 DECOMP 14:30 - 15:00 0.50 PXA N DPRB 3,187.99 DECOMP 15:00 - 15:30 0.50 PXA N DPRB 3,187.99 DECOMP 15:30 - 16:00 0.50 PXA N DPRB 3,187.99 DECOMP 16:00 - 16:30 0.50 PXA N DPRB 3,187.99 DECOMP 16:30 - 17:00 0.50 PXA N DPRB 3,187.99 DECOMP 17:00 - 18:30 1.50 PXA N DPRB 3,187.99 DECOMP 18:30 - 19:00 0.50 PXA N DPRB 3,187.99 DECOMP 19:00 - 19:30 0.50 PXA N DPRB 3,187.99 DECOMP 19:30 - 23:00 3.50 BOPSUR P DECOMP 23:00 - 00:00 1.00 BOPSUR P DECOMP 1/14/2012 00:00 - 01:00 1.00 FISH N DPRB 3,187.99 DECOMP 01:00 - 02:00 1.00 FISH N DPRB 3,187.99 DECOMP 02:00 - 02:30 0.50 FISH N DPRB 3,187.99 DECOMP 02:30 - 03:00 0.50 FISH N DPRB 3,187.99 DECOMP 03:00 - 04:30 1.50 FISH N DPRB 3,187.99 DECOMP 04:30 - 05:30 1.00 FISH N DPRB 3,187.99 DECOMP 05:30 - 07:00 1.50 FISH N DPRB 3,187.99 DECOMP 07:00 - 08:00 1.00 FISH N DPRB 3,187.99 DECOMP 08:00 - 09:30 1.50 FISH N DPRB 3,187.99 DECOMP 09:30 - 11:00 1.50 FISH N DPRB 3,187.99 DECOMP 11:00 - 11:30 0.50 FISH N DPRB 3,187.99 DECOMP 11:30 - 12:00 0.50 FISH N DPRB 3,187.99 DECOMP 12:00 - 13:30 1.50 FISH N DPRB 3,187.99 DECOMP 13:30 - 14:30 1.00 FISH N DPRB 3,187.99 DECOMP 14:30 - 16:30 2.00 FISH N DPRB 3,187.99 DECOMP 16:30 - 17:00 0.50 FISH N DPRB 3,187.99 DECOMP 17:00 - 18:00 1.00 FISH N DPRB 3,187.99 DECOMP 18:00 - 19:00 1.00 FISH N DPRB 3,187.99 DECOMP 19:00 - 20:00 1.00 FISH N DPRB 3,187.99 DECOMP 20:00 - 22:00 2.00 FISH N DPRB 3,187.99 DECOMP 22:00 - 22:30 0.50 FISH N DPRB 3,187.99 DECOMP 22:30 - 23:30 1.00 FISH N DPRB 3,187.99 DECOMP 23:30 - 00:00 0.50 FISH N DPRB 3,187.99 DECOMP 1/15/2012 00:00 - 03:00 3.00 FISH N DPRB 3,187.99 DECOMP 03:00 - 03:30 0.50 FISH N DPRB 3,187.99 DECOMP 03:30 - 06:00 2.50 FISH N DPRB 3,187.99 DECOMP 1/16/2012 00:00 - 00:30 0.50 CLEAN P DECOMP LUBRICATE RIG. Printed 1/23/2012 11:33:57AM ortfi America - A[ -ASKA - E3P Page 10 ef°i'4 .Operation Summary Re port, Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:30 - 02:30 2.00 CLEAN P DECOMP RUN IN HOLE FROM 1457'- 3145'. CIRCULATE AND WORK PIPE AT 60 RPM 420 GPM 550 PSI 2415' -2445' TO CLEAN UP CONTINGINCY WHIPSTOCK SFTTING DFPTH 02:30 - 03:30 1.00 CLEAN P DECOMP TAG UP AT 3145' WASH DOWN TO 3198' WITH 250 GPM 400 PSI 20 RPM 2K TQ. PUMP 30 BBL HIGH VIS SWEEP SURFACE TO SURFACE WORKING SCRAPER 3186- 3193'. 03:30 - 05:00 1.50 CLEAN P DECOMP BLOW DOWN TOP DRIVE AND PULL OUT OF HOLE TO DRILL COLLARS. 05:00 - 07:00 2.00 CLEAN P DECOMP STAND BACK COLLARS, LAY DOWN SCRAPPER BHA, AND CLEAN AND CLEAR RIG FLOOR. 07:00 - 08:00 1.00 CLEAN P DECOMP RIG UP SCHLUMBERGER E -LINE AND BRING HALLIBURTON 9 -5/8" EZSV RUNNING TOOL TO THE FLOOR. 08:00 - 08:30 0.50 CLEAN P DECOMP MAKE UP E -LINE GAUGE RING JUNK BASKET 08:30 - 10:00 1.50 CLEAN P DECOMP RUN IN HOLE WITH GAUGE RING JUNK BASKET. UNABLE TO GET PAST 1275'. 10:00 - 10:30 0.50 CLEAN N DPRB 1,275.00 DECOMP PULL OUT OF HOLE ON E -LINE. 10:30 - 13:00 2.50 CLEAN P DECOMP CHANGE OUT 8.75" GAUGE RING FORA 8.4" GAUGE RING AND RUN IN HOLE TO 3170'. PULL OUT OF HOLE WITH GAUGE RING. 13:00 - 15:30 2.50 CLEAN P DECOMP CHANGE OUT GAUGE RING WITH 9 -5/8" EZSV. RIH AND SET AT 3165'. 15:30 - 17:00 1.50 CLEAN P DECOMP PULL OUT OF HOLE WITH ELINE, RIG UP AND TEST EZSV. -250 PSI 5 MIN, 3000 PSI30 MIN -LOST 0 PSI IN FIRST 15, AND 0 PSI IN LAST 15. 17:00 - 20:00 3.00 CLEAN P DECOMP RIG DOWN E -LINE, BLOW DOWN CHOKE MANIFOLD, CHOKE AND KILL LINES, AND MOBILIZE WINDOW MILLS TO THE FLOOR. 20:00 - 20:30 0.50 CLEAN P DECOMP MAKE UP WHIPSTOCK BHA. 20:30 - 23:30 3.00 CLEAN N HMAN DECOMP FLOAT SUB IS NOT BORED OUT TO HOLD A FLOAT. WAIT ON NEW FLOAT SUB TO BE SENT FROM SCHLUMBERGER SHOP. 23:30 - 00:00 0.50 CLEAN P DECOMP CONTINUE TO MAKE UP WINDOW MILLING BHA. 1/17/2012 00:00 - 03:30 3.50 CLEAN P DECOMP FINISH MAKEING UP 8.75" WINDOW MILLING ASSEMBLY AND RUN IN THE HOLE TO 3131' AND STACK UP. SLOWLY PUT 20K WOB TO SEE IF WE CAN SLIDE THROUGH. GENTLY PICK UP 10' WITH 95K. SLOWLY GO DOWN AGAIN AND STACK UP WITH 20K WOB. FIRST UPPER STRING MILL CORRESPONDING WITH PREVIOUS TIGHT SPOT AT 1,301'. 03:30 - 05:00 1.50 CLEAN N DPRB 1,301.00 DECOMP PULL OUT OF HOLE WITH WHIPSTOCK from 1301' TO 397' 05:00 - 08:00 3.00 CLEAN N DPRB 1,301.00 DECOMP RACK BACK COLLARS LAY DOWN WHIPSTOCK AND MILLS FROM 397' TO SURFACE 08:00 - 10:00 2.00 CLEAN N DPRB 1,301.00 DECOMP PJSM WITH ALL HANDS, MAKE UP 83/4 MILLS AND STABILIZER TO ATTEMPT TO SWEDGE CASING, RUN IN TO 437' 10:00 - 11:00 1.00 CLEAN N DPRB 1,301.00 DECOMP RUN IN HOLE FROM 437' TO 1301' SET DOWN 8K IN TIGHT SPOT, WORK THROUGH SEVERAL TIMES UNTIL CLEAR Printed 1/23/2012 11:33:57AM orth`Ailierica T ALASKA - BP Page 11 ** Operation Summary Report Common Well Name: S -110 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 12/27/2011 End Date: X3- 00WJN -C (6,037,167.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 14 Spud Date/Time: 8/11/2001 12:00:OOAM Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: 500292303000 Active Datum: S -110 @69.55ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:00 - 11:30 0.50 CLEAN N DPRB 1,301.00 DECOMP CIRCULATE BOTTOMS UP AT 210 GPM, 310 PSI 11:30 - 13:00 1.50 CLEAN N DPRB 1,301.00 DECOMP CONTINUE TO RUN IN HOLE FROM 1301' TO 3180' TAG UP ON EZSV 13:00 - 14:00 1.00 CLEAN N DPRB 1,301.00 DECOMP CIRCULATE SUPER SWEEP AROUND 450 GPM, 580 PSI 14:00 - 15:00 1.00 CLEAN N DPRB 1,301.00 DECOMP PULL OUT OF HOLE FROM 3180' TO 437' 15:00 - 17:00 2.00 CLEAN N DPRB 1,301.00 DECOMP RACK BACK COLLARS CHANGE OUT 83/4 MILLS TO 8 1/2 17:00 - 19:30 2.50 CLEAN N DPRB 1,301.00 DECOMP RUN IN HOLE WITH 8 1/2" MILLS TO 1350' PULL OUT OF HOLE WITH MILLS FROM 1350' TO SURFACE ABLE TO GET MILLS THROUGH OBSTRUCTION DID NOT TAKE WEIGHT 19:30 - 21:30 2.00 CLEAN N DPRB 1,301.00 DECOMP RIG UP AND TEST 9 5/8 CASING 250 PSI LOW FOR 5 MIN 2000 PSI HIGH FOR TEN MIN TEST HELD 0 PSI BLEED OFF 21:30 - 00:00 2.50 CLEAN N DPRB 1,301.00 DECOMP PICK UP MWD AND ORIENT MAKE UP WHIPSTOCK TO MILLS AND RIH TO 1050' SHALLOW HOLE TEST MWD 500 GPM, 420 PSI 1/18/2012 00:00 - 02:30 2.50 WHIP N DPRB 1,301.00 WEXIT CONTINUE TO RUN IN HOLE WITH WHIPSTOCK FROM 1050' TO 3130' () I:4k 02:30 - 03:30 1.00 WHIP P WEXIT ORIENT WHIPSTOCK 38 DEG RIGHT OF HIGHSIDE (( SET WHIPSTOCK ON TOP OF EZSV AT 3180'. 5 UP WT 100K, SOW 90K SET DOWN 15K TO SET ANCHOR, PICK UP 15K OVER TO CONFIRM SHEAR OFF MILLS WITH 45K 03:30 - 09:30 6.00 STWHIP P WEXIT BEGIN MILLING OPERATIONS TOP OF WINDOW AT 3158' S -1 \,O - MILLING FROM 3158' TO 3186' -480 GPM, 900 PSI, 80 RPM, 8K TQ -PUW 110K, SOW 95K, RTW 100K SPR TAKEN @ 3158' MD, 2682' TVD PUMP 1 @ 2BPM 100 PSI @ 3BPM 150 PSI PUMP 2 @ 2BPM 100 PSI @ 3BPM 150 PSI 09:30 - 10:00 0.50 STWHIP P WEXIT CIRCULATE 30 BBL HI VIS SWEEP - GPM 462, PSI 910 10:00 - 11:30 1.50 STWHIP P WEXIT RIG UP PERFORM LEAK OFF TEST -850 PSI, 15.53 PPG EMW - PUMPED 1.5 BBLS, BLEED BACK 1 BBL -TEST APPROVED BY ODE KRIS HONAS 11:30 - 13:00 1.50 STWHIP P WEXIT CONTINUE MILLING FROM 3186' TO 3192' -480 GPM, 900 PSI, 80 RPM, 8K TQ -PUW 110K, SOW 95K, RTW 100K 481 LBS OF METAL RECOVERED 13:00 - 14:30 1.50 STWHIP P WEXIT PJSM WITH ALL HANDS - DISPLACE WELL TO 9.0 PPG LSND MUD SPR TAKEN @ 3195' MD, 3173' TVD PUMP 1 @ 2BPM 130 PSI @ 3BPM 160 PSI PUMP 2 @ 2BPM 130 PSI @ 3BPM 160 PSI 14:30 - 16:30 2.00 STWHIP P WEXIT POOH FROM 3192' TO 437' Printed 1/23/2012 11:33:57AM . . TREE = 4" LLHEAC FAA Completion 707 BF. ELEV = 36.4' KOP= 3165' Max Angle = 72 8174' Datum M0= 8020' I I 2000' H4-1 (2" HES X Mpple, ID 3.81] Datum1'VD 6700' SS 3165" H9 -5 /E" 40# CSG, L-80, BTC-M 0=8.835" 3165" F-I Top or 9-5' Vdndovr 4165' -J TOC(280'WDabove UG4a) 7737' j-j 41/2" HES X Nipple, lD3.8l3"j 7794' }7"x41I2"I'ESThTPKR 7904' H 41/2" HES XNpple03.813"J 9-518' Baker Gen A 7946' 4-1(2' HES X Npple, 03.813" Whipstock �% - 7936' J-I 4-1/TTBG12.6#, LEO, TC-ll,1D3.958" I L 7956J ToPorFl:H VAM TOP lD"6 276 7" CSG CUT � _� I \( , 4 8154 - Bottom at Rsh: bit, rotary GAS LIFT Ma,NDRELS steerable kpluse MWO ® M) WOes 0EV J!Ya LATCH • adnVtSl(»1475 LWt) 3x NM Flex LI 3500 DCX2 RK DC's Circulation Sub. 2x XO's J 6288 5300 7653 6478 Jars 1 H 6-118" Pr oduction bo le (A DATE - REV BY CO.ENrS DATE REV BY I C�aVVENTS AURORA UNijT 02/09111 K9 8110A Completion WELL: S-110A PERNk API SEC 3S,TI2N,R12E,44g8'Fa&4481'FSL - - . BP Explorat ton (Alaska) S -110A Update and Minor Mud Weight Change Page 1 of 2 ID Schwartz, Guy L (DOA) From: Honas, Kristopher [Kristopher.Honas @bp.com] Sent: Friday, January 20, 2012 12:19 PM To: Schwartz, Guy L (DOA) a.-01-11 Subject: RE: S -110A Update and Minor Mud Weight Change Guy, No, there was no need to shoot and squeeze the casing for isolation of the lower reservoirs. We had very good cement isolation between both the Kuparuk/Schrader and Schrader /Ugnu. The original USIT log from 2001 was performed a little too early after cement was in place and was most likely logging cement with very low compressive strength. We did involve global experts both from BP and SLB in interpretation of the new log and isolation of the reservoirs was agreed unanimously. Thanks, Kris Honas BP Rotary Drilling Engineer Desk: 907 - 564 -4841 CeII: 907 - 268 -0891 _ ( c Kristopher.Honas@bp.com t ` ' �" From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, January 20, 2012 12:06 PM To: Honas, Kristopher Subject: RE: S -110A Update and Minor Mud Weight Change Kris, The change in mud weight is approved. Glad you guys got the casing out. I assume you didn't do any shoot and sqz cement in the annulus below the casing cut. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Honas, Kristopher [ mailto:Kristopher.Honas @bp.com] Sent: Friday, January 20, 2012 12:00 PM To: Schwartz, Guy L (DOA) Subject: S -110A Update and Minor Mud Weight Change Guy, About two weeks ago we had discussed the potential suspension of operations on S -110A due to a USIT log indicating cement in the OA, preventing a casing cut and pull. We did not end up deciding to move off S -110 and we were able to get the 7" casing cut and pulled. It took multiple cuts and a bit of jarring, but ultimately we have been able to continue on with operation as planned in the original drilling permit. I'm emailing you today to let you know that we plan to use only a 10.5 ppg mud to reach TD of the intermediate interval top setting the Kuparuk. The current permit to drill indicates that we will weight up to 10.8 ppg. The heavier mud was initially planned for wellbore stability through the HRZ and was not necessary for well control. The HRZ in this particular area is only -10 ft TVD. We have experience in the 1/20/2012 S -110A Update and Minor Mud Weight Change Page 2 of 2 • area drilling the HRZ at our planned inclination and Azimuth with the lower mud weight. 10.8 ppg was being ultra conservative for shale stability. A 10.5 ppg mud weight will reduce ECD and the potential of lost circulation &/or wellbore breathing in the Colville and still provide adequate overbalance. We did a leak off test at the window and achieved a 15.5 ppg LOT. The 10.5 ppg mud weight provides a kick tolerance of greater than 50 bbls. With your approval we would like to make this minor change to the drilling program. Thank you, Kris Honas BP Rotary Drilling Engineer Desk: 907 - 564 -4841 Cell: 907 - 268 -0891 Kristopher.Honas @bp.com 1/20/2012 S -110A Brine Weight Modification from Permit to Drill Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, November 08, 2011 9:13 AM To: 'Honas, Kristopher' Subject: RE: S -110A Brine Weight Modification from Permit to Drill (PTD 201 -129) Kris, S -I r o Since CT is going to lay in a cement plug up into the tubing the well will be isolated from the reservoir. Assuming this cement plug (CMIT) passes a pressure test to 4000 psi as per your procedure the 9.8 KWF brine would not be required for the initial RWO operations. Seawater would be an acceptable completion fluid. This email is sufficient notification for the change in approved procedure. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Honas, Kristopher [mailto:Kristopher.Honas @bp.com] Sent: Monday, November 07, 2011 3:57 PM To: Schwartz, Guy L (DOA) Subject: S -110A Brine Weight Modification from Permit to Drill Guy, The permit to drill for S -110A states that during pre -rig work we will turn the well over to 9.8 ppg brine and freeze protect with diesel. Then once the rig moves on we will circulate out the diesel with 9.8 ppg brine. There is not any need to utilize a 9.8 ppg brine at this point in the well. Instead, we would like to use 8.4 - 8.5 ppg seawater during the pre -rig work and initial circulation once the rig moves over the well. As previously planned, the well will be swapped to a kill weight fluid prior to perforating casing to complete P &A work and prior to milling a sidetrack window. I wanted to both let you know that this change is desired and ask if there is anything other than this email which is necessary to make this change official. Having worked years ago with the AOGCC an email was all that was necessary, however, I'm not sure that is still the case? Thank you for your help in this matter, Kris Honas BP Rotary Drilling Engineer Desk: 907 - 564 -4841 Cell: 907 - 268 -0891 Kristopher.Honas@bp.com 11/8/2011 • • IE [HP ELAsgp SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Ken Allen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 ao Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Aurora Pool, S -110 Sundry Number: 311 -285 Dear Mr. Allen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Chair DATED thisZi — day of September, 2011. Encl. STATE OF ALASKA 4'1Z.11 a ,11 "E IVG ALASKA •AND GAS CONSERVATION COMMISSS`�`/ `aEP 6 2011 ' D . APPLICATION FOR SUNDRY APPROVAL o 20 AAC 25.280 Alaska nil & Gas Cosa. CORVIIinfeli 1. Type of Request: rh ❑ Abandon - ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Pro -- -- g- o Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 201 - 129 3. Address: - ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50 - 029 - 23030 - - - 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: SA10- Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028257' Prudhoe Bay Field / Aurora Pool ( a , f ,„( /,,,,,) 11. PRESENT WELL CONDITION SUMMARY Q Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8792' - 7116' ' 8690' 7014' None Yes, Unknown Depth Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 3432' 9-5/8" 3466' 2883' 5750 3090 Intermediate Production 8742' 7" 8773' 7097' 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8480' - 8524' 6804' - 6848' 3 -1/2 ", 9.3# L -80 8528' Packers and SSSV Type: 7" x 3 -1/2" Baker 'S -3' packer Packers and SSSV 8305' / 6630' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development - ® Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 1, 2011 ❑ OiI ❑ WINJ ❑ WDSPL Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned 1 Commission Representative: ❑ WAG ❑ SPLUG _ ('Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Kris Honas, 564 -4841 Printed Name Ken Allen Title Engineering Team Leader Prepared By Name/Number: Signature - . Phone 564 -4366 Date? Terrie Hubble, 564 -4628 ,/ C7 — -- / / / Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 31 1 ( Sundry Number U ❑ Plug Integrity t1d BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: i LN /i0 �JS�. A0-1 .........-4--t_ i °' 1T l h+.f:+t / A t,2r�.; / P p �ProPore fey-- Z® �Ac ZS / /Z�e) Subsequent Form Required: / 0 °- APPROVED BY ( 1 • Approved B .)\ COMMISSIONER THE COMMISSION Date Q4 A 2011 � 4 • Submit In Duplicate Form 1� �' J CI' 1 G 2 LY�� / - 1/ �� , , !GINA , k$ • • 14 b P 011‘0 1 {� iA `i 4) � V *•"'" GP O S - 11 0 Well Type: Injector Current Status: The well is currently shut -in. MITOA passed to 2000 psi 8/16/2010 MITIA passed to 4000 psi 8/16/2010 Operations noted tree growth of -2 ", the flutes are still in the conductor and a 1700 psi differential was observed between Tubing & IA 01/13/10 Request: Approval is requested for plug and abandonment of the Prudhoe Bay Unit Well S -110. S -110 is a slant injector which has poor Injectivity due to siderite cement distribution. S -110 was completed in 2001 as a pre - produced injector. Well production averaged 300 -700 bopd. Cumulative production was 0.16 MMbbis. In 2003, the well was converted to a WAG injector. Injection rate began at 1800 bwpd, but the rate dropped off to less than 100 bwpd. S -110 is on boosted injection pressure but injection rates have always been low. Recent injection rates are 350 -600 bwpd. Static pressure was 3570 psi in July 2009. A step -rate test was performed in May 2010 to monitor injection changes before setting a Wavefront tool. The Wavefront tool was a free trial to increase injectivity by pulsating injected water near the perfs, however, there was not any noticeable improvement. Therefore, a rig sidetrack is the most attractive option. Scope of Work: The S -110 perforations will be plugged and abandoned during pre; rig operations by laying cement across the perforations to a depth 100 ft above the production packer. The tubing will be cut approximately 200 ft above the production packer. A USIT log will be ran after the tubing is pulled by ✓ the rig. The USIT will determine cement isolation between the Kuparuk and Schrader formation and the Schrader and Ugnu formation for permanent abandonment (original 2001 USIT results indicate poor isolation). Cement isolation will be achieved behind 7" intermediate casing by perforating the casing and circulating 100 ft of cement behind casing between each of the primary oil bearing sands. Details are described in the operations summary (If the USIT log does indicate cement isolation, a solid cement plug will be set from a minimum of 500 ft MD below the Schrader to a minimum of 500 ft MD above the Schrader). Following the cement abandonment, 7" casing will be cut and pulled from inside the surface casing shoe. An EZSV plug will be placed above the casing stump and a whipstock exit from the 9 -5/8" surface casing will allow an 8 -3/4" intermediate hole to be drilled to the top of the Kuparuk formation. The interval will be cased and cemented with 7 ", 26# casing bringing top of cement approximately 250 ft TVD above the shallowest heavy oil zone in the Ugnu. The production interval for S -110Ai will be a horizontal 6 -1/8" hole drilled to the East - Northeast over approximately 3700 ft. The base plan is to complete the interval with a 4 -1/2" liner utilizing multiple swell packers and sliding sleeves for zonal isolation and selective injection into the Kuparuk. S -110A injection will support production for S -109. MASP: 2785 psi - S /c✓ �� l�l/ Estimated Start Date: Nov 1st, 2010 Cde�GV� . �AJec t�g,, , <O�t dp q fool ("Alecto,- s vc h 6"11}/d Ploy 6k / 0 ;// 'O'% £4't �� -Gr 4 ,1" i � e tare // , �`nv/ci /lam, G l/ fro VGfv4 k ,'n ✓ e"/O coo !ec D EC £ / ' (9 4 f41) /b ch btu' 0-4 fi ,00r -(On/ • • Pre -Riq Work: 1. E Obtain static bottom hole pressure survey at datum TVDss of 6700 ft. 2. E Punch tubing tail below packer at -8315 ft MD. 3. C RIH with coil to PBTD (or top of fish). Lay -in 18 bbls of 15.8 ppg class G cement bringing TO • - estim- ed 6-6 • • I ■■ II Circulate out any excess cement from 8205 ft. 4. C Drift and tag TOC (minimum required TOC at 8305' MD). 5. F MIT -T to 4000 psi. `Ii -t P. 6. C Displace the tubing to 9.8 ppg NaCI brine. • 7. E Jet cut tubing at -8155' MD in the middle of a joint. 8. F CMIT -T x IA to 4000 psi. Circulate 9.8 ppg brine around the tubing cut and freeze protect the well bore to -2000 ft TVD. 9. F MIT -OA to 2000 psi. 10. W PPPOT -T to 5000 psi. PPPOT -IC - 4000 psi. Function LDS. 11. V Set BPV Proposed Drilling Riq Operations: 1. Move in and rig up Doyon 14./ 2. Pull the BPV with tested lubricator, circulate out diesel freeze protection and displace the well to 9.8 ppg brine through tubing cut at -8155 ft MD. 3. Set BPV and test to 1000 psi from below for 10 minutes. • 4. Rig up OA to bleeder tank and bleed pressure to zero psi. Monitor to ensure well is dead in preparation for 7" cut and pull. 5. Nipple down tree and tubing adapter. Nipple up and test BOPE to 250 psi low / 4000 psi high (3500 psi on the annular) with 3.5" and 4" test joints. Note: Install spacer spool above the tubing spool to allow testing of the lower set of rams prior to pulling tubing. 6. Pull BPV with tested lubricator per FMC. ' 7. Pull and laydown 3 -1/2 ", 9.3 #, L -80 tubing from the cut depth at -8155 ft MD. - 8. Make a cleanout run with full gauge mill, boot baskets and used 6 -1/8" roller cone bit to top of the • tubing stub. 9. Swap the well over to a 10.4 ppg LSND fluid (used fluid is ok) and POH with cleanout assembly. • 10. RU E -line and run a CCL /USIT log from top of the tubing stub to surface to confirm 7" top of cement, collar locations, and verify no cement is present above the surface shoe. Note: If USIT log results demonstrate a minimum of 100 ft of fully bonded cement between the TKC4 and SB_OBf base and also between the SB_Nb and Ug Ma base then steps 11 through 22 are not necessary, instead a cement plug will set from 500 ft below the SB OBf to 500 ft above the SB Nb. 11. RIH with a 7" EZSV bridge plug on E -line and set at -8120 ft MD. 12. Rig up lubricator and pressure test. RIH with E -line and perforate a 5 ft interval in the 7" casing at -8100 ft MD. Perforate a second 5 ft interval at 8001 ft MD (99 ft above first perforations). Run a y gauge ring (minimum 5.560 ") through the upper perforation interval to ensure and EZSV packer can drift. Rig down E -line and lubricator. 13. Run in hole with a 7" EZSV cement squeeze packer on 4" drill pipe. Set EZSV at -8021 ft MD between the perforation intervals. Break circulation through perforations behind 7" casing and condition hole for cement. Note: If circulation is not achieved, increase pressure over formation fracture gradient and inject -5 bbls to verify zonal isolation. 14. Rig up and test cement lines. Pump -10 bbls of cement to fill casing x 7" annulus. Un -sting from EZSV ✓ and lay in an additional 40 bbls of cement on top of the EZSV. Circulate out excess cement from 1000 ft above cement retainer. 15. Continue to circulate above TOC while waiting for cement to reach 200 psi compressive strength. . Weight test the cement plug by setting down 15K. • • 16. POH. Wait on cement to reach 1500 psi compressive strength. Pressures test the cement plug to 2500 psi for 30 minutes and chart. 17. Rig up E -line and run a gauge ring. Pick up and set an EZSV bridge plug at -6524 ft MD. 18. Rig up lubricator and pressure test. RIH with E -line and perforate a 5 ft interval in the 7" casing at -6524 ft MD. Perforate a second 5 ft interval at 6425 ft MD (99 ft above first perforations). Run a gauge ring (minimum 5.560 ") through the upper perforation interval to ensure and EZSV packer can drift. Rig down E -line and lubricator. 19. Run in hole with a 7" EZSV cement squeeze packer on 4" drill pipe. Set EZSV at -6445 ft MD between the perforation intervals. Break circulation through perforations behind 7" casing and condition hole for cement. Note: If circulation is not achieved, increase pressure over formation fracture gradient and inject -5 bbls to verify zonal isolation. 20. Rig up and test cement lines. Pump -10 bbls of cement to fill casing x 7" annulus. Un -sting from EZSV and lay in an additional 40 bbls of cement on top of the EZSV. Circulate out excess cement from 1000 ft above cement retainer. 21. POH with drill pipe and rig down cementers. 22. Make -up a Baker 7" multi- string cutting assembly and RIH. Wait on cement to reach 200 psi compressive strength and tag top of the cement abandonment plug setting down 15K. 23. Wait on cement to reach 1500 psi compressive strength. Pressures test the cement plug to 2500 psi for 30 mintites and chart 24. Pick up to target cut depth 10 - 20 ft inside the 9 -5/8" surface casing shoe (depending on USIT results). Cpt the 7" casing per Baker representative's instruction. Displace the annulus with 10.0 - 10.4 ppg LSND and pump sweeps of Safe -Surf-O as needed until returns clean up. POH and lay down multi- string cutter. Note: Be prepared for diesel freeze protect and potentially dead crude in OA returns. 25. Pull the mandrel hanger and 7" casing from the cut through the Wellhead /BOPE per FMC. 26. Make up the Baker 8 -3/4" full gauge window mill, including the two full gauge watermelon mills. Drift the 9 -5/8" casing down to the 7" stub. Ensure the mills easily drift through the surface casing float PfA� collar and shoe track starting at 3382 ft MD. 27. Run in hole with 9 -5/8" EZSV confi • ured a - • ri • • - • . • • 4 , " • 4 - - • • • m 4f EZSV at 3423 ft MD, four feet above the collar in the second joint from the shoe based on original surface casing pipe tally. POH. 28. Pressure test the EZSV to 2500 psi for 30 minutes and chart. 29. Pick up 9 -5/8" whipstock, bottom trip anchor, 8 -3/4" full gauge window milling assembly, and MWD. Run in hole. orient whipstock 45° right of high side set whipstock enc:hnr nn F7SV 30. Mill an 8 -3/4" window in the 9 -5/8" casing with 10.0 - 10.4 ppg LSND milling fluid. Ensure a minimum of 20 ft of new formation is milled and the upper watermelon mill fully exits the window. Circulate the well clean and pull back into 9 -5/8" casing. 31. Perform an FIT to 12.6 ppg EMW. POH and lay down milling assembly, verify mills are in gauge. Note: A minimum of 12.6 ppg EMW is required for a 25 bbl kick tolerance if pore pressure is 9.9 ppg with 0.5 ppg kick intensity (10.8 ppg drilling fluid). A 12.2 ppg FIT is required for a 25 bbls kick Pro tolerance with a 0.3 ppg kick intensity 32. Pick up 8 -3/4" drilling assembly with PDC bit, bent housing motor, and DIR /GR /RES /PWD. Kick -off S /(a A and drill 8 -3/4" intermediate interval to the top of the Kuparuk (TKC4). Circulate the wellbore clean and POH. Note: Weight up to 10.5 ppg prior to crossing fault #1 at -6300 ft TVDss Note: Weight up to 10.8 ppg prior to reaching the top of the HRZ. Weight up slowly over multiple circulations. 33. Change out upper rams from variables to 7" casing rams and test from 250 psi low / 4000 psi high. 34. Run 7 ", 26 #, L -80, Vam Top HC casing. Cement casing with LiteCrete lead that brings calculated top of cement to 250 ft TVD above the UG4. Follow with a 15.8 ppg Class G tail which covers 1000 ft MD of annulus above the shoe. Note: following cement job, line up to the OA and inject -10 bbls to verify annulus is clear. Continue to inject 5 bbls down the annulus every hour until cement reaches 500 psi compressive strength and well is freeze protected. 35. Change upper rams back to 3.5" x 6" variables. Test from 250 psi low / 4000 psi high with 4" and 4.5" test joints. • • 36. Freeze protect the Outer Annulus (7" x 9 -5/8 ") with diesel to -2000 ft TVD by rigging up Little Red Hot Oil and bullheading (this can be done off the critical path at a convenient time). 37. Make up a 6 -1/8" drilling assembly with PDC bit, bent housing motor, and DIR /GR /RES /DEN /NEU. RIH and tag float collar. 38. Pressure test the 7" casing to 4000 psi for 30 minutes and chart. 39. Swap the well over to 10.2 - 10.4 ppg Rheliant oil based drilling fluid. Note: Density may be adjusted based on pre -rig bottom hole pressure survey to maintain >100 psi overbalance. 40. Drill out the 7" shoe track and 20 ft of new formation. Circulate the well clean and pull into the 7" shoe. Perform an FIT to 12.0 ppg EMW. Note: 10.9 ppg required to maintain Infinite kick tolerance assuming 9.9 ppg pore pressure and 0.5 ppg kick intensity (10.3 ppg mud weight) 41. Drill 6 -1/8" production hole geo- steering through the Kuparuk as directed by the on -site geologist to TD. 42. Circulate until returns are clean minimum 3x bottoms up. Short trip back to 7" casing shoe, performing MAD pass as required to obtain Azimuthal Caliper logs through slide intervals. Circulate minimum of 1 bottoms up inside 7" casing shoe. 43. Trip back to TD on elevators. Note: It is extremely important that all tight spots are wiped as the plan forward targets no circulation following placement of the open hole pill in the next step. 44. Spot a clean 10.4 ppg Rheliant liner running pill in the open hole. The pill should be newly refurbished mud directly from the MI plant in deadhorse. The density of the pill should be 0.2 ppg over the completion brine discussed in later steps. Spot the pill as a balanced plug and ensure enough volume is pumped to fill the entire open hole volume plus 500 ft when drill pipe is removed. 45. POH on elevators. Wipe any tight spots without pumps or rotation if possible to preserve the clean Rheliant pill in open hole. 46. RIH with 4 -1/2 ", 12.6 #, L -80, TCII solid liner with sliding sleeves and swell packers. Ensure all sliding sleeves are in the closed position. Ensure floats are holding. 47. Circulate 1.5x the liner volume after picking up the liner hanger /packer at 3 bpm (Verify ECD with MI Virtual Hydraulics to verify flow rate). 48. Continue in hole to the 7" shoe on 4" drill pipe. Break circulation if necessary to condition drilling fluid. Adjust running speed as dictated by fluid displacement. Do not exceed 45 seconds /joint. Circulate an additional 1.5x liner volumes at the shoe. 49. Run liner into open hole to TD. Avoid any circulation in open hole due to clean Rheliant pill. Note: if circulation is required to reach TD, another clean Rheliant pill must be spotted in the open hole prior to setting the liner top packer. 50. Drop ball and land in liner running tool. Increase pressure to set liner hanger. Set liner top packer per Baker Rep. Prior to pulling the running tool out of the liner top, pressure test the liner top packer to 4000 psi for 30 minutes and chart test. 51. Swap the well over to a clean 10.2 ppg NaCI /NaBr brine. The target brine density will be -100 psi overbalance to formation pressure based on the latest static bottom hole pressure survey performed during pre -rig work for S -110. 52. POH and lay down running tool. 53. Rig up E -line and run a gauge ring to the 4 -1/2" liner top. Obtain a CCL /USIT log from the top of the liner to surface. Verify 100 ft TVD of full cement coverage between the Kuparuk and Schrader. Additionally, verify 100 ft TVD of full cement coverage between the top of the Ug_Mc and TOC. 54. Run 4 -1/2 ", 12.6 #, L -80, TCII tubing. Space out tubing tail pipe inside liner tieback sleeve. Land hanger and run in lock down screws. 55. Circulate corrosion inhibited brine into the inner annulus. 56. Drop the ball and rod and set the production packer. Continue to pressure up to 4000 psi, hold for 30 minutes and chart test. Bleed pressure to 2500 psi. Pressure test the inner annulus to 4000 psi for 30 charted minutes. Bleed tubing pressure to sheer the gas lift valve and reverse circulate to confirm sheer. 57. Set a TWC with T -bar and test from below to 1000 psi for 10 minutes. 58. Nipple down the BOPE. Nipple up the double master valve and test to 5000 psi. 59. Verify OA and IA pressure is zero, if not; install VR plugs in the annulus. 60. Rig up lubricator and pull the TWC • • 61. Reverse in a sufficient volume of diesel to freeze protect the wellbore to 2000 ft TVD and allow diesel to u -tube. 62. Set a BPV. Secure the wellbore. 63. Rig down and move off well. Post -Rio Work: 1. Install remaining sections of the tree with electric surface safety valve. 2. Pull BPV. 3. Rig up slickiine and replace the shear valve with a dummy gas lift valve. Pull the ball and rod / RHC no -shear plug from the X nipple profile in the tubing tail. 4. Rig up coil and set a bridge plug in the tubing tail immediately above the 3 -1/2" anchor swell packer. Circulate out the oil based mud in the liner with clean brine. Shift open the sliding sleeves. 5. Flow well back to a test separator to clean out oil based mud behind production liner. 6. Install Wellhouse and fiowlines. Drilling Engineer: Kristopher Honas (907) 564 -4841 Production Engineer: Taylor West (907) 564 -4647 Geologist: Bob Dawson (907) 564 -5264 ATTACHMENTS: Current Schematic Pre -Rig Schematic De- Completion Schematic Proposed Schematic TREE= 4" • • , WELLHEAD = FMC 11" SAFETY NOTE: UNSHOT 4-5/8" I-ES SCALLOP GUNS ACTUATOR = NA S -110 (5 SPF) @ 8480' - 8528'. HES FIRING HEAD @ 8398' KB. ELEV = 70.8' BF. ELEV = 36.4' ) KOP = 642' I ) \ I 72' H 4-1/2" X 3 -1/2" XO, ID = 2.992" Max Angle = 54 @ 2202' Datum MD= 8445' ■ - -I 1030' H TAM PORT COLLAR I Datum TVD = 6700' SS t ' I 2175' (� 3-1 /7' HES X NIP, ID = 2.813" I 9-5/8" CSG, 40#, L -80 BTC -M ID = 8.835" H I 3466' GAS LIFT MANDRELS ST ND TVD DEV TYPE VLV LATCH PORT DATE 3 4656 3608 46 MNG MY RK 0 07/15/03 Minimum ID = 2.375" @ 8397' I � 1 I 2 7002 5291 24 NNNG DMY RK 0 07/15/03 2 -7/8" X 3-1/2" XO 1 8254 6508 3 MVIG CMY RK 0 07/15/03 • I 8124' H 20' SHORT JT. W /RA TAG I 1 1 I 8282' H 3 -1/2" HES X NP, ID = 2.813" I Z — 8305' H 7" X 3 -1/2" BKR S-3 PKR ID= 3.875" 1 1 I 8330' H 3 -1/2" HES X NIP, ID = 2.813" 1 1 1 1 8351' H 3 -1/2" HES X NIP, ID = 2.813" I 13-1 /2" TBG, 9.3#, L -80, .0087 bpf, ID = 2.992" H 8361' I �I 8397' (—I 3 -1/2" X 2 -7/8" XO, ID= 2.375" I PERFORATION SUMMARY �/ 8398' H TCP FIRING HEAD, ID = 2.500" ( REF LOG: SS MWD GR ON 08/26/01 8404' H AUTO RELEASE FORTCP GUN, ID = 2.700" I ANGLEATTOP FERF: 3 @ 8480' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 4 -5/8" 5 8480 - 8524 0 10/03/01 • I 8548' H 20' SHORT JT W/ RA TAG 1 �I TCP SCA LLOP GUNS PBTD 8690' I 1'�'1/11��'�'� 44 44 44 1 7" CSG, 26 #, L -80 BTGM, ID = 6.276" 8773 DATE REV BY COMMENTS DATE REV BY COMPEM S AURORA UNIT 09/01/01 CH/tlh ORIGINAL COMPLETION WELL: S -110 10/13/01 TMNAIh TCP PERF GUN SHOT PERMIT No: 2011290 04/09/03 DRS/TP TVD /MD CORRECTIONS API No: 50- 029 -23030 07/15/03 PWE/KK GLV C/O SEC 35, T12N, R12E, 4498' FEL & 4481' FSL BP Exploration (Alaska) TREE = 4" WELLHEAD ATOR FMC 1NA SA 1 Ci P &A ( SAFETY Ni UNSOT 4-5/8" HES SCALO 6 SPF) @ '-85 8H HES FIRING HEAD@ 839 GUNS KB. ELEV = 70.8' BF. ELEV = 36.4' KOP = 642' —I 72' I 4-1/2" X 3-1/2" XO, ID = 2.992" Max Angle = .. 54 4 2202' Datum MD= 8445' � 1030' H TAM PORT COLLAR Datum TV D = 6700' SS I 2175' H 3 HES X NIP, ID = 2.813" I I 9 -5/8 ", 47 #, L -80 BTC-M, ID = 8.835" H 3466' I GAS LIFT MANDRELS ST MD TVO DEV TYPE VLV LATCH PORT DATE LI 3 4656 3608 46 MMG DMY RK 0 07/15/03 2 7002 5291 24 MMG DMY RK 0 07/15/03 1 8254 6508 3 MMG DMY RK 0 07/15/03 Minimum ID = 2.375" @ 8397' 7 " Casing Estimated TUC Between: 2 -7/8" X 3 -1/2" X4 4478' MD (40% excess) and 2273' MD (0% excess) based on 165 bbls 7 / 8205' I1P1anned TOC (8305 I3 -112" Tbg Cut I ( 8155' I minimum) i I I I 8282' I-1 3-1/2" HES X NIP, ID = 2.813" I Z -- 1 8305' H 7" X 3 -1/2" BKR S -3 PKR. ID = 3.875" IP- I 3 -1/2" TBG perforations -5 ft interval H 8315' I--- - r • 1 I 8330' H 3 -1/2" HES X NIP, ID = 2.813" I ' t 8351' H 3 -1/2" HES X NIP, ID = 2.813" I 3-1/2", 9.3#, L -80, .0087bpf, NS -C —i 8773' Fes_ ID= 2.992" ,I 8397' I—I 3-1/2" X 2-7/8" XO, ID = 2.375" I PERFORATION SUMMA RY / 8398' ji TCP FIRING HEAD, ID = 2.500" I REF LOG: SS MWD GR ON 08/26/01 I 8404' H AUTO RELEASE FOR TCP GUN, ID = 2.700" I ANGLE AT TOP PERF: 3 @ 8480' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn /Sqz DATE 4-5/8" 5 8480 - 8524 0 10/03/01 - II 8548' H 20' SHORT JT W/ RA TAG I lk I H TCP SCA LLOP GUNS I PBTD I I 8690' I . 7" CSG, 26 #, L -80 BTC-M, ID = 6.276" H 8773' e ' A ' • , A ' A ' e ' • ' • ♦ • ' • ' • , DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT' 09/01/01 CH/tlh ORIGINAL COMPLETION WELL: S -110A 10/13/01 TMN/tIh TCP PERF GUN SHOT PERMIT No: 2011290 04/09/03 DRS/1'P TVD/MD CORRECTIONS API No: 50- 029 -23030 07/15/03 PWEIKK GLV C/O SEC 35, T12N, R12E, 4498' FEL & 4481' FSL 12/09/09 PJP /SV PERF DRAWING BP Exploration (Alaska) - TREE .= 4" WELLHEAD = FMC 11" SAFETY : UNSHOT 4 -5/8" FES SCALLOP GUNS ACTUATOR = NA S -11 e- complete (5 SPF) @'- 8528'. HES FIRING HEAD @ 8398' KB. ELEV = 70,8' BE ELEV = 36.4' - KOP= 642' —1 72' I—I 4-1/2" X 3 -1/2" XO, ID = 2.992" I Max Angle = 54 @ 2202' Datum MD = 8445' = 1030' H TAM PORT COLLAR I Datum ND = 6700' SS 3420' I-1 9 -5/8" HES QSV Bridge Plug I 9 -5/8 ", 47 #, L -80 BTC-M, ID = 8.835" H 3466' 4 1111111111111w-411111111111111111111 3446' H 7" casing cut and pull I I 5445' H TOC 7" Casing Perforations -5 ft Interval H 6425' (Must be less than 100 ft above lower perf ® j 6445' H 7", 26#, HES EZSV Cement Retainter interval) ��� � � Pump 10 bbls of 15.8 G cement ® I 7" Casing Perforations -5 ft Interval I-I 6524' I through EZSV cement retainter around perforations. Unsting and lay an I 7", 26 #, HES EZSV Bridge Plug (—I 6544' I additional 40 bbls above retainer 7021' I--1 roc I 8021' H I 7 ", 26 #, HES EZSV Cement Retainter 7" Casing Perforations -5 ft Interval —I 8001' I C1 (Must be less than 100 ft above lower perf PINV■11411111� 5 interval) P ump 10 bbls of 15.8 G cement through EZSV cement retainter around I 7" Casing Perforations -5 ft Interval I-1 8100' ® ' perforations. Unsting and lay an I 7", 26#, HES EZSV Bridge Plug I—{ 8120' I PIBSw■ligl additional 40 bbls above retainer l I3 -1/2" Tbg Cut I 1 8155' I I 8205' H Planned TOC 8282' H 3 -1 /2" HES X NIP, ID = 2.813" 1 z , I 8305' I—f 7" X 3 - 1/2" BKR 5 -3 PKR, ID = 3.875" I I 3 -1/2" TBG perforations -S ft interval I-1 8315' I as PP- I I I 8330' I-i 3 -1/2" HES X NIP, ID = 2.813" I 1 8351' I—{ 3-1/2" HES X NIP, ID = 2.813" I 3 -1/2 ", 9.3#, L -80, .0087bpf, NSTC IH 8773' Imo_ ID= 2.992" 8397' H 3 -1/2" X 2 -7/8' XO, ID = 2.375" I 7" Casing estimated TOC between: 8398' I—I TCP FIRING HEAD, ID = 2.500" 4478' MD (40% excess) and 2273' MD la:r:[[f (0% excess) based on 165 bbls, 8404' H AUTO RELEASE FOR TCP GUN, ID = 2.700" I However, 2001 USIT results do not show cement bond. P &A requires [ cement squeeze to issolate permeable oil reservoirs with potential for ■ I 8548' H 20' SHORT JT W/ RA TAG 1 production. Illik TCP SCALLOP GUNS IPBTD I I 8690' I . I 7" CSG, 26 #, L -80 BTC-M, ID = 6.276" I 8773' 4 DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 09/01/01 CH/tlh ORIGINAL COMPLETION WELL: S -110A 10/13/01 TMN/tlh TCP PERF GUN SHOT PERMfT No: r 2011290 04/09/03 DRS/TP ND/MD CORRECTIONS API No: 50 -029 -23030 07/15/03 PVVEIKK GLV C/O SEC 35, T12N. R12E, 4498' FEL & 4481' FSL 12/09/09 PJP /SV PERF DRAWING BP Exploration (Alaska) S -11i! TA Proposed K� .ELEV= 70. ttt BF. ELEV = 36. �t - 1030' H TAM Port Collar I KOP= 339: / Max Angle = 95 @ 1016 Datum MD = 8021 i.,.... 1 I 2000' H 4-1/2" HES X Nipple, ID 3.813" I Datum ND = 6700' S I 3466' 1-19-5/8" 40# CSG, L -80, BTC-M, ID 8.835" I 3395' J- Top of 9-5/8" Window 4195' H TOC (250' TVD above UG4) I 7763' H 4-1/2" HES X Nipple, ID 3.813" I 7794' N 7" x 4-1/2" HES TNT PKR j 7830' H 4-1/2" HES X Nipple, ID 3.813" I 1" Baker Gen II • 7862' 4 -1/2" HES X Nipple, ID 3.813" stock @ 3417' '+ 18•. 7884' -J 4 - 1/2' TBG 12.6#, L80, TC - II, ID 3.958" I ' 7888' 7" X 5" BKR ZXP PKR & LNR HGR, 0=4.43" " QSV @ 3420' ■111/ 8036' I — { T' 26# CSG, L -80, VAM TOP, ID 6.276" CSG CUT @3446' r S 11746' ]- - /2" 12.6# Solid LNR, L -80, TCII, ID 3.958" p 01 -7ea: 41/7' HES Sliding Sleeve F "' `TBD, TBD', TBD', TBD' TBD', TBD', 8.113U I : : "`: { PBTD @ -11750' - lea: 4 J2" HES OBM Sw e0 Packers TBO, TBI7, TBD&Y , T, TBD, 7617, & TBD i ( TO 11761 GAS LIFT MANDRELS � ST MD TVDss DEV TYPE VLV LATCH PORT ' 3 4353 3500 43 MG DCK2 RK 1" 2 6288 5300 15 NAG DMY RK 1" 1 7653 6478 46 IVIIMG DMY RK 1" I 11694' 1-I XO 4 1/2" TCII x 3 1/2" TCII I 11699' H 3-1/Z HES OBM Sw ell Packer I 11731' 1—I XO 3-1/2" TCII x 4-1/2" TCII I 11746' I—I HES 4 -1/2" Float Collar & Shoe DATE REV BY COMMENTS DATE REV BY COMMENTS AURORA UNIT 08/10/11 IBi S110A Proposed Sidetrack WELL: S -110A PERMIT No: A PI No: SEC 35, T12N, R12E, 4498' FEL & 448' BP Exploration (Alaska) ! • b BP Exploration (Alaska) Ina ~;,' ` ~ Attn: Weli Integrity Coordinator, PRB-20 " Post Office Box 196612 ,`~' Anchorage, Alaska 99519-6612 June 25, 2009 ^ ~ ` Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, ~~~'~~:~~~:'~ ~ ~.,~ ~' ~' 2~~Q~ Torin Roschinger BPXA, Well Integrity Coordinator ~ BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) S-pad ~ ~nte 6/25/2009 Wetl Name PTD # Initial top of cement Vol. o( cement um ed Final top of cement Cement top off date Conosion inhibitor Corrosion inhibitod sealant date ft bbis ft na al S-O18 1952020 025 NA 0.25 NA 2.6 5/30/2009 S-02A 1941090 025 NA 0.25 NA 1.7 5/25/2009 S-03 1811900 1325 NA 13.25 NA 92.65 5/20/2009 S-04 1830790 0 NA 0 NA 0.9 5/25/2009 s-o5A 1951890 0 NA 0 NA o.s 5/26/2009 5-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA O.s 5/26I2009 S-O88 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 1821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.4 5/31/2009 S-118 1990530 025 NA 025 NA 1.7 5/2~/2009 S-12A 1851930 025 NA 025 NA t.7 6/1/2009 5-13 1821350 8 NA 8 NA 55.3 6/1/2009 S-15 1840170 0.25 NA 025 NA 3 6/2/2009 S-t7C 2020070 0.25 NA 0.25 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2/2009 S-~s 1861160 0.75 NA 0.75 NA 22 5I79/2009 S-20A 2010450 0.25 NA ~ 025 NA t.3 5/79/2009 S-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 5-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 5-23 1901270 025 NA 025 NA 1.7 5/25/2009 S-24B 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.6 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 S-278 2031680 0.5 NA 0.5 NA 2.6 5/31/2009 5-288 2030020 0.5 NA 0.5 NA 2.6 5/31/2009 S-29AL1 7960120 0 NA 0 NA 0.85 5/27/2009 5-30 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S31A 1982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26I2009 5-34 1921360 0.5 NA 0.5 NA 3.4 5/31/2009 S-35 1921480 0 NA 0 NA .85in 5/31/2009 5-36 1921160 0.75 NA 0.75 NA 425 5/27/2009 S-37 1920990 1.25 NA 125 NA 11.9 5/27/2009 S38 1921270 025 NA 025 NA 102 5/27/2009 S-41 1960240 1.5 NA 1.5 NA 11.1 5/30/2009 5-42 1960540 0 NA 0 NA 0.9 5/30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 S-44 1970070 025 NA 0.25 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 5-101 2001150 125 NA 125 NA 11.9 5/29/2009 5-102L7 2031560 1.25 NA 125 NA 11.1 5/31/2009 S-103 2001680 7.5 NA 1.5 NA 11.9 5/18/2009 S-704 2001960 1.75 NA 7.75 NA 15.3 5/20/2009 5-105 2001520 4 NA 4 NA 32.7 5/20/2009 5-106 2070120 1625 NA 1625 NA 774.3 6/2/2009 S-707 2011130 225 NA 225 NA 2a.9 5/18/2009 S-~oe 2071000 3.5 NA 3.5 NA a0 5/30/2009 5-109 2022450 2 NA 2 NA 27.3 5/30/2009 St10 ~ 2011290 17.75 NA 11.75 NA 98.6 5/30/2009 S-17~ 2050510 2 NA 2 NA 79.6 5/30/2009 S-t72 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1,75 NA 1.75 NA 22.1 5/18/2009 5-114A 2021980 125 NA 125 NA 102 5/30/2009 5-115 2022300 2.5 NA 2.5 NA 272 5/29/2009 5-116 2031810 1.5 NA 7.5 NA 13.6 5/28/2009 5-117 2030120 1.5 NA 1.5 NA ~5.3 5/29/2009 5-118 2032000 5 NA 5 NA 76.5 5/28/2009 S-1~s 2041620 1 NA 1 NA 52 5/30/2009 5-120 2031980 5.5 NA 5.5 NA 672 5/29/2009 S-121 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 S-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-123 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 S-12a 2061360 1.75 NA 1.75 NA 7t.9 5/2&2009 S-125 2070830 2.25 NA 225 NA 20.4 5/28/2009 S-126 20710970 125 NA 125 NA 15.3 6/1/2009 S-200 1972390 1.25 NA 125 NA 14.5 5/2B/'L009 S-201 2001840 0 NA 0 NA 0.85 6/19/2009 S413A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 5-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 5-217 2070950 025 NA 025 NA 1.7 6/1/2009 S-400 2070740 2 NA 2 NA 9.4 5/28/2009 S-401 2060780 16 NA 16 NA 99.5 6/2I2009 5-504 0 NA 0 NA 0.85 5/28/2009 • MEMORANDUM ~ State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, September 10, 2008 k ~9 Tai Jim Regg ~ Z° cl~ P.I. Supervisor ' ` ~ ~ t ~ SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-I 10 FROM: Bob Noble PRUDHOE BAY UN AURO S-] 10 Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ~ QL NON-CONFIDENTIAL Comm Well Name: PRUDHOE BAY UN AURO S-1 t0 Insp Num• mitRCN080910064907 Rel Insp Num: API Well Number: 50-029-23030-00-00 Permit Number 201-129-o Inspector Name: Bob Noble Inspection Date• 9i9i2oos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well s-uo Type Inj. W TVD ~ 6630 IA z2o aooo aooo aooo P.T. ~ 2011290 ITypeTest sPT Test psi I aooo OA ~ ~o sao sao sao ~ Interval 4YRTST per, P ~ Tubing j zlso I 21so 21 so ~ zlso i Notes: _u rr Wednesday, September 10, 2008 Page 1 of I e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _Iuserts\Microfilm _ Marker.doc STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATION~CT 0 52004 1. Operations Performed: Abandon 0 Alter Casing 0 Change Approved Program 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): "", 69.55 8. Property Designation: ADL-0028257 11. Present Well Condition Summary: Total Depth measured 8792 true vertical 7116.0 feet 8566 Repair Well 0 PluÇJ PerforationsD Pull TubingO Perforate New PoolO Operation Shutdown 0 Perforate 0 Stimulate 0 Alaska W~as~y!.r\JBrtftffl!!'fðn WaiverD Time Extension~chorage Re-enter Suspended Well 0 5. Permit to Drill Number: 201-1290 6. API Number 50-029-23030-00-00 4. Current Well Class: Development 0 Exploratory 0 Service ŒJ Stratigraphic 0 9. Well Name and Number: S-110 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool feet Plugs (measured) / Junk (measured) None Effective Depth measured 8690 feet true vertical 7014.1 feet Casing Conductor Production Surface Length 80 8742 3432 Perforation depth: Measured depth: 8480 - 8524 Size 20" 91.5# H-40 7" 26# L-80 9-5/8" 40# L-80 MD TVD 35 - 115 35.0 - 115.0 31 - 8773 31.0 - 7097.0 34 - 3466 34.0 - 2883.3 1490 7240 5750 Burst Collapse 470 5410 3090 True vertical depth: 6804.41 - 6848.35 Tubing (size, grade, and measured depth): 4-1/2" 12.6# L-80 3-1/2" 9.3# L-80 Packers & SSSV (type & measured depth): 4-1/2" Baker S-3 Perm Packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Daily Average Production or Injection Data Gas-Met Water-Bbl Casing Pressure 0.5 16 1260 0 -3413 700 13 Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys run- Daily Report of Well Operations - ! @ 29 @ 72 72 8404 @ 8305 Oil-Bbl 413 0 Tubing Pressure 286 1933 15. Well Class after proposed work: Exploratory D 16. Well Status after proposed work: OilD GasD DevelopmentD Service Œ] WAG ŒI GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-123 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Garry Catron j1: Calron ~ Signature SCANNED OCT 0 9 2004 Form 10-404 Revised 4/2004 Title Production Technical Assistant ~ Phone 564-4657 Date 9/28/04 n ~::",¡;",../' I INAL MtWL oct Q ö lUU~ S-110 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 06/02/04 First day of WAG injection BBLS 0 ITOTAL SCANNED OCT 0 9 2004 FLUIDS PUMPED No Fluids Pumped Page 1 TREE = 4" ,WB..LHEAD = FMC 11" A CTLLA. TOR = NA - ~ ~-,,~~, ,KB. ELEy = 70.8' B F. ELEV = 36.4' KÖP = . 642'- ri.1äX Ang'~'~' "'54--@"22CJ2ï' DaturiÙŸ;b = " . MA5' Datum iVD =' . 670Ö;'SS I 9-518" CSG, 40#, L-80 BTC-M, ID = 8.835" H 3466' ~ Minimum ID = 2.375" @ 8397' 2-718" X 3-1/2" XO 13-1/2"TBG,9.3#,L-80,.0087bpf,ID=2.992" H 8361' I PERFORATION SLIv1MA. RY REF LOG: SS MND GR ON 08/26/01 ANGLE A TTOP ÆRF: 3 @ 8480' I'bte: Refer to A"oductbn œ for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" 5 8480 - 8524 0 10/03/01 I PBTD H 8690' I I 7" CSG, 26#, L-80 BTC-M, ID = 6.27fj' H 8773' I DATE 09/01/01 10/13/01 04/09/03 07/15/03 REV BY COMMENTS CH/tlh ORIGINAL COMPLEfION TMN/tlh TCP PERF GLN SHOT DRSrrp TVD/MD CORRECTIONS PWElKK GLV C/O 8-11 0 = \ i L SAFETY NOTES: UNSHOT 4-5/8" ÆS SCALLOP GlJ\IS (5 SPF) @ 8480'-8528". ÆS FIRING HEAD@ 8398' 72' H 4-112" X 3-1/2" XO, ID = 2.992" J =--1 1030' H TAM PORT COLLAR I I 2175' H 3-1/2"I-ESX J\lP, ID=2.813" J ~ ST MD 3 4656 2 7002 1 8254 GAS LIFT MANDRELS lV D DEV TYPE V LV LATCH PORT DATE 3608 46 tv'MG D'v1Y RK 0 07/15103 5291 24 tv'MG D'v1Y RK 0 07/15103 6508 3 tv'MG D'v1Y RK 0 07/15103 II----f 8124' H2O' SHORT JT. W/RA TAG I I I I 8282' H 3-1/2" HES X NIP, ID = 2.813" I :8: :8:' I 8305' H 7" X 3-1/2" BKR &3 A<R, ID = 3.875" J ~ J I 8330' H 3-1/2" HES X NIP, ID = 2.813" I I 8351' H 3-1/2" HES X NIP, ID = 2.813" I .....-1 8397' H 3-1/2" X 2 -7/~' XO. ID = 2375" I ,/ ~ 8398' H TCPFIRlNG HEAD, ID= 2.500" I L " " r I 8404' H A UfO RELEASE FOR TCF GUN. ID = 2.700" ! " ~ DA TE REV BY SCANNED OCT 0 9 2004 II----f 8548' H 20'SHORT JTW/RA TAG I I H TCPSCALLOPGLNS I COMMENTS A LRORA UNIT WELL: S-110 PERMT I'b: 2011290 API I'b: 50-029-23030 SEC 35, T12N, R12E, 4498' FEL & 4481' FSL BP Exploration (Alaska) /'*'. ~ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg -;-:) I P.I. Supervisor f<,c?f( c¡ ~)~ DATE: Wednesday, September IS, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) lNC S-IIO PRUDHOE BAY UN AURO S-IIO a.OI-'~ FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv :::J1?"e.- Comm Well Name: PRUDHOE BAY UN AURO S-110 Insp Num: mitLG040914134033 Rei Insp Num: NON-CONFIDENTIAL API Well Number: 50"029-23030-00-00 Permit Number: 201-129-0 Inspector Name: Lou Grimaldi Inspection Date: 9/14/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-IIO Type Inj. N TVD 6630 IA 240 4000 3940 3920 P.T. 2011290 TypeTest SPT Test psi 1657,5 OA 0 0 0 0 Interval 4YRTST P/F P Tubing 340 350 350 350 Notes: Wednesday, September 15,2004 Page I of I MEMORANDUM State of Alaska Alaska Oil and Gas Con~f'rvation Commission TO: Jim Regg. ~ì.í1 fctZi((''t- P.I. SUpf'nll~Or \ -f\. DATE: MQnday. June ~ I. ~OO-1 SlI8JECT: MechamcallntegrH)' Tests BP EXPLORA. nON (ALASK.A I fNC FROM: Jeff Jones Petroleum Inspector 5-110 PRUDHOE BAY UN AURO S-IIO Src: Inspector Rniewed 8,.: P.I. Suprv :J$,c..- Comm NON-CONFIDENTIAL Well Name: PRUDHOE BA Y UN AURO S-110 API Well Number: 50-029-23030-00-00 Insp Num: mitJJ040621070111 Permit Number: 201-129-0 Rellnsp Num: Inspector Name: Jeff Jones Inspection Date: 6/18/~OO4 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-110 Type Inj. F TVD 7116 IA ~ÚO ..1000 I P.T. ~01129ú TypeTest SPT Test psi 1657.5 OA Û 0 Interval -IYRTST PIF F Tubing 2590 2590 Notes: Pre ~11 swap 1'\'1IT failed due to external leak at API ring gasket between m~ter \'ahe & tubing hanger spool Monday. June 21, 2004 Page I of I 05/19/2004 08:58 9075644005 ,,-...... PETROTECH_DATA_CNTR: ,-..., PAGE 01 bPO SP Exploration (Alaska) Inc. 900 East Benson Boulevard f.O. Box 196612 Anchomge. Alaska 99519.6612 (907) 561.5111 May 18. 2004 Winton Aubert Alaska on & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Fax 276a 7542 Dear Winton: RE: Sundry Notjç!;.Jor S~lJ9 Gas Injection (permit #2Ql-12991. In order to enhance water injection rates and fine-tune enhanced oil recovery benefits, a 3 month gas injection pilot h~ administrative approval (457A.OO3 and 33B.OOl) for Aurora injection wells S-112, 5-110, and Sal16. Per AOGCC request, attached is a IOA03 for $-110 which will be on gas injection for a maximum of 3 months in 2004. Offset penetrations within 'A mile of S-11Oi and a water-flow log were approved with the original 10-403 application to verify that the well has been completed in accordance with 20 AAC / 25.412. No new wells have penetrated the proposed injection interval within the area of interest since this information was last provided. If you have any questions, please contact Jim Young, Aurora Petroleum Engineer, at 564-5754 or byemail at Youngj3@bp.com. Sincerely; ,j / .' \ ( ~ ~ Jim Young Aurora Petroleum Engineer RECEIVED MAY 1 9 2004 .-.01 & GII Cia ~ Aid" Page ¡ OR\G\NAL i. Type of R$( uest: . AbMdon 0 Alter Casing 0 Change Approved Program I!J ...... . 2. operator Name: BP Exploration (Alaska), Inc. 3. Address: P.O. Box 196612 .. Anehorage, Ak ~9519-6612 7. KB Elevation (ft): .- ... 69.5~.....KB 's. Property Designation: AOL-o28257 05/19/2004 08:58 PETROTECH DATA CNTR: """'-'1" PAGE" eì~ ....-~, STATE OF ALASKA - ~ RECE\VED Ap;~~~~~:~A~~;S~~~~~C~;M~S~~NVAL MAY 192004 20 MC 25.2a.~.. ,.QI.ß-GøII'~ perforateD waiverdnc\.~r DispoaalD StimulateD TIme ExtensionD Other 0 Re.enter Suspended WeliO 5. Pennlt to Drill Number; 201-1290 /' 9075644005 ,-...., Suspend 0 Repair Well 0 / Pull Tubing 0 Operation Shutdown 0 Plug PerforatiOn$ 0 Pertorate New Pool 0 ,..,.- 4. Current wëil Class: ., Development 0 Exptoratory 0 6. API Number / 50-029-23030-00-00 Stratigraphic 0 Service Œ] / 9. Well Name and Number; 5-110 / 10. ï=ïëld/Pool(s): . .'" _~r~dhoe Bay Field I Aurorël Oil Pool. PRESENT WELL CONDITION SUMMARY ¡Effective Depth Me (ft):. - IEffective DEtpth f\tD (ft):" 8690 6944.6 811:e. MD.' .. TVD top -, bottom top 35 115 35.0 31 8773 31.0 34 3466.. 34.0 11, Total Depth MD (It): ,. ITotal Depth TVD (It): 8792 7116.0 Casing Length ... Conductor Production Surface 80 8742 3432 ,.... Perforation Depth MD (ft): 8480 - 8524 Packers and SSSV Týpe: 4-1/2" Baker S-3 perm Packer piUgs (md): None Burst Junk (md): 8586 - . Collapse 20" i1.S' H-40 7" 2M L'ao 9-518" 401 L-80 bott°rTI. . 115-0 1400 7097.0 7240 2883.3 5750 470 5410 3090 Perforation Depth TVD (ft): 6804.4 6848.4 Tubing Size: 3.6 .. Tubing Grade: Tubing MD (ft) 9.3 # L.SO 72 12.6 # L..oo 29 8404 72 4.5 Þackers and SSSV MD (ft): 8305 .... , 12. Attachments: Description Summary of Proposal 0 Detailed Operations Program ŒI "14. Estimated Date for Co.mlTHtncing Qperation: 16. Verbal Approval; Commission Representative: 13. Well Class after proposed work: BOP Sketch 0 Development 0 Ëxploratory 0 Service£&] June 1, 2004 15, Well Status after proposed woik Oil 0 GasD / PluggedD AbandonedD WAG 0 GINJ~ WINJO WDSPLn Prepared by Sharma,ne11opuland 564-4424. Date: 17 I hereby certify that the foregoing Is true and correct to the best of my knowledge. Title Phone Contact Jim Young Petr.oleum Engineer 564-5754 5/18/04 printed Name Signature . Jim¡jO,unf. i n'" \ (J t""-1 m, t': Comml881òn Use OnlY Conditions of approval: Notify Commission so that a representative may witness I Sundry Number: £/ V' 30'7-/8'7 Form 1 0-403 Revised 12/2003 Mechanciallntegnty Test 0 Location Clearance 0 u...r (! ¿ m 0 ~ J.(f ¿\j-l Dv-- , BY ORDER OF THE COMMISSION Data ?fr QR\G\NÂ: tJ , RBDMS Sf L SUBMit IN DUPLICATE; - a \! lU~' 05/19/2004 08:58 9075644005 ,-..., PETROTECH DATA CNTR: - ~ PAGE 03 TÆE= .WEtLI-fEAO '" A CTIJI\ TOR = .~8. a.EV '" BF. ELEV = 'KoP= Malt Angl:! = bstumMD=- Dalum..1VD= 4" FMC 11" NA ...!~:8.', 36.4' . 642' 54.@v22~? . .... ..8445' 6700' SS 8-110 / \ ~ SAFETY NOT.: UN8HOT "'518" ~ SCAl lOP GltoIS (6 $PF)@ 8480'.8628'. ŒS FIRING HEAD@ 8398' - - 72"'H :-4 1030' "K I 2175' H 4-1/2"~3"1/2.XO,ID=2.992" I TA~..PORT OOU,.AR I 3-1/2" ÆsX NP.ID.2.813" I r..9-518" CSG, 401#. l-8Ó~TC-M. 10= 8.835"H 34&6;. t--- IMlnimUmlD:= 2,375" @ 8397' I 2.7/8" X 3-112" XO .. . L - GAS lIFT MAN~as .' ,....... ST ~ 'TYp' 'œv TYPE VLV ..~A}ëH PORT M'TE 3 4656 3608 46 M\1G [NY'. R< a 07115~3 2 7002 5291 24 Mo.1G D.4Y R< 0 07115~3 1 8~4 6508 3 M\1G [),4Y R< 0 om 5,uJ n. ~.. --t 8~2~~ H ZO' SHORT JT. W/PA TAG I g I Z'----i f 8330' 8282.~ H 3.~i2" HE~ X t-F, ID" 2.813" I 8305'" H ~:',X3"1!2" BKR ~3 R<R IIJ = 3 9750;'1 H 3.1/2" HESX NP,II?~2.8'3" I I a35~'H 3-112"HES:X III~, 10 = 2,813" I l3-lIZ'TèG,9,3#,L-~?,0087bpf.ÏD=2~992" H 8361' I PERFORATION 5W1M\RY REF LOG; SS MIllO GR ON 0812E!JO1 ANGLEATTŒ'ÆRF: 3@8480' I'Dte. Refer to A'~dur;:,iJn œ fo~ hIStorical perf <l8t8 , SIZE.. SPF IN1ERVAl OpnlSQz DATE 4-!.V8" 5 8480 - 8524 o' 10/03/01 ~".-'i 8397'..H 3.1/Z;'X2-71f!:'XO,ID=2,3~~."1 8398' ... H iCP FIf1ING HEA D, I~ ~ 2,50(1' I 8404' H AurOREÙ:A~F9RTœGUN,ID=2.700" I ~ 8890'.. I' 7" CSG. 26#. L~O 8To.M, I~ --6.ÏJfj; H 877~' 8--f I .,,-~-- I :~ 8548'-1-1 20'S~oRT JTW/AA TAG I .. H TCPSCALLOPGLl'JS I DA TE REV BY COMfIII5NlS 09101101 CHlllh ORIGINAL COMPlEl'ION 10113/01 'TMNMh TCPPffiF(:¡û\ì'St;QT '04109103 CftSITP 1V0/M:> aJRRECrION$ .... . 07115/03 PWf:lK.K GLV C/O DATE REV BY COMtÆNT"S AtROPA UNIT weLL: 5.110 P8'tMT" fib: 2011290 API fib: 50-029-23030 SEC35. "12N. R12E, 4498' ÆL& 4481' FSL BP Exploration (Ala' ka) ..., "....:- - ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon 0 Alter CasingD Change Approved ProgramD 2. Operator Suspend 0 RepairWeliD Pull TubingD Operation ShutdownD Plug PerforationsO Perforate New Pool 0 4. Current Well Class: Perforate 0 WaiverD Stimulate 0 Time ExtensionO Re-enter Suspended Well 0 Other!!] Convert to WAG Name: BP Exploration (Alaska), Inc. 5. Permit to Drill Number: 201-1290 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Development D Stratigraphic 0 9. Well Name and Number: S-110 10. Field/Pool(s): Prudhoe Bay Field / Aurora Oil Pool ExploratoryD ServiceŒ 6. API Number 50-029-23030-00-00 69.55 8. Property Designation: ADL-o028257 11. Present Well Condition Summary: Total Depth measured 8792 feet Effective Depth feet Plugs (measured) Junk (measured) None true vertical 7116.0 feet measured 8690 8566 true vertical 7014.1 feet Casing Length Size MD TVD Conductor 80 20" 91.5# H-40 35 115 35.0 - 115.0 Production 8742 7" 26# L-80 31 - 8773 31.0 - 7097.0 Surface 3432 9-5/8" 40# L-80 34 - 3466 34.0 - 2883.3 Burst 1490 7240 5750 Collapse 470 5410 3090 Perforation depth: Packers & SSSV (type & measured depth): 4-1/2" 12.6# L-80 @ 3-1/2" 9.3# L-80 @ 4-1/2" Baker S-3 Perm Packer 29 72 @ 72 8404 RECEIVED MAH 3 0 2004 Alaska 011 & Gas Cons. Comrnieeion Anchcnge ltIIaL.- Measured depth: 8480 - 8524 True vertical depth: 6804.41 - 6848.35 Tubing ( size, grade, and measured depth): 8305 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv Averaae Production or Iniection Data Gas-Met Water-Bbl Casing Pressure 0.5 16 1260 _Ih. 13 0 0 3413 1400 Tubing Pressure 286 1933 Prior to well operation: Subsequent to operation: Oil-Bbl 413 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentD ServiceŒ Copies of Logs and Surveys run - 16. Well Status after proposed work: Operational Shutdown 0 Oil 0 GasD WAG Œ GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. SUndry Number or N/A if C.O. Exempt: 303-123 Daily Report of Well Operations. ! 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron ,jj~ Cd7b~ Title Production Technical Assistant Signature Phone 564-4657 Date 3/24/04 Form 10-404 Revised 12/2003 ~ ,. .. ,- ~ TREE = WB.LHEAD = ACTL14 TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = DatumMD= DatumTVD = 4" FMC 11" NA 70.8' 36.4' 642' 54 @ 2202' 8445' 6700' S8 5-11 0 \ ) 72' H 4-1/2"X3-1/2"XO,ID=2.992" :-1 1030' H TAMPORfCOLLAR I 2175' H 3-1/2"I-ESXNP,ID=2.813" I SAÆTY NOTES: UNSHOT 4-5/8" I-ES SCALLOP GUNS (5 SPF) @ 8480'.8528'. tES FIRING HEAD@ 8398' - - I 9-518" CSG, 40#, L-80 BTC-M, ID = 8.835" H 3466' r-- Minimum 10 = 2.375" @ 8397' 2-718" X 3-1/2" XO L - ST tv{) 3 4656 2 7002 1 8254 GA S LIFT MANCRELS TVD ŒV TYPE VLV LATCH PORT DAlE 3608 46 WMG ~Y RK 0 07115103 5291 24 WMG ~Y RK 0 07/15103 6508 3 WMG ~Y RK 0 07/15103 8----1 8124' H2O' SHORT JT. W/RA TAG :8: I 8282' H 3-1/2" HESX NP, ID =2.813" ~ 8305' H 7"X3-1/2"BKRS-3A<R.ID=3.87S'" I 8330' H 3-1/2"HESXNP,ID=2.813" I I 8351' H 3-1/2"HESXNP,ID=2.813" 13-1/2" lBG, 9.3#, L-80, .0087 bpf, ID= 2.992" H 8361' , PERFORATION Sl..MMA.RY REF LOG: SS MND GR ON 08/26/01 ANGLEATTOPÆRF: 3@8480' f\bte: Refer to A-oductbn œ for historical perf data SIZE SPF INlERVAL Opn/Sqz DATE 4-5/8" 5 8480 - 8524 0 10/03/01 ~ 8397' H 3-1/2" X 2-7/8" XO, ID= 2.375" , ~ -II 8398' H TCPFIRINGHEAD,ID=2.500" I b::mJ:I 8404' H AUfORELEASEFORTCPGUN,ID=2.70a' I PBlD H 8690' I .., I 7" CSG, 26#, L-80 BTC-M, ID = 6.276" H 8773' ~ II--- 8548' H2O' SHORT JTW/ RA TAG' I H TCPSCALLOPGUNS I Do\ 1E 09/01/01 10/13101 04109103 07/15/03 RBI BY COM~NTS CH/tlh ORIGINAL COMPLETION 1MNÆlh TCP PERF GUN SHOT CRSIfP TVD/MD CORRECTIONS PWEiKK GLV ao DATE REV BY COM~NTS ALRORA UNIT WELL: S-110 PERMT f\b: 2011290 API f\b: 50-029-23030 SEC 35, T12N, R12E, 4498' FEL & 4481' FSL BP Exploration (Alas ka) Permitto Drill 2011290 DATA SUBMITTAL' COMPLIANCE REPORT 1012212003 Well Name/No. PRUDHOE BAY UN AURO S-110 Operator BP EXPLORATION (ALASKA) INC APl No. 50-029-23030-00-00 MD 8792 ..~' TVD 7116 _..- Completion Date 10/3/2001 ~ Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log N._go Samples N._9o Directional Survey N._9o DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type MedlFrmt Number Name (data taken from Logs Portion of Master Well Data Maint) ~R Processed Log KUP Log Log Run Scale Media No Interval Start Stop OH/ CH 5 FINAL 8400 8630 Case Received Comments 9/14/2001 8400-8630 Color Print ! .~ED' C i ED D D C ~ ko~,~ ~x~-0727 ~/~1256 section Directional Survey ~?../~'~ Directional Survey GYRO Directional Survey GYRO Directional Survey MWD Directional Survey .................................................................................................................... Directional Survey MWD ~:;:; '.i-:.:. ~-:::' ::'-'i:? ;::::~'~i'.:i~i"i! i '~'~:?~ C~MR Processed Schrader ~;,,~ection FINAL FINAL 1 FINAL FINAL 1 FINAL 1 FINAL FINAL 6348 61 113 6350 8690 8762 8792 668O Open Open Open Open Open Open Open Case Open Open 9/12/2001 Directional Survey DIGITAL DATA 9/12/2001 Directional Survey GYRO DIGITAL DATA 3/29/2002 9/12/2001 Directional Survey GYRO 9/12/2001 Directional Survey MWD DIGITAL DATA 3/12/2002 9/12/2001 10/30/2002 9/12/2001 9/14/2001 Directional Survey Digital Data: Rate of Penetration, Dual Gamma Ray, and Electromagnetic Wave Resistivity Directional Survey 6350-6680 Color Print Well Cores/Samples Information: Name Start Interval Stop Sent Received Sample Set Number Comments Permit to Drill 201'1290 DATA SUBMITTAL COMPLIANCE REPORT 10/22/2003 Well Name/No. PRUDHOE BAY UN AURO S-110 Operator BP EXPLORATION (ALASKA) INC MD 8792 'I'VD 7116 ADDITIONAL INFORMATION Cored? Y/N~ Well Chips Received? Analysis Received? Completion Date 10/3/2001 Completion Status 1-OIL Current Status Daily History Received? ~)N Formation Tops (~ N APl No. 50-029-23030-00-00 1-OIL UIC N Compliance Reviewed By: Date: MEMORANDUM ., State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich Commissioner TH RU :--T-em-Marmd'e~ P.I. Supervisor FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL DATE: July 21,2003 ~fCSUBJECT: Mechanical Integrity Test BPX S Pad S-110 PBU Packer Depth Pretest Initial 15 Min. 30 Min. We,,I S-110 ITypelnj. I S I T.V.D. I 6629 I Tubing[ 1950 I~0 11950 I~0 I,,terva, I , P.T.D.I 201-129 ITypetestl P ITestpsil 1657 I Casingl 590 I 21001 20701 20601 P/F I P Notes: converted producer to injector P.T.D. Notes: Well P.T.D. Notes: P.T.D. Notes: Well P.T.D. Notes: IType Inj. Type test Type Inj. Type test IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER I NJ. N = NOT INJECTING Type' Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs S Pad and witnessed the initial MIT on well S-110. This well was recently converted from a producer to injector. The pretest tubing and casing pressures were observed and found to be stable. The pressure test was then performed for 30 minutes with the well demonstrating good mechanical integrity. M.I.T.'s performed' 1_ Number of Failures: 0 Attachments: Total Time during tests: 1 hour MIT report form 5/12/00 L.G. 2003-0721 MIT PBU S-110 cs.xls 7/23/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to: Winton_Aubert@admin.state.ak.us; Bob_Fleckenstein@admin.state.ak.us; Jim_Regg@admin.state.ak.us OPERATOR: FIELD / UNIT / PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska)Inc. Prudhoe Bay / PBU / S 07/21/03 Ken Clare Chuck Scheve Packer Depth (TVD-ft.) P.T.D.12011290 Type test Test psiI 1657.251 Casin~ Notes: Initial MITIA (post injection startup) P.T.D.I Notes: Type Inj. P.T.D.I Notes: Type Inj, P.T.D.I Notes: Type Inj P.T.D.I Notes: Type inj. Pretest Initial 15 Min. 30 Min. 1,9201 1,9501 1,9601 1,9601 IntervaI I 600] 2,1001 2,0701 2,0601 P/FI P Test Details: TYPE INJ Codes F = Fresh Water Inj G = Gas Inj S = Salt Water Inj N = Not Injecting TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) MIT Report Form Revised: 06/19/02 2003-072 I_MIT_PBU_S-110.xls Aurora S-110 Subject: Aurora S-110 Date: Mon, 19 May 2003 19:08:43 -0500 From: "Young, Jim" <YoungJ3~BP.com> To: "Winton Aubert (E-mail)" <Winton_Aubert~admin.state.ak.us> Winton, heres the summary of the waterflow completed in S-110. There is movement above the perfs into the HRZ/brookian shale that we apparently propped with the frac treatment. The water-flow log, temperature log, and frac height match all agree with shallowest fluid entry at 8400' I have the full log & will be glad to go over with you at your earliest convenience. Thanks Jim Young <<Young, Jim.vcf>> <<Si10 WFLresults. ZIP>> Young, Jim <YoungJ3(~BPmom> Production Engineer BPXA GPB/WEND ~-~Sll 0 WFI.resu],ts.ZIPil Type: Zip Compressed Data (application/x-zip-compressed) ii,Encoding: base64 ,, STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Alter casing _ WAG INJECTION CONVERSION Suspend_ Operational shutdown _ Re-enter suspended well _ Repair well _ Plugging _ Time extension _ Stimulate _ Pull tubing _ Vadance _ Perforate_ CONVERSION Other X -- 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 799' FNL, 4498' FEL, Sec. 35, T12N, R12E, UM At top of productive interval 3761' FNL, 810' FEL, SEC 26, T12N, R12E, UM At effective depth 3754' FNL, 802' FEL, Sec. 26, T12N, R12E, UM At total depth 3751' FNL, 798' FEL, Sec 26 T12N, R12E, UM 5. Type of Well: Development .._X Exploratory __ Stratigraphic __ Service__ (asp's 618930, 5980684) (asp's 622577, 5983061) (asp's 622585, 5983068) (asp's 622589, 5983071) 6. Datum elevation (DF or KB feet) RKB 69.6 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number/ S-110 /" 9. Permit number / approval number 201-129 / 10. APl number 50-029-23030-00/ 11. Field / Pool Prudhoe Bay Field / Aurora Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 115' Surface 3432' Production 8742' 8792 feet Plugs (measured) 7116 feet 8690 feet Junk (measured) 7014 feet Size Cemented Measured Depth 20" 260 SX AS (approx) 149' 9-5/8" 577 sx AS III, 298 sx 'G', 3466' 658 sx AS III 7" 390 sx LiteCrete 8773' True vedical Depth 149' 2883' 7097' Perforation depth: measured Open Perfs 8480'- 8524' true vertical Open Perfs 6804' - 6848' Tubing (size, grade, and measured depth Packers & SSSV (type & measured depth) RECEIVED APR ! $ 2.OO3 Alaska 0il & Gas Cons. Commission Anchorage ' 4-1/2" 12.6#, L-80 @ 72'. 4-1/2" x 3-1/2" XO @ 72'. 3-1/2" 9.3#, L-80 @ 8397'. 3-1/2" x 2-7/8" XO @ 8397'. TCP Firing Head @ 8398'. Auto Release for TCP Gun @ 8404'. 7" x 3-1/2" Baker S-3 Packer @ 8305'. 3-1/2" HES 'X' Nipple @ 2175'. 13. Attachments Description summary of proposal ._X Detailed operations program __ BOP sketch __ 15. Status of well classification as: 14. Estimated date for commencing operati0/P/ June, 2003 -- 16. If proposal was verbally approved Name of approver Date approved Oil __ Gas Service WAG INJECTION Suspended 17. I hereby certify tha~he foregoing is true and correct to the best of my knowledge. Signed ! /"'Trj/(:::~-¢~1 ~/ Title: Aurora Surveillance Engineer JimYoun~ /! -- / FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity__ BOP Test__ Mechanical Integrity Test _L~ Approved by order of the Commission Location clearance__ Subsequent form required 10- ......... ORIGINAL Questions? Call Jim Young @ 564-5754. Date April 15, 2003 Prepared by DeWayne R. Schnorr 564-5174 Commissioner J ~.., Approval no. Form 10-403 Rev 06/15/88. SUBMIT IN TRIPLICATE BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 15, 2003 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, AK 99501 Dear Winton: Re: Sundry Notice for S-110 conversion to WAG injection well BP Exploration Alaska, Inc. proposes to convert well S-110 to WAG injection. The following work is required asap in order to prep the well for surface conversion to injection which will commence in mid-June. A USIT/GR log was run on this well during the initial completion. The cement bond is good across the interval that will have WAG injection. '~. /' The procedure includes the following major steps: Category IOR Step C 1 C 2 Description D & T, DGLV's, SBHP's. (FCO if < 8530'). MITIA and Injectivity test (300 bbls water). 1) Tag PBTD, FCO if sand top <8530' ELMD. 2) Install DGLVs & SBHPs per attached. (verify well SI at least 5-days before SBHPs) 3) MITIA to 3000psi in perform injectivity test at 2000 and 2800psi. -"' a. Need 300bbls water (tubing vol +75bbls at each pressure, 30 bbls 60/40 meoh) AOGCC witnessed MITIA within 1-2 weeks following injection startup. Last Test: FBHP: Max. Deviation: Perfs: Min. ID: Last TD tag: 04-10-03,490 BOPD, 18 BWPD, 933 Mscf Gas. To be taken. 54° @ 2202' md Deviation at perfs: 3° Present Perfs 8480' to 8524' MD One .... 2.375" at 3-1/2" x 2-7/8" XO @ 8397', see schematic. TCP Scallops Guns on Bottom. Last Downhole ©ps: Latest H2S value: Reference Log: Brush tubing with 3-1/2" BLB & 2.25 GR down to 8381' SLM; pump 130 bbls hot crude down tubing, 04/08/2003. < 10 ppm Sperry MWD GR (08/26/2001) Please call (Jim Young 564-5754, hm: 248-0133, cell: 440-8007) if there are any questions. Sincerely, Jim Young Greater Prudhoe Bay Aurora Development Engineer TREE= WB_l-I;I, EAD = FMC 11" ACTUATOR = NA KB. ELEV = TO.E~ BF. ELEV = KOP = 642~ Max Angle = 54 @ 2:202' Datum MD = 8446' D~tumTVD = 67017 SS ] ~-5~" csG, 4D~. L-SD BTC-M, D= E~.835" I--I 3466' Minim u m ID = 2.375" i~ 8397' I 2-7/8" X 3-1/2" XO I S-110 / SAFETY NOTES: UNSHOT 4,-5/13" HES SCALLOP GUNS (5 SPF} ~ 841D3'-1~21~. HES FIRING HC~D~G3DG' 7~" H 4' 1/'Z' X 3' 1/2" XO' ID = 2'~9Z' I 11~0' H TAM PORT OOLLARI ~17~' H 3-1/'Z' HES/~ NIP. ID= 2.813" I GAS LIFT MANDRELS S124' Id 20'SHORTJT. W/RA TAGI 13-t/*Z' TRIG,9.3#, bSl~..0~87 bpf, ID= 2.992" I--I S361' PERFORATION SUMlu~ RY REF LO G: SS ~ D GR ON DG/2B/O 1 ANGLEATTOP PERF: 3 @8480' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-5/8" 5 a4e~. a524 0 10/D3/01 3-112" H ES X NIP. ID = 2.B13" J 7" ,~3-1/2" BKR D3 PI(R, ID = 3.875" 3-1/2" HESX NIP. ID =2.B1~' I 3-1/2" H ES X NIP, ID = 2.B13" I 3-112" ~ 2-7/D' XD, ID = 2.:375" TCPFIRING HEAD, ID= 2.5017' I · 1o4' Id AUTO RELEASE FOR TCP GUN, ID=2.7OID' J H H ! 20' ~JHORTJTW/RA TAG J TCP SCALLO? GUNS ] DATE RD BY COMlvENTS DATE REV BY COMIVENTS 05/08/01 D.Wesley ORIGINAL PROPOSED .0D/01/01 CH/tlh ORIGINAL COMPLETION tD/13/01 TMN/tlh TCP PERF GUN SHOT : 04/0g103 DRS/TP TVD/IvD CORRECTIONS AURORA UNIT WELL: S- 110 PEP, MT No: 2011290 APl Ne: §0-1:)2G23[)30 SEC 35. T12N. R'I2E. 44~' FEL& 44~1' FSL BP Exploration (Alaska) S-110 Offset Penetrations iWell ! I Meas Subsea TOC Est.(30%) Comment, other · I Well I Status IIDepth at i Depth at Offset (30%wash Cement above Job !evidence of Name Name Well Status Desc TKUP (ft) TKUP (ft) (ft) .out) MD AOP (ft) Flags? confinement S-110 ,SI-O ,Oil Well On Gas-Lift' 8,350 6,605 12,,~400~ 4,196,i 4,154 USIT TOC above 6000' S-41 iSl-O Oil Well On Gas-Lift I 8,810 6,664 4,904 3,905 S-32 ISI-O iOil Well On Gas-Lift 7,454 6,620 5,097 2,357 S-112 'GL-O IPre-Prod. Inj-Heel 6,852 6,614. 2,209 3,168 3,685 USITtop@3250' S-15 INJ-PW Water Injector 8,000 6,6681 2,283 4,032 3,968 S-35 GL-O Oil Well On Gas-Lift 7,204 6,620 2,404 4,781 2,423 S-109 FL-O IOil Well On Gas-Lift 7,820 6,676 2,485 3,150 4,670 USIT top at 3150' S-24 ~P&AI P&A 7,282 6,620 2,536 4,933 2,349 S-110Offsetl nteg rity4-03.xls h: North Slope Aurora 708.51' FNL & 781.50' FWL S-110 BP Exploration (Alaska), Inc. REMARKS: RUN NUMBER 1 Objective: Perform Static Bot. Hole Pre~/Temp log and RSTVl~aterfl prepare well for conversion to injection. Depth correlated to S~I~S Perforating Depth Record ! GR dated 1-Sep. Baseline Temperature pass had to be spliced due to computer Iockin~ Temperature and pressure cur~es on baseline down pass affected by to o I u p a n d d own sere ra I ti m es fro m :2200' - :2800' wh il e tr~i n g to wo REMARKS' ow Log to 2001. up. nning the tool down Spinner damaged when passing through tubing tail. No valid spinner data recorde¢ Pressure gradient indicates borehole filled with gas from surface to T ,. After logging Static Sur~e¥ Stop Counts, pumped 100 BBLS KCL do~n tubing to fluid pad< well, then brou~lht rate bad< to ,0 BPM (lowest rate aohie~able, wellwason avacuum) During WFL Stations, injection ratesteadil¥i creased to nearl.4BPM. WFLStationsidentifiesUP-Flow~SqSO, S450, and ZlO0 and co nfi rm e d zero u pfl ow i~ S:350' M D. FollowingWFLStations, logged injecting temperature pass(~30 fpm and shut in well for 30 minutes prior to logging warmback pass ~ 30 fpm. ~R scale xlO AFE# AUL'd~'PS 110 I~II IliI ,,.I Inj rate during WFL ~l.4bpm into perfs 8480'-8524' in 7" casing. Top fluid movement 8400'-8450' in HRZ/brookian shale confirmed by both WFL stops & temp overlay. Fluid is contained by cement 8290'-8360' indicated by 8/30/01 USIT. Max movement detected at ~35fpm at 8450', flow rate depends on channel area (Q=VA). Suspect channel caused increased fracture height, placing proppant into non-pay zone. Frac model predicts fluid movement above perfs within fracture. Rock stress & frac- height modeling indicate containment to within 100' of top perf. Wellbore inclination is 3degrees, temperature log can easily detect frac top. JPY 5/13/2003 .' : : · · · · · · · : · · · · '- · · · .' · · _, · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · · : · · · · · · · · · · · · · · · · · · 4500 5500 -0. -0.,-0.00.2 0.4 50 100 150 200 Fracture Penetration (ft) o S-110 o ....... ~ .......... i ........ [ ....... ? .......... [ ........ [ ....... T .......... ['Simulated Data] I I 2.0 5.0 10 20 50 100 200 500 10002000 Time (min) Frac history match of net pressures during datafrac 9 -208 (OAPI) Computed CCL (CCLC) ,i'ENS) I mn/ecTmn9 men., ~aTure ~ss ~wm~-m~=~m~/ O~...(L..B.F. ).. J120 (DEOF) 1 G( OPEN ~ ............................. ~[I. ~F~Yr~_~~) ........................... (PSIA) ii pERFS I0 lO~ 120 (DEOF) I miS( Top of Injection at >8370' where post-inj temp grad deviates from static temp grad (red line) ,' WFL: No upward ,f,lui?d,, dete,,ct,e,,d , WFL' 35fprn up I ! I m I ! ¢,'irst Rea I I · WELL LOG TRANSMITTAL To: State of Alaska October 29, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs · S-110 AURORA, AK-MM-11134 S-Il0 AURORA: Digital Log Images: 1 CD Rom PLEASE ACKNOWLEDGE RECElPT 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: 3/27/2002 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1932 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-110 21477 CMR/MDT 08/25/01 1 S-110 21477 CMR 08/25/01 1 1 S-110 21477 MDT 08/25/01 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 AK 99508-4254 Date Delivered: RECEIVED Schlumberger DCS 3940 Arctic BIvd Suite 300 Anchorage AK 99503-5789 ATTN: Sherrie WELL LOG TRANSMITTAL To: State of Alaska March 05, 2002 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska RE: MWD Formation Evaluation Logs S-110, AK-MM-11134 1 LDWG formatted Disc with verification listing. API#: 50-029-23030-00 PLEASE ACKNOWLEDGE iRECEIPT BY SIGNING ,AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: Signed: RECEIVED 'i ,?002 Scblumbe Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1590 Company: Alaska Oil & Gas Cons Comm Atln: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 11/1/2001 Field: Borealis Aurora Well Job # Log Description Date Color Sepia BL CD S-110 SO)- /~ 21419 USIT 08/20/01 S-103 ~-~ DO ~ _~ ~ ~ PROD PROFILE/DEFT 10/20/01 1 L-115 .~OI- IctO TEMPERATURE LOG 10/22/01 o 1 ~1~ L-110 21381 D/N & IMP (PDC) 07/27/01 1 L-110 <:~O7- / ~ ?~ 21381 MD VISION RESISTIVITY 07/27/01 o 1 ~1~ L-110 21381 TVD VISION RESISTIVITY 07/27/01 L-110 21381 IUD VISION DEN/NEUTRON 07/27/01 · 1 ,1~ L-110 21381 TVD VISION DEN/NEUTRON 07/27/01 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Bivd, Anchorage AK 99508-4254 Date Delivered: RECEIVED k'OV 02 2001 Anf:orsge Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATrN: Sherrie Receiv~ ~.~. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 201-129 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-23030-00 :4. Location of well at surface .,, ........................ : 1 Lt"J~'rtOt,,~ 9. Unit or Lease Name 4481' NSL, 4498' WEE, SEC. 35, T12N, R12E, UM i eL';..',.:-: :" '"'~ ~ !: ¥~i~,~-~:~ ~ Prudhoe Bay Unit At top of productive interval 1519' NSL, 810' WEL, SEC. 26, T12N, R12E, UM ', At total depth ; ~ .;. ~,..!;..~,?_~,,~,..~,j 10. Well Number 1528' NSL, 797' WEL, SEC. 26, T12N, R12E, UM i ....... 'i,~'/~ 'i ...... ? --.~-,,. ............. .~, S-110 ""~ .................. 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Aurora Pool KBE = 69.55' ADL 028257 (Undefined) 12. Date Spudded8,13,2001 ] 13' Date T'D' Reached 114' Date C°mp" Susp" °r Aband'8,24,2001 10,0/2001 115' Water depth' if OffshOreN/A MSL 116' N°' °f C°mpleti°nsOne 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD) 119. Directional Survey 120. Depth where SSSV set1 21. Thickness of Permafrost 8792 7116 FTI 8690 7014 FTI []Yes []NoI (Nipple) 2175' MDI 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, Gyro, RES, NEU, DEN, CMR, MDT, RFT, USIT, CBL, Temp, CCL 23. CASINGr LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM S~ZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 115' 30" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 34' 3466' 12-1/4" 577 sx AS lilt 298 sx 'G'~ 658 sx AS III 7" 26# L-80 31' 8773' 8-3/4" 390 sx LiteCrete 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 4-5/8" Gun Diameter, 5 spf 3-1/2", 9.3#, L-80 8528' 8305' MD TVD MD TVD 8480' - 8524' 6804' - 6848' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8480'- 8524' Frac'd: 106,342# 16/20 Carbolite behind 3000' Freeze Protect with 23 Bbls Crude and 45 Bbls MeOH 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Not on Production N/A Date of Test Hours Tested PRODUCTION FOR OIL'BBL GAS-MCF WATER'BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER'BBL OIL GRAVITY'API (CORR) Press. 24-Hour RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED OCT g 5 2001 Alaska Oil & Gas Cons. Commissio~ Apnhnmn~ Form 10-407 Rev. 07-01-80 ORIGINAL Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. Schrader Bluff M 6393' 4857' Schrader Bluff N 6677' 5075' Schrader Bluff O 6808' 5186' Colville Mudstone 7132' 5481' HRZ 8463' 6787' , , ,' Kuparuk C 8480' 6804' LCU / Kuparuk S 8535' 6859' 4~,, C~ ~ Kuparuk A 8562' 6886' '~e~O~u~_~ Base Kuparuk / Top MJluveach 8621' 6945' 31. List of A~achments: Summa~ of Daily Drilling Repo~s, Su~eys, Leak-Off Test '32. I hereby ce~Jfy that the foregoing is true and correct to the best of my knowledge Signed TerrieHubble ~~ ~ Title TechnicalAssistant Date S-110 201-129 Praparad By ~am~/Numbar: Terde H~bble, Well Number Permit No./Approval No. INSTRUCTIONS GENERAL: ']'his form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in ^iaska. 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: ~ndicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIGINAL Legal Name: S-110i Common Name: S-110i TeStDate :ii: i .: TeSt D~pth(TMD):: :: TeStDepth(~D):: : :::: AMw::I i: SUrface Pressure Leak Off Pressure (BHP) EMW 8/21/2001 LOT 3,466.0 (ft) 2,883.0 (ft) 10.30 (ppg) 530 (psi) 2,073 (psi) 13.84 (ppg) Printed: 9/4/2001 5:06:03 PM BP EXPLORATION Page i of 7 Operations Summa Report Legal Well Name: S-110i Common Well Name: S-110i Spud Date: 8/11/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours 'Activity Code NPT Phase Description of Operations '8/13/2001 00:00 - 05:00 5.00 MOB P PRE Move rig to S-110. Cantilever rig floor in place. Accept rig at 05:00 on 8/13/01. 05:00 - 08:00 3.00 RIGU P PRE Nipple up diver[er bag w/o diver[er line, riser, flow nipple, and flow line. 08:00 - 10:30 2.50 DRILL P SURF PU and stand back 5" DP. 10:30 - 12:30 2.00 DRILL P SURF PJSM. Cut and slip drilling line. Service top drive. 12:30 - 17:00 4.50 DRILL P SURF Continue to PU DP and HWDP and stand back in derrick. 17:00 - 20:00 3.00 DRILL P SURF MU BHA. 20:00 - 20:30 0.50 DRILL P SURF Upload MWD and conduct pre spud meeting. 20:30 - 21:30 1.00 DRILL P SURF Continue MU BHA. 21:30 - 22:00 0.50 DRILL P SURF Fill hole with mud and watch for leaks. 22:00 - 23:00 1.00 DRILL P SURF Tag bottom at 115' and drill to 177' 23:00 - 00:00 1.00 DRILL P SURF RU slickline and run photo gyro survey. 8/14/2001 00:00 - 00:00 24.00 DRILL P SURF Drill with slickline gyro to 532' while building angle. Continue drilling with gyro to past close approach well. Last gyro at 800' (bit depth 896'). Drill to 1203'. ART--6 hrs. AST=8.75. 8/15/2001 00:00 - 09:30 9.50 DRILL P SURF Drill from 1215' to 1758'. Pumping at 520 gpm while rotating, 440 gpm while sliding. AST=5.29, ART--1.85 09:30 - 10:00 0.50 DRILL P SURF Circulate 1.5 x bottoms up. 10:00 - 12:00 2.00 DRILL P SURF Flow check. POH form 1758'. Work pipe and pump from 615' to 360'. Attempt to work through with no pump pulling 25K over. Circulate app. 200 gpm while working out of hole. from 550 to 360. No more adverse hole conditions once above 400.'7. 12:00 - 12:30 0.50 DRILL P SURF Stand back BHA. 12:30- 13:00 0.50 DRILL P SURF Down Icad MWD. Upload MWD. 13:00 - 15:00 2.00 DRILL P SURF Change out acoustic caliper to take down loading off the critical path. Break and grade bit. 15:00 - 17:00 2.00 DRILL P SURF TIH to 1758'. Orient and wash down through tight spot seen on the trip out. (? 400 to 600) Hole in good shape on remainder of trip with no fill on bottom. 17:00 - 00:00 7.00 DRILL P SURF Drill from 1758' to 2143'. AST 2.8, ART=1.16. 8/16/2001 00:00 - 11:30 11.50 DRILL P SURF Drill from 2,143' to TD at 3,480'. ART=6.5 hrs. AST=2.25 hrs. 11:30 - 14:00 2.50 DRILL P SURF Circulate and condition mud. 14:00 - 23:00 9.00 DRILL P SURF POOH working first 6 stands with 5 to 50 K overpulls. Intermittent packing off and sticky while back reaming to app. 1,250 ft. Unable to pull without pumps on. Hole appears to fall in once pumps are shut down. Begin to bring vis. from 200 to 300. Circulating from 60 - 130 spm. Getting lots of pea gravel and sand over shakers. Able to pull without circ. from 1,250 to 400. 23:00 - 00:00 1.00 DRILL P SURF MAD pass from 352 to 264 with Acoustic Caliper @ 250-300 fph. 8/17/2001 00:00 - 03:00 3.00 DRILL P SURF Down Icad MWD. Flush and LD motor. 03:00 - 03:30 0.50 DRILL P SURF Service top drive. 03:30 - 05:00 1.50 DRILL P SURF MU 12 1/4" Smith tri-cone hole opener. 05:00 - 09:00 4.00 DRILL P SURF RIH w/hole opener to 1,000' and obtain base line parameters. Wash and ream tight spots from 1,446' to ~2,100' at 70 rpm and 500 gpm. Lots of gravel and sand over shakers. Continue reaming as needed to TD. Ream last 500 ft. to bottom as this section showed 5-50k overpulls coming off bottom after TD. Reaming with 465 gpm @ 70 RPM. 09:00 - 11:30 2.50 DRILL P SURF Circulate hole and condition mud. 11:30 - 17:00 5.50 DRILL P SURF Flow check. Well static. POOH. Wash and back ream tight Printed: 9/4/2001 5:05:20 PM BP EXPLORATION Page 2 of 7 Operations Summary Report Legal Well Name: S-110i Common Well Name: S-110i Spud Date: 8/11/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/17/2001 11:30 - 17:00 5.50 DRILL P SURF hole from 2,250' to 1,350'. Run one stand back in without pumps. POH 17:00 - 18:00 1.00 DRILL P SURF LD BHA. 18:00 - 19:00 1.00 DRILL P SURF Clear rig floor. 19:00 - 21:00 2.00 CASE P SURF Rig up to run 9 5/8" surface casing. 21:00 - 00:00 3.00 CASE P SURF Run 9 5~8" surface casing. Baker lock first 3 joints. RIH and check floats, OK. RIH with casing to 1,000'. No problems while running in hole. 8/18/2001 00:00 - 22:00 22.00 CASE P SURF Run 9 5~8" casing from 944' to 2023'. No hole problems until 1,256'. Wash and drive casing from 1,256'. Very tight hole through clay / shale section from 71,400' to ? 1,975'. Very slow progress. Circulate at 30 - 60 spm and drive casing down. Casing progress increased after 87/100' dogleg at 72,170'. Last few joints had to be driven and circulated down. After picking up landing joint and hanger the hole was very tight and the landing joint was driven in the hole. 22:00 - 00:00 2.00 CASE P SURF Land casing hanger. Circulate and condition mud for cement job. 8/19/2001 00:00 - 01:30 1.50 CASE ;P SURF Circulate and condition mud for cement job at 7 bpm and 600 psi. Slow rate to 5 bpm due to minor losses. Losses stopped at 5 bpm. Mud reology prior to cementing: Funnel vis. in=98, vis out=119, MW=9.7, PV=23. 01:30 - 02:00 0.50 CASE P SURF LD Franks fill up tool and MU cement head. 02:00 - 05:30 3.50 CASE P SURF Pump 5 bbls CWl00 and test lines. Pump 15 bbls CW 100, 65 bbls Mud push spacer, 456 bbls 10.7 ppg lead cement at 6 bpm, and 62 bbls 15.8 ppg tail cement at 5 bpm as per well plan. Started Iossing fluid after pumping 380 bbls of lead cement. Loss rate from 1.5 bpm to 3.5 bpm. Slowed rate to 4bpm while pumping tail slurry. Loss rate decreased to 1 bpm. Start displacement at 7 bpm with loss rate of 2.3 bpm. Slowed displacement to 5 bpm and loss rate decreased to 1 bpm. Bumped plug at calculated strokes (.0986 bbl/stk). Total losses--60 bbls during cement job, 74 bbls during displacement. 05:30 - 06:30 1.00 CASE 3 SURF LD cement equipment. RU to RIH w/drill pipe. 06:30 - 08:00 1.50 CASE 3 SURF MU TAM combo tool and RIH on DP to 1,030'. Latch into TAM collar and test to 1000 psi. Open TAM port collar. 08:00 - 12:00 4.00 CASE 3 SURF Circulate at 3 bpm at 120 psi, increase to 7 bpm at 300 psi. 12:00 - 13:00 1.00 CASE 3 SURF Cement truck blew 1/2 gal of dry cement onto pad. Cleaned up by rig crew. 13:00 - 15:00 2.00 CASE 3 SURF Fill silo with dry cement for 2nd stage cement job. 15:00 - 17:30 2.50 CASE 3 SURF PJSM. Test lines to 2,000 psi. Perform 2nd stage cement job through TAM port collar at 1,030'. Pumped 520 bbls of 10.7 ppg Arctic Set Lite cement. Flushed DP and pumped 25 bbls of mud. Got cement returns to surface after flushing DP and pumping 20 bbls of mud. 17:30 - 18:00 0.50 CASE ~ SURF Close TAM port collar and circulate 9 5/8" x 5" DP annulus clean. 18:00 - 19:30 1.50 CASE 3 SURF POH and LD TAM combo tool. Printed: 9/4/2001 5:05:20 PM BP EXPLORATION Page 3 of 7 Operations Summa Report Legal Well Name: S-110i Common Well Name: S-110i Spud Date: 8/11/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYEN Rig Release: 9/1/2001 Rig Name: DOYEN 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 18/19/2001 19:30 - 20:30 1.00 CASE P SURF Pull and LD landing joint. Flush stack w/stack washer. 20:30 - 23:00 2.50 CASE P SURF ND surface stack. 23:00 - 00:00 1.00 CASE P SURF Install FMC split speed head and tubing spool. 8/20/2001 00:00 - 04:30 4.50 CASE P SURF Nipple up BOPE. 04:30 - 05:30 1.00 CASE P SURF PU test joint and test plug and RU to test BOP. 05:30 - 11:00 5.50 CASE P SURF PJSM. Test BOP to 250 psi and 3500 psi as per BP policy and AOGCC regulations. 11:00 - 12:00 1.00 CASE P SURF Pull test plug. LD test joint and PU DP. 12:00 - 12:30 0.50 CASE P SURF Install wear ring. 12:30 - 13:00 0.50 CASE P SURF Install bails and elevators. 13:00 - 17:00 4.00 CASE P SURF PU 78 joints of 5" DP from pipe shed and stand back 15 stands. 17:00 - 18:00 1.00 CASE P SURF Slip and cut drilling line. 18:00 - 19:00 1.00 CASE P SURF Stand back 11 stands of DP. 19:00 - 22:00 3.00 CASE P SURF PJSM. MU BHA. Upload to MWD and load Nuclear sources. 22:00 - 00:00 2.00 CASE P SURF RIH PU drill pipe to 2,500'. 8/21/2001 00:00 - 00:30 0.50 CASE P SURF Service rig. 00:30 - 02:00 1.50 DRILL P PROD1 Pick up drill pipe. Wash last 1 1/2 stands. 02:00 - 03:00 1.00 DRILL P PROD1 Circ. and cond. contaminated mud in casing. Prop 5 BPM at 400 psi. 03:00 - 04:00 1.00 DRILL P PROD1 Pressure test casing. Bled off at 550 psi. Would not test. Rig surface equipment checked and tested to 2,500. Source of leak not found. 04:00 - 05:00 1.00 CASE N DPRB SURF Prop dry job and POOH. 05:00 - 07:00 2.00 CASE N DPRB SURF LD flex collar. Pull RA sources. Download MWD. Break bit and stand back BHA. 07:00 - 08:30 1.50 CASE N DPRB SURF Acquire TAM combo shifting tool. 08:30 - 09:00 0.50 CASE N DPRB I SURF Pull wear bushing. 09:00 - 10:00 1.00 CASE N DPRB SURF Pick up TAM combo shifting tool and RIH to 1030'. 10:00 - 11:00 1.00 CASE N DPRB !SURF With TAM shifting tool at TAM collar, PT above tool to 1400 psi. OK. PT below tool to 600 psi. OK. 11:00 - 12:00 1.00 CASE N DPRB SURF POOH with TAM combo shifting tool and lay down same. 12:00 - 13:00 1.00 CASE P SURF Close blind rams. Pressure test 9 5/8" casing to 3500 psi for !30 minutes. OK 13:00- 13:30 0.50 CASE N DPRB SURF ; Install wear bushing. 13:30 - 15:00 1.50 DRILL N DPRB PROD1 Make up BHA. Up load MWD. Install RA sources. 15:00 - 17:00 2.00 DRILL N DPRB PROD1 RIH to float collar 3381'. 17:00 - 18:00 1.00 DRILL P PROD1 Drill float collar, firm/hard cement, float shoe, and clean out 14' of rat hole to 3480'. 18:00 - 18:30 0.50 DRILL P PROD1 Drill 20' of new hole to 3500'. 18:30 - 20:00 1.50 DRILL P PROD1 Displace old mud in hole with new 10.3 ppg LSND mud. 20:00 - 21:30 1.50 DRILL P PROD1 PJSM. Perform LOT. Determined leak-off pressure to be 530 3si with 10.3 ppg mud in hole. Calc. eq. mud wt. = 13.84 ppg. 21:30 - 00:00 2.50 DRILL P PROD1 Dir. drill from 3500' to 3814'. AST = 0.15 hrs; ART = 1.15 hfs; ADT = 1.3 hrs. 8/22/2001 00:00 - 11:30 11.50 DRILL P PROD1 Dir. drill from 3814' to 5056'. ADT = 6 hrs; AST = 1 hr; ART = 5 hrs. 11:30 - 12:30 1.00 DRILL P PROD1 Pump sweep for short trip. Circ. bottoms up. 12:30 - 14:00 1.50 DRILL P PROD1 Flow check. OK. Short trip, POOH to 3431'. Nominal hole conditions. 14:00 - 14:30 0.50 DRILL P PROD1 Adjust brakes. Service top drive. 14:30 - 15:30 1.00 DRILL P PROD1 RIH to 5056'. Hole conditions OK. 15:30 - 00:00 8.50 DRILL P PROD1 Dir. drill from 5056' to 6014'. ADT= 4.9 hrs; AST = 1 hrs; ART Printed: 9/4/2001 5:05:20 PM BP EXPLORATION Page 4 of 7 Operations Summa Report Legal Well Name: 8-110i Common Well Name: S-110i Spud Date: 8/11/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/22/2001 15:30 - 00:00 8.50 DRILL P PROD1 =3.9 hrs. 8/23/2001 00:00 - 03:30 3.50 DRILL P PROD1 Dir.drill from 6014' to 6397'. AST -- 0.8 hrs; ART = 1.5 hrs; ADT = 2.3 hrs. 03:30 - 04:30 1.00 DRILL P PROD1 Circ. bottoms up for short trip. Flow check-OK. 04:30 - 05:30 1.00 DRILL P PROD1 Short trip 15 stands. POOH from 6397' to 4961'. Occasional 20K overpull. 05:30 - 06:30 1.00 DRILL P PROD1 RIH back to 6397' on short trip. Hole condition good. 06:30 - 00:00 17.50 DRILL P PROD1 Dir. drill from 6397' to 7933'. AST = 5.1 hrs; ART - 6.0 hrs; ADT = 11.1 hrs. Pump sweeps every 400'-500'. 8/24/2001 00:00 - 04:30 4.50 DRILL P PROD1 Dir. drill from 7933' to 8219'. AST = 0.9hrs; ART = 1.7 hfs; ADT= 2.6 hrs. 04:30 - 05:30 1.00 DRILL P PROD1 Circ. and condition hole for short trip. Pump sweep. 05:30 - 07:00 1.50 DRILL P PROD1 POOH to 6687'. Pulled tight at 6840'. 07:00 - 08:00 1.00 DRILL P PROD1 Wash and back ream from 6687' to 6526'. 08:00 - 08:30 0.50 DRILL P PROD1 Complete POH to 6304'. 08:30 - 09:30 1.00 DRILL P PROD1 RIH to 8219'. Wash last stand to bottom, precautionary. 09:30 - 19:30 10.00 DRILL P PROD1 Dir. drill from 8219' to 8792' (TD). Survey. AST = 0 hrs; ART = 8.1 hrs; ADT = 8.1 hrs. 19:30 - 21:00 1.50 DRILL P PROD1 Circ. and condition hole. Pump sweep. Flow check, OK. 21:00 - 00:00 3.00 DRILL P PROD1 POOH for short trip to 9 5~8" csg shoe. 35 stands out (5439') at 24:00 hrs. 8/25/2001 00:00 - 01:00 1.00 DRILL P PROD1 POOH for short trip to csg shoe. SLM to 3460'. 01:00 - 03:30 2.50 DRILL P PROD1 RIH to TD. 03:30 - 06:30 3.00 DRILL P PROD1 Circ and condition mud. Pump sweep and circ. out. Spot lube pill in open hole for logging. Pump dry job. Flow check, OK. 06:30 - 11:00 4.50 DRILL P PROD1 POOH to log. First 500 off bottom had intermittant overpull. Wiped tight spots without pump or rotation. Continued POH. SLM from 3460'. No correction on pipe strap. 11:00-12:00 1.00 DRILL P PROD1 POHwithBHA. LD flex collar. 12:00-14:00 2.00 DRILL P PROD1 PJSM. Remove RAsources. Download MWD. Lay down remaining BHA. 14:00 - 14:30 0.50 DRILL P PROD1 PJSM. Rig up electric line equipment for logging. 14:30 - 15:00 0.50 DRILL P PROD1 RIH w/CMR-GR. Could not get below 2150' (dogleg and magnet decentralizing tools). POH and lay down bow springs. 15:00 - 16:00 1.00 DRILL P PROD1 RIH with CMR-GR. Could not get below 2150'. POH and change tool profile. 16:00 - 17:00 1.00 DRILL P PROD1 RIH with CMR-GR. Could not get below 2150'. POH to pick up tool rollers. 17:00 - 18:00 1.00 DRILL P PROD1 Break down tool and pick up tool rollers. 18:00 - 00:00 6.00 DRILL P PROD1 RIH with CMR-GR to 8695'. Tool has 3 MRT's. Log Kuparuk interval from 8650' to 8450'. Ran 2 repeats between 8545' and 8480'. Logging Schrader Bluff interval from 7135' to 6350'. 8/26/2001 00:00 - 03:30 3.50 DRILL P PROD1 Complete CMR/GR logging through Schrader Blufffrom 7135' to 6350'. POH with wireline. 03:30 - 04:00 0.50 DRILL P PROD1 Rig down SWS E-line equipment and logging tools. 04:00 - 05:00 1.00 DRILL P PROD1 Pick up drill pipe conveyed MDT logging tools. 05:00 - 06:30 1.50 DRILL P PROD1 PJSM. Make up MDT. Confirm tool function and connections. 06:30 - 11:30 5.00 DRILL P PROD1 RIH with MDT on drill pipe to csg shoe at 3466'. Fill pipe at 30 spin and 120 psi. RIH to 6260' filling pipe every 10 stands. 11:30 - 12:00 0.50 DRILL P PROD1 Make up cable side entry sub (CSES). 12:00 - 13:00 1.00 DRILL P PROD1 RIH with pump-down wet connect head (PWCH) on wireline and latch into downhole wet connect head (DWCH). Install line clamp on CSES. Printed: 9/4/2001 5:05:20 PM BP EXPLORATION Page 5 of 7 Operations Summary Report Legal Well Name: S-110i Common Well Name: S-1 10i Spud Date: 8/1 1/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/26/2001 13:00 - 19:00 6.00 DRILL P PROD1 Run MDT log per SWS. Take pressure measurements in Schrader Bluff from 6472' to 6830'. 19:00 - 20:30 1.50 DRILL P PROD1 Make stop at 6848' to obtain fluid sample. Packers would not inflate due to plugging in pump-out system. 20:30 - 00:00 3.50 DRILL P PROD1 Take MDT pressure measurements from 6851' to 6998'. Had 9 unsuccessful attempts. Last good station was 6851'. 8/2712001 00:00 - 01:30 1.50 DRILL P PROD1 Log with MDT to 7005'. Reposition tool at 6700' to check pressure probe seal function. Unable to obtain seal. Tool failure. 01:30 - 02:00 0.50 DRILL P PROD1 POOH from 7005' to 6260'. Remove line clamp at CSES. Unlatch from DWCH and POH with wireline. Remove CSES. 02:00 - 03:30 1.50 DRILL P PROD1 Lay down wireline tools and sheaves. 03:30 - 08:00 4.50 DRILL P PROD1 POOH. Flow check at shoe-OK. 08:00 - 10:00 2.00 DRILL P PROD1 Lay down MDT tools. 10:00 - 10:30 0.50 DRILL P PROD1 Pull wear bushing. 10:30 - 11:00 0.50 DRILL P PROD1 Rig up to test BPOE. 11:00 - 15:30 4.50 DRILL P PROD1 Test BOPE. Test annular to 250 psi for 5 mini3000 psi for 10 min. Test rams, floor valves, kelly valves, and choke manifold to 250 psi for 5 mini3500 psi for 10 min--OK. Witnessing waived by Mr. Chuck Sheve, AOGCC Rep. 15:30 - 16:00 0.50 DRILL P PROD1 Pull test plug and run wear bushing. 16:00 - 16:30 0.50 DRILL P PROD1 Rig down test equipment. Clear floor. Blow down choke, kill line, and top drive. 16:30 - 18:00 1.50 DRILL P PROD1 PJSM. Pick up RFT tools and rig up E-line equipment. Perform diagnostic testing on RFT. Make up and run drill pipe conveyed. 18:00 - 20:00 2.00 DRILL P PROD1 RIH to shoe at 3466'. 20:00 - 21:00 1.00 DRILL P PROD1 Slip and cut drilling line. 21:00 - 21:30 0.50 DRILL P PROD1 Circ. drill pipe volume at 30 spin and 175 psi. 21:30-00:00 2.50 DRILL P PROD1 RIH. Fill DP at 4506' at 30 spm and 300 psi. Fill DP at 5751' at 30 spin and 375 psi. 18/28/2001 00:00 - 01:00 1.00 DRILL N DFAL PROD1 RIH with RFT tools on drill pipe to 6202'. 01:00 - 02:30 1.50 DRILL N DFAL PROD1 Make up CSES. Run wireline. Pump down PWCH. Latch up. Test latch-OK. Install line clamp. Rig snatch block. 02:30 - 04:00 1.50 DRILL N DFAL PROD1 RIH with DPC RFT to 6805'. 04:00 - 06:00 2.00 DRILL P PROD1 Logging RFT from 6805' to 6830. Only one successful pressure station in 6 attempts. Tool failed. 06:00 - 07:00 1.00 DRILL P PROD1 POOH to 6202' to the CSES. Hole not taking proper fill volume. 07:00 - 08:00 1.00 DRILL P PROD1 Flow check-OK. Remove clamp. Unlatch wireline. Break out CSES. Lay down wireline, CSES, and sheaves. 08:00 - 10:00 2.00 DRILL P PROD1 Circulate bottoms up. Condition mud. Clear floor and remove all wireline equipment. 10:00 - 13:00 3.00 DRILL P PROD1 POOH from 6202' to 3466'. Flow check - OK. 13:00 - 15:00 2.00 DRILL P PROD1 POOH to RFT tool. 15:00 - 16:00 1.00 DRILL P PROD1 Lay down RFT tools and clear floor. 16:00 - 17:00 1.00 DRILL P PROD1 Pick up clean out BHA and MT bit. 17:00 - 18:30 1.50 DRILL P PROD1 RIH to csg shoe. 18:30 - 19:00 0.50 DRILL P PROD1 Circulate bottoms up and condition mud. 19:00 - 21:00 2.00 DRILL P PROD1 RIH to 6976'. 21:00 - 21:30 0.50 DRILL P PROD1 Slowly break circ. Circ. 2000 strokes bringing rate slowly up to 510 gpm and 1250 psi. 21:30 - 22:00 0.50 DRILL P PROD1 RIH to 8697'. Printed: 9/4/2001 5:05:20 PM BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: S-1 10i Common Well Name: S-110i Spud Date: 8/11/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/28/2001 22:00 - 22:30 0.50 DRILL P PROD1 Wash and ream from 8697' to 8792', precautionary. Hole condition appears good. 22:30 - 00:00 1.50 DRILL P PROD1 Circulate and condition mud. Rotate and reciprocate drill pipe. 8/29/2001 00:00 - 02:30 2.50 DRILL P PROD1 Circ. sweep. Circ. & cond. mud at 606 gpm and 1650 psi. Spot lube pill in open hole. Pump dry job. 02:30 - 08:30 6.00 DRILL P PROD1 Pull 6 stands( through HRZ) and rack in derrick. POOH & LDDP. 08:30 - 10:00 1.50 DRILL P PROD1 Lay down BHA. Clear floor. 10:00 - 10:30 0.50 DRILL P PROD1 Pick up test joint and pull wear bushing. 10:30 - 11:00 0.50 DRILL P PROD1 Pick up casing tools and rig up floor. Change bales. 11:00 - 12:00 1.00 DRILL N SFAL PROD1 Lost high line power. Bring generators on line. Check SCR. 12:00 - 13:30 1.50 DRILL P , PROD1 Continue rigging up to run casing. Hang tongs, rig up Franks tool, set slips and hang elevators. 13:30 - 18:00 4.50 DRILL P i PROD1 PJSM Run 7" casing to 3451'. 18:00 - 18:30 0.50 DRILL P PROD1 Break circ. at shoe and circ. one annular volume staging up from 1.5 bpm to 6.5 bpm at 450 psi. PU = 135K, SO = 105K. 18:30 - 22:00 3.50 DRILL P PROD1 Run 7" casing to 6434', PU - 242K, SO = 120K. 22:00 - 23:00 1.00 DRILL N SFAL PROD1 Repair casing slips. Slip retaining pin came loose. Repaired and secured pin with cotter key. 23:00 - 00:00 1.00 DRILL P PROD1 Running 7" casing. 185 of 215 joints run. Full returns and hole conditions good. 8/30/2001 00:00 - 03:00 3.00 CASE P PROD1 Compl. running 215 jts. 7" 26#, L-80, MBTC casing. Make up mandrel hanger and landing jt. Lost returns when running jts. 188 and 189. Regained returns. Total fluid lost during running = 19 bbls. 03:00 - 04:30 1.50 CASE P PROD1 Break circ. at 2 BPM and 600 psi. Staged up to 5 BPM at 600 psi. Reciprocating while circulating. PU = 310K, SO = 145K. 04:30 - 05:00 0.50 CASE P PROD1 Lay down Franks tool. Make up cement head and cementing hose. 05:00 - 08:00 3.00 CASE P PROD1 Pump 10 bbl CWl00 spacer, PT lines to 3500 psi. Drop bottom plug. Pump 50 bbls MUDPUSH XL, mix and pump 390 sacks (165 bbl) DIS LiteCrete at 12 ppg. Drop top plug. Pump and displace with 333 bbls seawater at 6.5 BPM, slowing to 2 BPM prior to bumping plug. Landed csg in hanger after 250 bbl displacement. Bumped plug 1 bbl over calc. Pressure to 2400 psi. Full returns while cementing. Check floats-OK. ClP at 0741, 8/31/01. 08:00 - 09:30 1.50 CASE P :PROD1 Lay down cementing equipment and casing tools. 09:30 - 10:30 1.00 CASE P PROD1 Pick up one stand out of derrick and make up packoff running tool and casing hanger packoff. Set packoff and run in LDS. Test packoff to 5000 psi-OK. LD running tool. 10:30 - 11:00 0.50 CASE P PROD1 Run wear bushing. 11:00- 12:00 1.00 CASE P PROD1 Change bales. Clear floor. 12:00 - 16:00 4.00 CASE P PROD1 Lay down last 6 stands DP out of derrick. Pick up tubing handling equipment. 16:00 - 17:00 1.00 CASE P PROD1 Pick up E-line equipment and rig up to log. 17:00 - 19:00 2.00 CASE P PROD1 Ran in with USIT/CBL/Temp/GR logging tools. 19:00 - 20:00 1.00 CASE P PROD1 Tool problems. Change sonde sections and replace USIT unit. Run diagnostics and repair. 20:00 - 00:00 4.00 CASE P PROD1 Log USIT/CBLFFemp/GR from 8665' to 6500'. 8/31/2001 00:00 - 04:30 4.50 CASE P PROD1 Run second pass on USlT/CBLFFemp/GR from 8665' to 6150'. No conclusive improvement in bonding over the run made 12 hrs. after ClP. Printed: 9/4/2001 5:05:20 PM BP EXPLORATION Page 7 of 7 Operations Summa Report Legal Well Name: 8-110i Common Well Name: S-110i Spud Date: 8/11/2001 Event Name: DRILL+COMPLETE Start: 8/13/2001 End: Contractor Name: DOYON Rig Release: 9/1/2001 Rig Name: DOYON 14 Rig Number: Date From - To Hours Activity Code NPT Phase Description of Operations 8/31/2001 04:30 - 08:30 4.00 CASE P PROD1 Evaluate logging results. Partial rig down of logging tools. Pick up logging tools and prepare for 27-hour (post ClP) logging pass. 08:30 - 12:30 4.00 CASE P PROD1 RIH with USlT and log from 8665' to 3450'. Indicates possibly a slight bonding improvement trend over the 12 and 18 hour passes. 12:30 - 13:00 0.50 CASE P PROD1 Lay down logging equipment. 13:00 - 13:30 0.50 CASE P PROD1 Pull wear bushing. 13:30 - 14:30 1.00 CASE P PROD1 Pressure test 7" casing to 4000 psi for 30 minutes-OK. 14:30 - 18:30 4.00 RUNCOr 13 COMP Mobilize new HES perforating gun configuration. 18:30 - 21:30 3.00 RUNCOr 13 COMP PJSM. Pick up HES tubing conveyed perforating guns and associated BHA. 21:30 - 22:00 0.50 RUNCO~ 13 COMP Pick up bottom hole completion jewelry and Baker S-3 packer. 22:00 - 00:00 2.00 RUNCO~ 13 COMP Run 3.5", 9.2 #, L-80, NSCT completion tubing. 42 of 256 joints run as of 2400 hrs. 9/1/2001 00:00 - 07:30 7.50 RUNco~ 13 COMP Compl. running 3.5" completion string w/tbg conveyed perf guns. Running speed of 1 sec/ft. PU = 130K, SO = 90K. 07:30 - 08:00 0.50 RUNCO~ 13 COMP Space out tubing. PU tbg hanger and landing jr. Land tubing. 08:00 - 10:00 2.00 RUNCOr 13 COMP RU E-line equipment. Run GR/CCL correlation log. No spacing adjustment required. 10:00 - 10:30 0.50 RUNCO~ 13 COMP RILDS. RU to inhibit IA. 10:30 - 11:30 1.00 RUNCO~ 13 COMP PJSM. Pump 220 bbls corrosion ihnibited seawater into 3.5" X 7" annulus at 3 BPM and 300 psi. 11:30 - 14:00 2.50 RUNCO~ 13 COMP Drop ball and rod. Set packer. Test tubing to 4000 psi for 30 min-OK. Bled to 2000 psi. PT annulus to 4000 psi. Bled tubing pressure and sheared RP valve. 14:00 - 15:00 1.00 RUNCO~ 13 COMP Lay down landing joint. Set TWC. Test below to 1000 psi. 15:00 - 16:30 1.50 BOPSUF P COMP Nipple down BOPE. Pump down OA with 86 bbl mud to clear annulus. 16:30 - 19:00 2.50 WHSUR P COMP Install adapter flange and test packoff to 5000 psi. Nipple up and test tree to 250 psi and 5000 psi for 10 min-OK. 19:00 - 19:30 0.50 WHSUR P COMP Rig up lubricator and pull TWC. 19:30 - 20:30 1.00 WHSUR P COMP Freeze protect 7" X 9 5~8" OA by bullheading 79.5 bbls dead crude at 2.5 BPM and 1900 psi. SIP = 900 psi. 20:30 - 23:30 3.00 WHSUR P COMP Freeze protect tubing and IA by pumping 88 bbls of diesel down IA and U-tube down tubing. 23:30 - 00:00 0.50 WHSUR P COMP Set BPV in tree. Secure well. RREL @ 23:59, 9/01/01. Prep to move rig and camp to D-19B. Printed: 9/4/2001 5:05:20 PM Well: S-110 Rig Accept: 08/13/01 Field: Prudhoe Bay / Aurora Rig Spud: 08/13/01 APl: 50-029-23030-00 Rig Release: 09/01/01 Permit: 201-129 Drilling Ri~]: Doyon 14 POST - RIG WORK 09/10/01 Pulled ball and rod. Pulled dummy gas lift valves. 09/11/01 Set gas lift valves. 10~O3~O 1 Drift with 2.50" centralizer to 6100' sim, to ensure tubing clear. Drop 11' x 1.25" firing prong to set off perf gun. Indication guns fired. 10/14101 Begin static BHP survey. Tagged TD at 8551' wlm (8585' MD). Make stop at 8545' and 8526' MD. 10/15/01 Complete static survey. Set catcher sub, pull gas lift valves and set dummy valves. Set petredat side- pocket gauge. Pull catcher sub. MITIA to 3500 psi. 10/19/01 MITIA to 3500 psi, passed. 10/22/01 Frac'd 'C' sands with YF125LG and 106,342# of 16/20 carbolite. Placed 85,657# behind pipe. Left 20,700# in casing. Screened out with 59 bbls of 8 ppga on perfs to max treat at 8422 psi. Average treat - 4300 psi. Estimate top of sand at 4849' if packed, expect bridges to surface. Recovered all saver cups. 10/23/01 Make up 2.25" BDN. FCO to 8463' ctm. Well flowing. Shut-in with 480 psi WHP. Consult with PE. Did not want to damage formation or flow back proppant pack without separator. Pull out of hole. Freeze protect from 3000' with 23 bbls crude and 45 bbls MeOH. 08-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well S-110 Gyro Dear Dear SidMadam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 0.00' MD 'MD 0.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) FtECE VED SEP 1 :,.~aC, a ~J~ ~ G~ Cons. Com~i~on North Slope Alaska Alaska Drilling & Wells PBU_ WOA S Pad, Slot S- 110 S-110 Gyro Job No. AKMM11134, Surveyed: 24 August, 2001 DEFINITIVE SURVEY REPORT 8 September, 2001 Your Ref: 500292303000 Surface Coordinates: 5980684.85 N, 618929.96 E (70° 21' 21.1766" N, 149° 02' 02.8967" W) Kelly Bushing: 69.55ft above Mean Sea Level A Halliburton Company Survey Ref: svy10944 'Sperry-Sun Drilling Services Survey Report for S-110 Gyro Your Ref: 500292303000 Job No. AKMM11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl: Azim. Depth Depth (ft) , (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 0.000 0.000 -69.55 0.00 0.00 N 0.00 E 5980684.85 N 618929.96 E 80.00 0.250 191.000 10.45 80.00 0.17 S 0.03 W 5980684.68 N 618929.93 E 167.00 0.750 121.000 97.45 167.00 0.65 S 0.42 E 5980684.21 N 618930.39 E 255.00 1.750 116.000 185.42 254.97 1.54 S 2.12 E 5980683.35 N 618932.10 E 345.00 2.750 112.000 275.35 344.90 2.95 S 5.36 E 5980681.99 N 618935.36 E 439.00 5.000 100.000 369.13 438.68 4.50 S 11.48 E 5980680.53 N 618941.51 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to S-110. Northings and Eastings are relative to S-110. Magnetic Declination at Surface is 26.434° (10-Aug-01) . The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from S-110 and calculated along an Azimuth of 57.780° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 439.00ft., The Bottom Hole Displacement is 12.33ft., in the Direction of 111.418° (True). Survey tool program for S-110 Gyro From To Measured Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) (ft) (ft) 0.00 0.00 439.00 438.68 Survey Tool Description Tolerable Gyro Alaska Drilling & Wells PBU WOA S Pad -- Dogleg Vertical Rate Section Comment (°/100fi) 0.00 0.313 -0.12 0.810 0.01 1.142 0.97 1.124 2.96 2.532 7.31 Tolerable Gyro 8 September, 2001 - 22:17 Page 2 of 2 Dr#/Quest 2.00.08.005 08-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Definative Survey Re: Distribution of Survey Data for Well S-110 Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 439.00' MD 'MD 8,792.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 12 2001 Alaaka Oil & Gas Cons. Commission Anchorage DEFINiTiVE North Slope Alaska Alaska Drilling & Wells PBU_ WOA S Pad, Slot S-110 S-110 Job No. AKZZl1134, Surveyed: 24 August, 2001 SURVEY REPORT 8 September, 2001 Your Ref: API500292303000 Surface Coordinates: 5980684.85 N, 618929.96 E (70° 21'21.1766"N, 149° 02' 02.8967" W) Kelly Bushing: 69.55ft above Mean Sea Level DRIlL. lNG ...... Survey Ref: svy10941 A Halliburton Company North Slope Alaska Measured Depth (ft) 439.00 Incl: 5.000 Azim. 100.000 Sub-Sea Depth (ft) 369.13 Vertical Depth (ft) 438.68 464.26 5.700 93.890 394.28 463.83 554.52 8.150 87.540 483.88 553.43 641.60 10.990 89.450 569.74 639.29 732.76 13.900 93.010 658.75 728.30 828.65 15.270 92.250 751.55 821.10 925.16 16.390 82.840 844.41 913.96 1020.98 16.460 80,450 936.32 1005,87 1116.51 16.550 77.060 1027.92 1097.47 1210.89 18.350 72.830 1117.95 1187.50 1208.57 1299.21 1388.54 1476.21 1560.89 1306.60 19.230 1402.59 19.200 1498.56 23.620 1594.87 25.270 1690.51 30.080 69.710 67.940 65.120 63.380 61.190 1278.12 1368.76 1458.09 1545.76 1630.44 1785.27 34.120 61.200 1641.14 1710.69 1853.02 35.600 59.820 1696.74 1766.29 1883.54 36.720 59.890 1721.38 1790.93 1914.62 38.110 '58,900 1746.06 1815.61 1946.11 39.610 58.130 1770.58 1840.13 1978.80 40.840 58.650 i795.54 1865.09 2074.55 44.730 59.920 1865.80 1935.35 2169.00 52.150 61.040 1928.42 1997.97 2202.47 53.600 61.740 1948.62 2018.17 2266.03 53.450 62.070 1986.40 2055.95 2362.39 52.920 62.930 2044.14 2113.69 2458.46 50.490 60.340 2103.68 2173.23 2554.78 47.880 58.790 2166.63 2236.18 2651.15 45.800 55.800 2232.56 2302.11 2746.42 45.130 53.320 2299.38 2368.93 Sperry-Sun Drilling Services Survey Report for S-110 Your Ref: API500292303000 Job No. AKZZ11134, Surveyed: 24 August, 2001 DEFiNitiVE Alaska Drilling & Wells PBU_WOA S Pad Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4.50 S 11.48 E 5980680.53 N 618941.51E 4.78 S 13.82 E 5980680.29 N 618943.85 E 4.81 S 24.68 E 5980680.43 N 618954.72 E 4.47 S 39.15 E 5980681.01N 618969.18 E 4.96 S 58.78 E 5980680.83 N 618988.81 E Dogleg Vertical Rate Section (°/100ft) 7.31 3.569 9.14 2.84O 18.32 3.281 30,74 3.300 47.09 Comment Tie On Point AK-6 BP_IFR-AK 6.06 S 82.90 E 5980680.11N 619012.95 E 4.86 S 109.12 E 5980681.72 N 619039.14 E 0.92 S 135.92 E 5980686.09 N 619065.87 E 4.37 N 162.52 E 5980691.80 N ' 619092.40 E 11.77 N 189.82 E 5980699.63 N 619119.57 E 1.443 66.91 2.898 89.72 O.709 114.50 1.012 139.83 2.332 166.87 21.68 N 219.00 E 5980710.01N 619148.59 E 33.09 N 248.46 E 5980721.88 N 619177.86 E 47.11N 280.54 E 5980736.41N 619209.72 E 64.44 N 316.43 E 5980754.31 N 619245.32 E 85.15 N 355.70 E 5980775.64 N 619284.26 E 1.395 196.84 O.608 227.84 4.728 262.46 1.869 302.06 5.140 346.33 109.41N 399.82 E 5980800.59 N 619327.99 E 128.48 N 433.52 E 5980820.20 N 619361.38 E 137.52 N 449.09 E 5980829.48 N 619376.81E 147.14 N 465.34 E 5980839.36 N 619392.91E 157.46 N 482.19 E 5980849.94 N 619409:59 E 4.263 396.58 2.475 435.26 3.672 453.26 4.873 472.13 5.004 491.89 168.52 N 500.17 E 5980861.29 N 619427.39 E 201.71 N 556.08 E 5980895.36 N 619482.77 E 236.47 N 617.55 E 5980931.10 N 619543,68 E 249.25 N 640.98 E 5980944,25 N 619566.90 E 273.32 N 686.07 E 5980969.03 N 619611.60 E 3.900 512.99 4.161 577.99 7.906 648.54 4.642 675.17 0.480 726.15 308.94 N 754.49 E 5981005.73 N 619679.45 E 344.73 N 820.84 E 5981042.57 N 619745.22 E 381,63 N 883.69 E 5981080,47 N 619807.48 E 419.58 N 942.84 E 5981119.35 N 619866.02 E 458.94 N 998.17 E 5981159.58 N 619920.72 E 0.902 803.03 3.297 878.24 2.971 951.09 3.127 1021.36 1.984 1089.15 8 September, 2001 - 22:20 Page 2 of 6 DrillQuest 2. 00.08. 005 Sperry-Sun Drilling Services Survey Report for S-110 Your Ref: APi500292303000 Job No. AKZZ11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Depth (ft) Incl; Azim. Sub-Sea Depth m) Vertical Depth (ft) 2841.31 44.490 53.110 2366.70 2436.25 2936.67 43.790 52.660 2435.13 2504.68 3032.60 43.410 52.520 2504.60 2574.15 3129.16 43.140 52.040 2574.91 2644.46 3224.77 43.190 52.040 2644.64 2714.19 3320.24 45.620 53.840 2712.85 2782.40 3411.60 46.680 53.750 2776.14 2845.69 3465.10 45.820 54.070 2813.13 2882.68 3559.04 48.400 54.640 2877.06 2946.61 3656.40 49.470 53.500 2941.02 3010.57 3752.41 50.060 52.670 3003.03 3072.58 3848.06 48.340 54.470 3065.54 3135.09 3944.63 48.240 53.850 3129.79 3199.34 4040.23 47.890 53.580 3193.68 3263.23 4136.24 48.060 56.260 3257.96 3327.51 4230.24 48.980 54.590 3320.22 3389.77 4324.76 47.110 56.170 3383.41 3452.96 4421.75 47.490 56.120 3449.19 3518.74 4517.93 47.820 55.180 3513.97 3583.52 4612.80 45.660 =56.490 3578.99 3648.54 3645.70 3714.53 3782.53 3850.51 3915.62 4708.08 45.450 56.240 4805.22 44.320 58.640 4900.66 44.820 59.570 4996.48 44.790 59.380 5089.88 46.810 60.000 3715.25 3784.08 3852.08 3920.06 3985.17 5187.78 46.910 59.650 3982.57 4052.12 5283.74 47.620 59.180 4047.68 4117.23 5378.55 47.710 58.410 4111.54 4181.09 5476.25 48.200 57.180 4176.97 4246.52 5570.72 48.360 56.550 4239.84 4309.39 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 498.99 N 1051.73E 5981200.47 N 619973.63 E 539.06 N 1104.69 E 5981241.38 N 620025.95 E 579.25 N 1157.23 E 5981282~40 N 620077.85 E 619.75 N 1209.59 E 5981323.72 N 620129.56 E 659.98 N 1261.16 E 5981364,77 N 620180.48 E 700.21N 1314.48 E 5981405.84 N 620233.15 E 739.13 N 1367.64 E 5981445.60 N 620285.69 E 761.89 N 1398.87 E 5981468.86 N 620316.55 E 801.99 N 1454.80 E 5981509.84 N 620371.84 E 845.07 N 1514.23 E 5981553.85 N 620430.58 E 889.10 N 1572.83 E 5981598.80 N 620488.47 E 932.10 N 1631.07 E 5981642.73 N 620546.03 E 974.31 N 1689.51 E 5981685.86 N 620603.79 E 1016.40 N 1746.84 E 5981728.85 N 620660.44 E 1057.38 N 1805.19 E 5981770.75 N 620718.14 E 1097.35 N 1863.17 E 5981811.64 N 620775.47 E 1137.29 N 1921.00 E 5981852.49 N 620832.67 E 1177.00 N 1980.20 E 5981893.14 N 620891.22 E 1217.11 N 2038.88 E 5981934.17 N 620949.26 E 1255.91 N 2096.04 E 5981973.88 N 621005.79 E 1293.59 N 2152.67 E 5982012.45 N 621061.82 E 1330.49 N 2210.43 E 5982050.27 N 621118.99 E 1364.88 N 2267.90 E 5982085.56 N 621175.91 E 1399.18 N 2326.07 E 5982120.78 N 621233.52 E 1432.96 N 2383.88 E 5982155.48 N 621290.79 E 1468.87 N 2445.63 E 5982192.36 N 621351.96 E 1504.73 N 2506.31E 5982229.18 N 621412.06 E 1541.04 N 2566.25 E 5982266.44 N 621471.42 E 1579.71 N 2627.64 E 5982306.08 N 621532.19 E 1618.25 N 2686.68 E 5982345.55 N 621590.61 E Dogleg Rate (°/100ft) 0.692 0.804 0.409 0.441 0.052 2.867 1.162 1.665 2.782 1.410 0.902 2.294 0.490 0.422 2.081 1.652 2.336 0.394 0.800 2.489 0.289 2.096 0.861 0.143 2.214 0.280 0.823 0.608 1.061 0.526 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 1155.82 1221.98 1287.87 1353.75 1418.83 1485.39 1551.11 1589.67 1658.37 1731.62 1804.66 1876.87 1948.81 2019.75 2090.97 2161.33 2231.55 2302.80 2373.84 2442.88 2510.88 2579.42 2646.38 2713.87 2780.79 2852.18 2922.63 2992.71 3065.26 3135.76 8 September, 2001 - 22:20 Page 3 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling ServiceS Survey Repor. t for S-110 Your Ref: APi500292303000 Job No. AKZZ11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Depth (ft) Incl; Sub-Sea Depth (ft) 5666,99 48,090 56,760 4303.97 5762.41 48,480 55,660 4367.47 5859.20 48,810 55,620 4431,42 5954,81 49,130 52,270 4494.19 6049,57 49,350 52.260 4556.06 Vertical Depth (ft) 4373,52 4437,02 4500,97 4563,74 4625,61 6146.67 48,270 51,840 4620.01 4689,56 6242,54 48,260 53,250 4683.83 4753.38 6337,30 45,710 54,590 4748.47 4818,02 6432.85 42,970 55,280 4816.80 4886,35 6528.97 40,720 53,870 4888,40 4957.95 6625.31 37,130 54,140 4963.34 5032,89 6722,09 32,360 54,820 5042,84 5112,39 6817.24 28,250 55,090 5124,97 5194,52 6912,50 25,480 56,680 5209.94 5279,49 7008.40 23,610 56,590 5297,17 5366,72 7104.10 20,850 55,260 5385.75 5455.30 7200.41 19,040 54,500 5476.28 5545,83 7296,72 17,380 55,100 5567,77 5637.32 7392,53 16,180 54,800 5659,49 5729.04 7488.68 13,980 ,60,250 5752,33 5821,88 7584.58 11,610 57,290 5845.85 5915,40 7680.35 10,530 56,070 5939,83 6009,38 7775,99 9,390 56,250 6034,03 6103,58 7872.05 8,520 60.410 6128.92 6198.47 7967.80 6,630 63,430 6223.83 6293.38 8062.68 4.370 51.960 6318.27 6387.82 8160.64 3.370 55.730 6416.00 6485.55 8255.11 3.360 57.180 6510,31 6579.86 8350.23 3.090 56.710 6605.28 6674.83 8447.03 3.090 54.110 6701.94 6771.49 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1657.72 N 2746,66 E 5982385,97 N 621649.96 E 1697.33 N 2805,85 E 5982426,51N 621708.51E 1738.34 N 2865,83 E 5982468.47 N 621767.83 E 1780,78 N 2924.12 E 5982511,83 N 621825,44 E 1824.71N 2980,88 E 5982556,65 N 621881.50 E 1869.64 N 3038,50 E 5982602.49 N 621938.40 E 1913,15 N 3095.29 E 5982646,90 N 621994,49 E 1953.96 N 3151.27 E 5982688.59 N 622049,81E 1992.33 N 3205,92 E 5982727.82 N 622103.85 E 2029,48 N 3258.18 E 5982765.80 N 622155.51E 2065.05 N 3307,14 E 5982802,15 N 622203,90 E 2097,10 N 3352.01 E 5982834,91 N 622248,25 E 2124.67 N 3391,30 E 5982863,10 N 622287,11 E 2148.84 N 3426,92 E 5982887.82 N 622322,33 E 2170,74 N 3460.19 E 5982910.25 N 622355,25 E 2191.01N 3490.19 E 5982930,99 N 622384,93 E 2209,90 N 3517,07 E 5982950,30 N 622411,50 E 2227,25 N 3541.65 E 5982968.05 N 622435,81 E 2243,13 N 3564.30 E 5982984.29 N 622458.20 E 2256,62 N 3585,33 E 5982998,11N 622479,02 E 2267.58 N 3603,51 E 5983009.36 N 622497.02 E 2277,68 N 3618.88 E 5983019,69 N 622512.23 E 2286.89 N 3632,62 E 5983029.12 N 622525,82 E 2294.76 N 3645.33 E 5983037.19 N 622538.39 E 2300,73 N 3656.44 E 5983043,34 N 622549,41 E 2305.41 N 3664.18 E 5983048,14 N 622557,08 E 2309.33 N 3669.50 E 5983052.15 N 622562,34 E 2312,40 N 3674.12 E 5983055,28 N 622566,91 E 2315.31N 3678.61E 5983058.27 N 622571.35 E 2318.28 N 3682.90 E 5983061.30 N 622575,60 E Dogleg Rate (°/lOOft) 0,324 0,953 0,342 2,664 O,232 1.159 1.098 2.883 2.912 2.537 31731 4,945 4,322 3,004 1,950 2,931 1,898 1.735 1,256 2,720 2,563 1.154 1,192 1,128 2,017 2,637 1,053 0,091 0.285 0,145 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 3207.54 3278.74 3351.34 3423,29 3494,73 3567.44 3638,68 3707,79 3774.49 3838,50 3898,89 3953,94 4001,88 4044,90 4084,73 4120.91 4153,72 4183,77 4211.40 4236,38 4257.61 4275,99 4292,53 4307,47 4320,06 4329.11 .4335.70 4341,24 4346.59 4351.80 8 September, 2001 - 22:20 Page 4 of 6 DrillQuest Z00.08.005 Sperry-Sun Drilling Services Survey Report for S-110 Your Ref: API500292303000 Job No. AKZZ11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Inch Azim. Depth Depth (ft) ~. (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8536.60 3.030 58.090 6791.38 6860.93 2320.94 N 3686.87 E 5983064.03 N 622579.52 E 8636.21 2.780 55.530 6890.86 6960.41 2323.70 N 3691.10 E 5983066.86 N 622583.70 E 8731.55 2.760 50.260 6986.09 7055.64 2326.48 N 3694.77 E 5983069.69 N 622587.33 E 8792.00 2.760 50.260 7046.47 7116.02 2328.34 N 3697.01E 5983071.59 N 622589.54 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertioal depths are relative to S-110. Northings and Eastings are relative to S-110. Magnetic Declination at Surface is 26.435° (10-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from S-110 and calculated along an Azimuth of 57.780° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8792.00ft., The Bottom Hole Displacement is 4369.10ft., in the Direction of 57.798° (True). Dogleg Rate (°/100ft) 0.246 0.283 0.268 0.000 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 4356.58 4361.63 4366.21 4369.10 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 439.00 438.68 4.50 S 11.48 E 8792.00 7116.02 2328.34 N 3697.01E Comment Tie On Point Projected Survey 8 September, 2001 -22:20 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-110 Your Ref: APi500292303000 Job No. AKZZ11134, Surveyed: 24 August, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Survey tool program for S-110 From Measured Vertical Depth Depth (ft) To Measured Depth (ft) Vertical Depth (ft) 0.00 0.00 439.00 438.68 439.00 438.68 8792.00 7116~02 Survey Tool Description Tolerable Gyro (S-110 Gyro) AK-6 BP_IFR-AK (S-110) 8 September, 2001 - 22:20 Page 6 of 6 DrillQuest 2.00.08.005 08-Sep-01 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well S-110 MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: Window / Kickoff Survey Projected Survey: 439.00' MD 'MD 8,792.00' MD (if applicable) Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) RECEIVED SEP 1 2 2001 Alaska Oil & Gas COns. Commission North Slope Alaska Alaska Drilling & Wells PBU_ WOA S Pad, Slot S-110 S-110 MWD Job No. AKMM11134, Surveyed: 24 August, 2001 SURVEY REPORT 8 september, 2001 Your Ref: API500292303000 Surface Coordinates: 5980684.85 N, 618929.96 E (70° 21' 21.1766" N, 149° 02' 02.8967" W) Kelly Bushing: 69.55ft above Mean Sea Level DRILL. i N'G Survey Ref: svy10942 A Halliburton Company Sperry-Sun Drilling Services Survey Report for S-110 MWD Your Ref: API500292303000 Job No. AKMM11134~ Surveyed: 24 AuguSt, 2001 North Slope Alaska Measured Depth (ft) Incl-, 439.0o 5.ooo 1 oo.o0o Sub-Sea Depth (ft) 369.13 Vertical Depth (ft) 438.68 464.26 5.700 93.780 394.28 463.83 554.52 8.150 87.470 483.88 553.43 641.60 10.990 89.460 569.74 639.29 732.76 13.900 92.930 658.75 728.30 828.65 15.270 92.340 751.55 821.10 925.16 16.390 82.850 844.41 913.96 1020.98 16.460 80.040 936.32 1005.87 1116.51 16.550 77.010 1027.92 1097.47 1210.89 18.350 72.940 1117.95 1187.50 1306.60 19.230 69.820 1208.57 1278.12 1402.59 19.200 68.120 1299.21 1368.76 1498.56 23.620 65.280 1388.54 1458.09 1594.87 25.270 63.550 1476.21 1545.76 1690.51 30.080 61.050 1560.89 1630.44 1785.27 34.120 61.250 1641.14 1710.69 1853.02 35.600 59.810 1696.74 1766.29 1883.54 36.720 59.840 1721.38 1790.93 1914.62 38.110 58.850 1746.06 1815.61 1946.11 39.610 58,140 1770.58 1840.13 1978.80 40.840 58.550 1795.54 1865.09 2074.55 44.730 59.900 1865.80 1935.35 2169.00 52.150 60.950 1928.42 1997.97 2202.47 53.600 61.630 1948.62 2018.17 2266.03 53.450 61.920 1986.40 2055.95 2362.39 52.920 63.200 2044.14 2113.69 2458.46 50,490 60,230 2103.68 2173.23 2554.78 47.880 58.780 2166.64 2236.19 2651.15 45.800 55.850 2232.56 2302.11 2746.42 45.130 53.370 2299.38 2368.93 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 4.50 S 11.48 E 5980680.53 N 618941.51E 4.78 S 13.82 E 5980680.29 N 618943.85 E 4.79 S 24.68 E 5980680.45 N 618954.72E 4.44 S 39.15 E 5980681.03 N 618969.18 E 4.92 S 58.78 E 5980680.87 N 618988.81 E 6.02 S 82.90 E 5980680.14 N 619012.95 E 4.85 S 109.12 E 5980681.74N 619039.14 E 0.82 S 135.90 E 5980686.19 N 619065.86 E 4.58 N 162.49 E 5980692.01N 619092.36 ~ 11.96 N 189.79 E 5980699.83 N 619119.54 E 21.82 N 218.99 E 5980710.15 N 619148.58 E 33.16 N 248.48 E 5980721.95 N 619177.88 E 47.09 N 280.60 E 5980736.38 N 619209.78 E 64.31N 316.54 E 5980754.18 N 619245.43 E 85.02 N 355.81 E 5980775.51 N 619284.38 E 109.31N 399.91E 5980800.49 N 619328.08 E 128.36 N 433.61E 5980820.08 N 619361.48 E 137.42 N 449,18 E 5980829.38 N 619376.90 E 147.05 N 465.43 E 5980839.27 N 619392.99 E 157.37 N 482.27 E 5980849.86 N 619409.67 E 168.45 N 500.24 E 5980861.22 N 619427.46 E 201.70 N 556.12 E 5980895.35 N 619482.81E 236.52 N 617.56 E 5980931.14 N 619543.69 E 249.34 N 640.96 E 5980944.33 N 619566.88 E 273.51 N 686.00 E 5980969.21 N 619611.53 E 309.06 N 754.46 E 5981005.85 N 619679.41E 344.75 N 820.85 E 5981042.59 N 619745.23 E 381.72 N 883.66 E 5981080.55 N 619807.45 E 419.65 N 942.83 E 5981119.41N 619866.01E 458.96 N 998.19 E 5981159.60 N 619920.74 E Dogleg Rate (°/100ft) 3.595 2.838 3.283 3.294 1.437 2.919 0.832 0,906 2.303 1.395 0.584 4.729 1.867 5.173 4.265 2.499 3.670 4.873 4.969 3.849 4.174 7.900 4.625 0.436 1.197 3.505 2,939 3.094 1,984 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 7.31 Tie On Point MWD Magnetic 9.14 18.33 30.76 47.11 66.93 89.73 114.54 139.91 166.95 196.90 227.89 262,50 302.08 346.35 396.60 435.28 453.28 472.15 491.91 513.02 578.02 648.56 675,20 726.18 803.06 878.25 951.11 1021.38 1089.18 8 September, 2001 - 22:26 Page 2 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-110 MWD Your Reft API500292303000 Job No. AKMM11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Depth (ft) Incl; Sub-Sea Depth (ft) Vertical Depth (ft) 2842.31 44.490 53.090 2367.41 2436.96 2936.67 43.790 52.460 2435.13 2504~68 3032.60 43.410 52.260 2504.60 2574.15 3129.16 43.140 51.790 2574.90 2644.45 3224.77 43.190 51.770 2644.64 2714.19 3320.24 45.620 53.570 2712.84 2782.39 3411.60 46.680 53.560 2776.13 2845.68 3465.10 45.820 54.070 2813.13 2882.68 3559.04 48.400 54.410 2877.06 2946.61 3656.40 49.470 53.460 2941.01 3010.56 3752.41 50.060 52.760 3003.03. 3072.58 3848.06 48.340 54.560 3065.53 3135.08 3944.63 48.240 53.940 3129.78 3199.33 4040.23 47.890 53.680 3193.67 3263.22 4136.24 48.060 56.320 3257.95 3327.50 4230.24 48.980 54.910 3320.22 3389.77 4324.76 47.110 56.570 3383.41 3452.96 4421.75 47.490 56.510 3449.18 3518.73 4517.93 47.820 55.390 3513.97 3583.52 4612.80 45.660 ,56.620 3578.98 3648.53 4708.08 45.450 56.720 3645.70 3715,25 4805.22 44.320 57.700 3714.52 3784.07 4900.66 44.820 58.620 3782.51 3852.06 4996.48 44.790 58.520 3850.50 3920.05 5089.88 46,810 60.170 3915.61 3985.16 5187.78 46.910 59.730 3982.56 4052.11 5283.74 47.620 59.090 4047.68 4117.23 5378.55 47.710 58.310 4111.53 4181.08 5476.25 48.200 57.230 4176.96 4246.51 5570.72 48.360 56.570 4239.83 4309.38 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 499.41 N 1052.32 E 5981200.91 N 619974.22 E 539.17 N 1104.65 E 5981241.48 N 620025.91E 579.57 N 1157.04 E 5981282.71N 620077.65 E 620.29 N 1209.21 E 5981324.26 N 620129.17 E 660.76 N 1260.60 E 5981365.54 N 620179.91 E 701.25 N 1313.72 E 5981406.86 N 620232.39 E 740.37 N 1366.73 E 5981446.83 N 620284.76 E 763.19 N 1397.92 E 5981470.14 N 620315.59 E 803.41N 1453.77E 5981511.24 N 620370.79 E 846.62 N 1513.10 E 5981555.39 N 620429.43 E 890.62 N 1571.72 E 5981600.31N 620487.34 E 933.53 N 1630.03 E 5981644.15 N 620544.96 E 975.65 N 1688.54 E 5981687.19 N 620602.79 E 1017,65 N 1745.93 E 5981730.09 N 620659.52 E 1058.54 N 1804.35 E 5981771.91N 620717.27 E 1098.32 N 1862.46 E 5981812.60 N 620774.75 E 1137.90 N 1920.54 E 5981853.09 N 620832.19 E 1177.20 N 1980.00 E 5981893.33 N 620891.03 E 1217.00 N 2038.90 E 5981934.07 N 620949.28 E 1255.64 N 2096.17 E 5981973.61 N 621005.93 E 1293.01N 2153.00 E 5982011.88 N 621062.16 E 1330.14 N 2210.62 E 5982049.92 N 621119.19 E 1365.47 N 2267.52 E 5982086.15 N 621175.52 E 1400.68 N 2325:14 E 5982122.27 N 621232.57 E 1434.80 N 2382.74 E 5982157.30 N 621289.62 E 1470.58 N 2444.58 E 5982194.05 N 621350.88 E 1506.45 N 2505.25 E 5982230.88 N 621410.98 E 1542.86 N 2565.13 E 5982268.24 N 621470.28 E 1581.55 N 2626.50 E 5982307.90 N 621531.02 E 1620.06 N 2685.57 E 5982347.34 N 621589.47 E Dogleg Rate (°/lOOft) 0.698 0.876 0.421 0.435 0.054 2.867 1.160 1.749 2.759 1.323 0.829 2.294 0.490 0.418 2.050 1.490 2.371 0.394 0.927 2.465 0.233 1.364 0.856 0.080 2.506 0.343 0.887 0.616 0.962 0.548 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 1156.55 1222.01 1287.87 1353.73 1418.77 1485.30 1551.01 1589.56 1658.25 1731.49 1804.54 1876.75 1948.70 2019.65 2090.88 2161.24 2231.48 2302.75 2373.79 2442.84 2510.85 2579.40 2646.37 2713.89 2780.82 2852.20 2922.65 2992.73 3065.28 3135.78 8 September, 2001 -22:26 Page 3 of 6 DrillQuest 2.00,08.005 Sperry-Sun Drilling Services Survey Report for S-110 MWD Your Ref: API500292303000 Job No. AKMM11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl= Azim. Depth Depth (ft) ~ (ft) (ft) 5666.99 48.090 56.660 4303.96 4373.5i 5762.41 . 48.480 55.200 4367.46 4437.01 5859.20 48.810 56.610 4431.41 4500.96 5954.81 49.130 52.080 4494.19 4563.74 6049.57 49.350 52.080 4556.06 4625.61 61'46.67 48.270 51.600 4620.00 4689.55 6242.54 48.260 53.250 4683.82 4753.37 6337.30 45.710 54.650 4748.46 4818.01 6432.85 42.970 55.260 4816.79 4886.34 6528.97 40.720 53.610 4888.40 4957.95 6625.31 37.130 53.910 4963.33 5032.88 6722.09 32.360 54.630 5042.84 5112.39 6817.24 28.250 54.970 5124.97 5194.52 6912.50 25.480 56.620 5209.94 5279.49 7008.40 23.610 56.530 5297.17 5366.72 7104.10 20.850 55.350 5385.75 5455.30 7200.41 19.040 54.500 5476.28 5545.83 7296.72 17.380 55.210 5567.76 5637.31 7392.53 16.180 54.960 5659.49 5729.04 7488.68 13.980 60.300 5752.33 5821.88 7584.58 11.610 57.380 5845.84 5915.39 7680.35 10.530 56.170 5939.83 6009.38 7775.99 9.390 56.290 6034.02 6103.57 7872.05 8.520 60.500 6128.91 6198.46 7967.80 6.630 63.340 6223.82 6293.37 8062.68 4.370 52.000 6318.26 6387.81 8160.64 3.370 55.790 6416.00 6485.55 8255.11 3.360 57.100 6510.31 6579.86 8350.23 3.090 56.660 6605.28 6674.83 8447.03 3.090 54.270 6701.93 6771.48 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 1659.57 N 2745.52 E 5982387.79 N 621648.79 E 1699.47 N 2804.52 E 5982428.63 N 621707.14 E 1740.72 N 2864.33 E 5982470.82 N 621766.29 E 1783.26 N 2922.54 E 5982514.28 N 621823.82 E 1827.37 N 2979.16 E 5982559.29 N 621879.74 E 1872.52 N 3036.62 E 5982605.34 N 621936.47 E 1916.14 N 3093.31E 5982649.86 N 621992.46 E 1956.92 N 3149.31E 5982691.52 N 622047.81E 1995.27 N 3203.98 E 5982730.74 N 622101.86 E 2032.55 N 3256.14 E 5982768.83 N 622153.43 E 2068.33 N 3304.95 E 5982805.39 N 622201.66 E 2100.55 N 3349.70 E 5982838.31N 622245.89 E 2128.22 N 3388.92 E 5982866.61N 622284.67 E 2152.44 N 3424.50 E 5982891.39 N 622319.86 E 2174.39 N 3457.75 E 5982913.86 N 622352.75 E 2194.64 N 3487.75 E 5982934.59 N 622382.43 E 2213.51N 3514.64 E 5982953.88 N 622409.02 E 2230.84 N 3539.25 E 5982971.60 N 622433.34 E 2246.67 N 3561.93 E 5982987.79 N 622455.77 E 2260.12 N 3582.99 E 5983001.57 N 622476.62 E 2271.06 N 3601.18 E 5983012.80 N 622494.63 E 2281.13 N 3616.57 E 5983023.11 N 622509.86 E 2290.33 N 3630.32 E 5983032,52 N 622523.46 E 2298.18 N 3643.03 E 5983040.58 N 622536.05 E 2304.15 N 3654.15 E 5983046.72 N 622547.06 E 2308.84 N 3661.89 E 5983051.53 N 622554.73 E 2312.75 N 3667.21 E 5983055.53 N 622559.99 E 2315.82 N 3671.83 E 5983058.67 N 622564.56 E 2318.74 N 3676.31 E 5983061.66 N 622569.00 E 2321.70 N 3680.61E 5983064.69 N 622573.25 E Dogleg Rate (°/100ft) 0.289 1.213 0.466 2.805 0.232 1.173 1.284 2.900 2.902 2.606 3.732 4.947 4.323 3.011 1.950 2.921 1.903 1.739 1.255 2.704 2.561 1.153 1.192 1.133 2.012 2.632 1.053 0.082 0.285 0.133 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 3207.56 3278.75 3351.34 3423.27 3494.70 3567.37 3638.60 3707.72 3774.41 3838.42 3898.79 3953.82 4001.76 4044.77 4084.60 4120.78 4153.59 4183.65 4211.28 4236.27 4257.49 4275.88 4292.41 4307.35 4319.94 4328.99 4335.58 4341.12 4346.48 4351.69 8 September, 2001 - 22:26 Page 4 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-110 MWD Your Ref: API500292303000 Job No. AKMM11134, Surveyed: 24 August, 2001 North Slope Alaska Measured Sub-Sea Vertical Depth Incl; Azim. Depth Depth (ft) , (ft) (ft) Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 8536.60 3.030 58.210 6791.38~ 6860.93 2324.36 N 3684.58 E 5983067.41 N 622577.18 E 8636.21 2.780 55.650 6890.86 6960.41 2327.11 N 3688.82 E 5983070.22 N 622581.37 E 8731.55 2.760 50.380 6986.09 7055.64 2329.87 N 3692.49 E 5983073.05 N 622585.00 E 8792.00 2.760 50.380 7046.47 7116.02 2331.73 N 3694.74 E 5983074.94 N 622587.21 E All data is in Feet (US) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths' are relative to S-110. Northings and Eastings are' relative to S-110. Magnetic Declination at Surface is 26.435° (10-Aug-01) The Dogleg Severity is in Degrees per 100 feet (US). Vertical Section is from S-110 and calculated along an Azimuth of 57.780° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 8792.00ft., The Bottom Hole Displacement is 4368.99ft., in the Direction of 57.744° (True). Dogleg Rate (°n00ft) 0.244 0.283 0.268 0.000 Alaska Drilling & Wells PBU_WOA S Pad Vertical Section Comment 4356.46 4361.51 4366.10 4368.98 Projected Survey Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 439.00 438.68 4.50 S 11.48 E 8792.00 7116.02 2331.73 N 3694.74 E Comment Tie On Point Projected Survey 8 September, 2001 - 22:26 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for S-110 MWD Your Ref: AP!500292303000 Job No. AKMM11134, Surveyed: 24 August, 2001 North Slope Alaska Alaska Drilling & Wells PBU_WOA S Pad Survey tool program for S-110 MWD From To Measured Vertical Measured Depth Depth Depth (ft) (ft) (ft) 0.00 0.00 439.00 439.00 438.68 8792.00 Vertical Depth (ft) 438.68 7116.02 Survey Tool Description Tolerable Gyro (S-110 Gyro) MWD Magnetic (S-110 MWD) 8 September, 2001 - 22:26 Page 6 of 6 DrillQuest 2. 00. 08. 005 9/10/2001 Schlumberger Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1430 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Well Job # Log Description Date Color Sepia BL CD S-110 ~-~C)I- IcrC/ 21387 PROCESSED CMR (SCHRADER) 08/25/01 2 S-110 - ' 21387 PROCESSED CMR (KUPARUK) 08/25/01 2 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 AK 99508-4254 RECEIVED SEP 1 4 2.001 Date Delivered: Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATTN: ~ Rece,v .bdJ~L~'" ~ ~ Re: $-110i Diverter dispensation Subject: Re: S-110i Diverter dispensation Date: Thu, 26 Jul 2001 14:35:16 -0800 From: Tom Maunder <tom_maunder@admin.state.ak. us> To: "Wesley, Dave E" <WesleyDE@BP.com> CC: Dan Stone <stonedm@bp.com> Dave, I confirm that a diverter waiver has been granted for S-110i. Sorry that notice didn't make the approval letter. Best of luck. Tom Maunder, PE Sr. Petroleum Engineer AOGCC Tom Maunder wrote: Dave, You are correct, the letter does not comment regarding your request for diverter waiver. I did recommend approval of the waiver request. The Commissioners are presently in an important teleconference. Please get back to me with regard to when spud is anticipated. Thanks. Tom "Wesley, Dave E" wrote: Mr. Maunder, Can you please verify whether or not we were granted a dispensation for the diverter system on the surface hole of the S-110i, We had requested a dispensation with our application for a Permit to Drill. Ms. Heusser has granted and signed a Permit to Drill, but there was nothing in the cover letter regarding the diverter dispensation. Please advise. Thank you, Dave Wesley, Jr. Operations Drilling Engineer Alaska Drilling & Wells 907 564 5773 Office 907 440 8631 Cell 907 564 4040 Fax wesleyde@bp, com Tom Maunder <tom m:aunder~admin.state.ak.us> Petroleum Engineer Alaska Oil and Gas Consentalion Commission 1 of 2 7/26/01 2:35 PM Re: S-110i Diverter dispensation Subject: Re: S-110i Diverter dispensation Date: Mon, 23 Jul 2001 16:22:58 -0800 From' Tom Maunder <tom_maunder@admin.state.ak. us> To: "Wesley, Dave E" <WesleyDE@BP.com> Dave, You are correct, the letter does not comment regarding your request for diverter waiver. I did recommend approval of the waiver request. The Commissioners are presently in an important teleconference. Please get back to me with regard to when spud is anticipated. Thanks. Tom "Wesley, Dave E" wrote: :> :> :> :> :> :> :> :> Mr. Maunder, Can you please verify whether or not we were granted a dispensation for the diverter system on the surface hole of the S-'110i. We had requested a dispensation with our application for a Permit to Drill. Ms. Heusser has granted and signed a Permit to Drill, but there was nothing in the cover letter regarding the diverter dispensation. Please advise. Thank you, Dave Wesley, Jr. Operations Drilling Engineer Alaska Drilling & Wells 907 564 5773 Office 907 440 8631 Cell 907 564 4040 Fax wesleyde@bp.com Tom Maunder <tom maund:er~_admin.state.ak, us> Petroleum Engineer Alaska Oil and Gas Consewalion Commission I of 1 7/25/01 10:10 AM ALASKA OIL AND GAS CONSERYA~I~ION CO~SSION TONY KNOWLES, GOVERNOR 333 W. 7~ AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Stone Senior Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re~ Prudhoe Bay Unit S- 110 BP Exploration (Alaska) Inc. Permit No: 201-129 Sur Loc: 4481' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM Btmhole Loc. 1513' NSL, 824' WEL, SEC. 26, T12N, R12E, UM Dear Mr. Stone: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has n°t been requested as part of the Permit to Drill application for Prudhoe Bay Unit S' 110. Blowout prevention equipment (BOPE) must be'tested in accordance with 20 AAC25 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, Julie M. Heusser Commissioner BY ORDER OF THE COMMISSION DATED this 20~day of July, 2001 jjc/Enclosures CC: Dep .artment of Fish & Game, Habitat Section w/o encl. Department of EnvirOnmental Conservation w/o encl. STATE Of ALASKA~ ~' ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 I [] Exploratory [] Stratigraphic Test [] Development Oil Re-EntryDrill [][] DeepenReddll lb. Type of well [] Service [] Development Gas [] Single Zone [] Multiple Zone la. Type of work 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Planned RKB = 70.9' Prudhoe Bay Field / Aurora 3. Address 6. Property Designation Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028257 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 4481' NSL, 4498' WEL, SEC. 35, T12N, R12E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1390' NSL, 1014' WEL, SEC. 26, T12N, R12E, UM S-110 Number 2S100302630-277 At total depth 9. Approximate spud date 1513' NSL, 824' WEL, SEC. 26, T12N, R12E, UM 08/01/01 Amount $200,000.00 12. Distance to nearest property line 113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 047448, 3765' MDI S-10215.65' away at 705' MD 2560 8752' MD / 7058' TVD ~16. TO be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 300' Maximum Hole Angle 48.63 ° Maximum surface 2730 psig, At total depth (TVD) 6698' ! 3400 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 WLD 80' Surface Surface 133' 133' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC-M 3407' Surface Surface 3407' 2861' 454 sx Arctic Lite III, 298 sx Class 'G' 8-3/4" 7" 26# L-80 BTC-M 8752' Surface Surface 8752' 7058' 273 sx LiteCrete, 225 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface Intermediate ProductionRECEIVED Liner JUN 2, 8 ~001 Perforation depth: measured Alaska Oil & Gas Cons. Commission Anchorage true vertical 20. Attachments [] Filing Fee [] Property Plat [] BOP Sketch [] Diverter Sketch [] Drilling Program [] Drilling Fluid Program [] Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer Name/Number: Dave Wesley, 564-5773 Prepared By Name/Number: Sondra Stewrnan, 564-4750 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Dan Stone .'.',,.:.: .i':. '.,: :: ...." .:' ;". Permit Number I APl Number I Approval Date I See cover letter 2.~2 -- /2 ?;~ 50- 0 ~. ?' '" 2..~ 0 -~ 0 '"'7 ' ~2~ (-.)' (~) I for other requirements Conditions of Approval: Samples Required [] Yes J~ No Mud Log Required [] Yes 1~ No Hydrogen Sulfide Measures I~Yes ~ No Directional Survey Required ~Yes [] No Required Working Pressure forBOPE []2K []3K []4K []5K []1OK []15K by order of Approved By Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: I S-110i Drill and Complete Plan Summary Type of Well (service / producer /injector): I Pre-Produced Injector Surface Location: As-Built Target Location: Kuparuk "C" sands Bottom Hole Location: X = 618,929.96 Y = 5,980,684.85 Slot: 12 4481' FSL, 4498' FEL Sec. 35, T12N, R12E Umiat X = 622,375.00 Y = 5,982,930.0 TVDss 6698 1390' FSL, 1014' FEL Sec. 26, T12N, R12E Umiat X = 622,563.28 Y = 5,983,055.96 TVDss 6987 1513' FSL (3765' FNL), 824' FEL (4455' FWL), Sec. 26, T12N, R12E Um I AFENumber: 15M0025 I I Estimated Start Date: 1 8/1/2001 I MD: 18752' I TVD: 7058' Rig: I Doyon 14 I Operating days to complete: 115.5 I BF/MS: 136.4' I IRKB: [70.9' I Well Design (conventional, slimhole, etc.): 19 5/8" X 7" USH-LS (4 1/2" X 3 1/2" tubing) I Objective: I Kuparuk Formation (C - Sand) Mud Program: 12 1/4" Surface Hole (0-3407' t: Fresh Water Surface Hole Mud Density Viscosity Yield Point APl FL PH (ppg) (seconds) (Ib/100ftz) (mls/30min) Initial 8.5 - 8.6 300 50 - 70 15 - 20 8.5 - 9.5 below -2000' MD 9.3 - 9.5 200 minimum 30 - 45 < 10 8.5 - 9.5 interval TD 9.6 max 200 minimum 25 - 35 6 - 8 8.5 - 9.5 8 3,~,, Intermediate / Production Hole (3407' - 8752'): Fresh Water LSND Interval Density Viscosity ~'P PV pH APl HTHP (ppg) (seconds) Filtrate Filtrate Surface 10.5 40-60 20-29 8-15 8.5-9.5 6cc to 4 < 10 by shoe to HRZ HRZ S-110i Page 1 Directional: Ver. Sperry-Sun WP-07 KOP: 300' Maximum Hole Angle: 48.63° from 2297' MD - 6273' MD Close Approach Wells: All wells pass major risk criteria. However, S-102 and S- 108 are close in the surface hole section; S-102 is 15.65' ctr-ctr @ 705', and S-108 is 22.4' ctr-ctr @ 926'. A surface gyro will be required to a maximum of 1000'. Logging Program: Surface Intermediate/Production Hole Drilling' MWD / GR Open Hole: Gyro (SSDS Photo) (1000' max) Cased Hole: None Drilling: MWD/G R/Res/PWD/(Recorded Neu/Den.) Open Hole: CMR+ / MDT ( Drill pipe conveyed) Cased Hole: USIT Formation TVDss TVDrkb Estimated pore pressure, PPG Tops SV6 1555 1625.9 Base Permafrost 1880 1950.9 SV5 2130 2200.9 SV4 2330 2400.9 SV3 2690 2760.9 SV2 2850 2920.9 SVl 3205 3275.9 8.7 ppg UG4 3545 3615.9 UG4A 3595 3665.9 10.3 UG3 3910 3980.9 UG1 4440 4510.9 Top Schrader (Ma) 4775 4845.9 8.7 WS2 Schrader Na 4995 5065.9 8.6 WS1 Schrader OA 5110 5180.9 8.5 Base Obf 5400 5470.9 8.2 CMl (Colville shales) 6460 6530.9 HRZ 6537 6607.9 9.6 - 9.8 Kalubik 6692 6762.9 Kuparuk Top (C) 6698 6768.9 Target Sand 9.80 ppg EMW LCU (KUP B) 6748 6818.9 Kuparuk A 6774 6844.9 Miluveach 6837 6907.9 TD 6987 7057.9 TD Criteria 150' below Miluveach top S-110i Page 2 Casin I/Tubinq Proc ram: Hole Casing/ Wt/Ft Grade Conn Length Top Btm Size Tbg O.D. MD/TVD MD/TVD bkb 30" 20" 91.5# H-40 WLD 80' GL 133/133 12 1/4" 9 5/8" 40.0# L-80 BTC-M 3407' GL 3407'/2861' 8 3/4" 7" 26.0# L-80 BTC-M 8752' GL 8752'/7058' Tubing 4 Y2" 12.6# L-80 NSCT 40 GL 40'/40' Tubing 3 1/2" 9.2# L-80 NSCT 8393' GL 8393'/6700' Cement Calculations: The following surface cement calculations are based upon a single stage job using a port collar as contingency if cement is not cirCulated to surface. Casin~c Basis: Size 19 5/8" Surface Lead: Based on 2060' of annulus in the permafrost @ 175% excess and 590' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface ITotal Cement Volume: Tail: Based on 500' TVD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At -2650' MD (2360' TVDbkb). Lead 1 359 bbl / 2016 f¢ / 454 sks of Dowell ARTICSET Lite 3 at 1 10.7 ppg and 4.44 cf/sk. Tail 61 bbl / 343 f¢ / 298 sks of Dowell Premium 'G' at 15.8 ppg and 1.15 cf/sk. Casinc. Basis: Size 17" Production Longstring I Lead: Based on TOC 500' above top of Ugnu 4A formation & 30% excess above Tail Lead TOC: 4125' MD, 3336' TVDbkb ITotal Cement Volume: Tail: Based on TOC 1000' MD above top of Kuparuk C target and 30% excess + 80' shoe volume Tail TOC: 7463' MD, 5781' TVDbkb I Lead 116 bbls / 651 f¢/273 sks of Dowell LiteCrete at 12.0 I ppg and 2.39 cf/sk. Tail 1 48 bbls / 270 f¢/225 sks of Dowell Premium 'G' at 15.8 I ppg and 1.20 cf/sk. S-110i Page 3 Well Control: Surface hole will be drilled with diverter if no dispensation is awarded. A waiver has been requested. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based upon calculations below BOP equipment will be tested to 3500 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- . Maximum anticipated BHP: · Maximum surface pressure: 3400 psi @ 6698' TVDss - Kuparuk C -Sands 2730 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) · Planned BOP test pressure: 3500 psi · Planned completion fluid: 8.6 ppg filtered seawater / 6.8 ppg Diesel Disposal: · No annular injection in this well. · Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS- 04 for injection. Haul all Class I wastes to Pad 3 for disposal. S-110i Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Rig Work: The 20" conductor is in place. 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Rig 1. 2. 3. Operations: MIRU Doyon 14. Nipple up diverter spool and riser. PU 4" DP as required and stand back in derrick. MU 12 1/4" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3407' MD / 2861' TVD. The actual surface hole TD will be +/-50' TVD below the base of the SV3 sands, into the shales. 4. Run and cement the 9 5/8", 40.0# surface casing back to surface. A port collar or stage tool will be run in the casing to allow for secondary cementing if cement is not circulated to surface during primary cementing operations. 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 3500 psi.(Notify AOGCC). Measure and record the RKB - BF height. 6. MU 8 3/4" drilling assembly with MWD/GR/Res/Neu/Den/PWD and RIH to float collar. Test the 9 5/8" casing to 3500 psi for 30 minutes. 7. Drill out shoe joints and displace well to LSND drilling fluid. Drill new formation to 20' below 9 5/8" shoe and perform Leak Off Test. 8. Drill ahead to -150' of rat hole below the Kuparuk. Condition hole for logging and POOH. 9. RU Schlumberger. Make a single Drill Pipe Conveyed run with CMR+ / MDT over the Kuparuk and Schrader Bluff formations. POOH and RD Schlumberger. 10. RIH with 8 3/4" cleanout assembly and condition hole for running the 7" casing. POOH laying down the 4" DP. 11. Run and cement the 7" production casing, as required, to cover all significant hydrocarbon intervals. Displace the casing with seawater during cementing operations and freeze protect the 7" x 9 5/8" annulus via downsqueeze. 12. Test the casing to 3500 psi for 30 min. 13. R/U Schlumberger; Run USIT Log. 14. Run the 4 1/2" X 3 Y2", 9.2#, L-80 gas lift completion assembly. Shear the RP valve, set TWC and test from below to 2800 psi. 15. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. 16. Freeze protect the well to -2200' and secure; set BPV and test to 500 psi. 17. Rig down and move off. Estimated Spud Date: 8/O 1/2001 S-110i Page 5 S-110i Job 1: MIRU Hazards and Contingencies ~ Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad in the last 12 months was on S-40 @ 70 ppm, (January 2001). The closest wells, regarding SHL, are S-100 and S-104, each measuring 8 ppm at last testing, (Nov. 2000). The closest wells, regarding BHL are S-40 and S-101. S-101 measured 8 ppm. S-40, as previously mentioned, measured 70 ppm. ~ The closest surface locations are S-102 and S-108, each at 30' from well S-110i. No surface shut-in's will be required. Reference RPs Operational Specifics: Job 2: Drillinq Surface Hole Hazards and Contingencies No faults are expected to be penetrated by S-110i in the surface interval. There are two "close approach" issues in the surface hole. All wells pass major risk criteria. The closest wells are S-102 at approximately 15' center-to-center at 705' MD and S-108 at approximately 22' center-to-center at 926' MD. ~ The SV4 sand may contain gas hydrates, though little or none have been encountered thus far in the recent S-pad development. Hydrate will be treated at surface with appropriate mud products. Reference RPs Operational Specifics: Job 3: Install Surface Casinq Hazards and Contingencies ~ It is critical that cement is circulated to surface for well integrity. 175% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. As a contingency, a 9-5/8" port collar will be positioned at _+1000'MD to allow a secondary circulation as required. Reference RPs Operational Specifics: S-110i Page 6 Job 7: Drillinq Intermediate/Production Hole Hazards and Contingencies S-110i will not cross any faults. The surface casing point is chosen just below the SV3 sands, leaving the SV1 exposed for the 8 3/4" hole. Differential sticking across the SV-1 sands has not been identified as a major issue in the Aurora development, though the potential exists with the higher mud weight required on this well. ~ KICK TOLERANCE: In the worst case scenario of 10.3 ppg pore pressure at the Kuparuk target depth, a fracture gradient of 13.0 ppg at the surface casing shoe, and 10.5 ppg mud in the hole, kick tolerance is 38.8 bbls. An accurate LOT will be required as well as heightened awareness for kick detection. Contact Drilling Superintendent if LOT is less than 13.0 ppg. ~ The mud program states that the mud weight will be 10.5 ppg from drill out of the surface shoe. This is based upon the possibility that the UGNU may be pressured to 10.3 ppg. The mud weight will be maintained at 10.5 all the way to TD. Reference RPs Operational Specifics Job 8: Loq Production Hole Hazards and Contingencies ~ The CMR is a magnetic log which is highly influenced by metal debris. Make every effort to keep the hole free of metal shavings. ~ Ensure the hole is in very good condition to avoid a stuck tool string or log impasse. Reference RPs Job 9: Case & Cement Production Hole Hazards and Contingencies The Ugnu 4A is expected to be oil bearing. For this reason the 7" casing will be cemented to 500' above the Ugnu 4A sand (the uppermost significant hydrocarbon). The top of the hydrocarbon interval should be verified with LWD resistivity log. ~ After freeze protecting the 7" x 9 5/8" casing annulus with 35 bbls of dead crude, the hydrostatic pressure alone will be less than the formation pressure. Ensure a double-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Expect trapped annulus pressure after pumping the dead crude. ~ The well will be underbalanced after displacing the cement with Sea Water. Verify that the Floats are holding before continuing operations and hold pressure on the well if they are not holding. Reference RPs S-110i Page 7 Operational Specifics: · Job 12: Run Completion Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics: Job 13: ND/NU/Release Riq Hazards and Contingencies ~ No hazards specific to this well have been identified for this phase of the well construction. Operational Specifics: S-110i Page 8 TREE = , 4" 5000 psi .WELLHF-A~ .D-- ....... FMC..!.! '.i ACTUATOR= KOP = 300 'Ma~'AngiJ' -;'4'91'3~'@ 2'~29;' Datum TV D= 6698 SS Minimum ID - 2.813" I 3-1/2" 9.3# L-80 I I 8413' S-110i [70' [1000' 12200' XO4-1/2"X3-1/2" ] TAM P°rt c°llar X Nipple, 2.813" ID ] GAS LIFT MANDRELS k STA MD TVD DEV TYPE MAN LATCH 3 4676 3700 2 7481 5800 1 8270 6576 -- ~~'~ X Nipple, 2.813" ID I --~s~6~' I I Production Packer 18373' -~ I Short Joint & RA tag 8376' I I X Nipple, 2.813" I.D. Is~ss' I I XN,,p,~.2.~",~ S4~' 1 Iw'~ PERFORATION SUMMARY REF LOG: ANGLE AT TOP PERF: I I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE I~ ] I ~''~'-~° mBTC I I 8752' I 18630' I I Short Joint & PA, tag I DATE REV BY COMMENTS 05/08/01 DWesley Original Proposed Completion 05/17/01 DWesley Revised based upon SSDS Wp#6 06/19/01 DWesley Revised based upon SSDS Wp#7 PRUDHOE BAY UNIT/AURORA FIELD WELL: S-110i PERMIT No: 200-??? APl No: 50-029-* .... Sec. 35, T12N, R12E, 4498' FEL, 4481' FSL BP Exploration (Alas ka) To: Commissioner, AOGCC Date: June 20, 2001 From: Dave Wesley, Jr. Subject: Dispensation for 20 AAC 25.035 (c) on Aurora S-110i BP Alaska Drilling and Wells requests your consideration of a waiver of the diverter system identified in 20 AAC 25.035 (c) "Secondary Well Control for Primary Drilling and Completion: Blowout Prevention Equipment and Diverter Requirements". Experience and data gathered, summarized herein, supports rationale of the request. To date, none of the 40-plus Ivishak wells at S-pad, nor the recent eleven Aurora/Polaris wells have experienced pressure control or shallow gas problems above the surface casing depth, apart from minor and inconsequential hydrate shows. The first eleven surface holes~ for the Aurora/Polaris development were drilled no deeper than the shale underlying the SV-1 sands; S-110i is planned to TD in the shallower SV-3 shale, as did the most recent wells (apart from S-106 where a diverter was installed). The shale underlying the SV1 is the deepest planned surface casing setting depth for future pad development wells. This casing point is +500' TVD above the Ugnu horizon. The shallowest and most recent RFT points recorded in the area are from S-201, recording a pore pressure of 1,423psi at 3,175' TVDss (8.6 ppg EMW) and not exceeding 8.7 ppg EMW above 3700' TVDss. S-110i is planned to reach 9.6 ppg mud weight before TD at -2,800' TVDss (3406' MD.) This planned mud weight, and the aforementioned RFT data, is plotted on the attached chart. Supporting surface hole gas detection information is on file with the AOGCC from recently drilled S-105. Your consideration of the waiver is appreciated. Sincerely, Dave Wesley, Jr. ADW Engineer 564-5773 500 1000 15OO 2000 2500 3OOO 3500 8 Aurora/Polaris Surface Hole Mud Weight MW (ppg) 9 10 Pore -~- S-100 ~S-101 S-102 S-105 -~- S-103 S-201 ~,~- S-216 S-213 --S-104 S-106 ""~"'S-110i Plan 4000 PGS 5/31/2001 S-107i Drilling Permit S-110i Kick Tol TKUP Page I of 2 6/21/2001 4:52 PM KICK TOLERANCE CALCULATOR For Vertical, Deviated or Horizontal Wells Version 5.0, May 1997 Well: i S-110i I Units (UK/US): US Kick Zone Parameters: 1 Openhole Size ? 2 Measured Depth ? 3 Vertical Depth ? 4 Horizontal Length (>87 deg) ? 5 Tangent Angle Above Horizontal ? 6 Min Pore Pressure Gradient ? 7 Max Pore Pressure Gradient ? 8 Kick Zone Temperature ? Weak Point Parameters: 9 Measured Depth ? 10 Vertical Depth ? 11 Section Angle (<87 deg) ? 12 Min Fracture Gradient / EMW ? 13 Max Fracture Gradient / EMW 14 Weak Point Temperature ? Other Parameters: 15 Drill Collar OD ? 16 Drill Collar Length ? 17 DrillpipeOD ? 18 Surface Pressure Safety Factor ? 19 Mud Weight in Hole ? (inch) (ft) (ft) (ft) (deg) (PPg) (PPg) (deg. F) (ft) (ft) (deg) (PPg) (PPg) (deg. F) (inch) (ft) (inch) (psi) (PPg) 8.75 ...... 84~3 6768 0 9.800 10.300 150 3410 2862 49 13,000 16,000 lO0 6.75 180 4 100 10.500 Input Error Messages: Non-Horizontal Annular Capacity Around BHA: Annular Capacity Around DP: (bbl/ft) (bbl/ft) 0.03011 0.05883 At Min Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/ft) (ft) (bbl) (ft) (bbl) 271 0.0431 1030 61.2 681 38.8 Comments: At Max Fracture Gradient: Circulating MAASP Gas Gradient at Weak Point For Min Pore Pressure: Max Allowable Gas Height: Kick Tolerance: For Max Pore Pressure: Max Allowable Gas Height: Kick Tolerance: (psi) (psi/ft) (ft) (bbl) (ft) (bbl) 717 0.0534 1959 144.4 1601 113.3 S-110i Kick Tol TKUP Page 2 of 2 ( 6/21/2001 4:52 PM lMinFracture Grad --O--Max Fracture Grad 9.70 9.80 9.90 Pot~.~lf~essure Gtadlient 10.20 10.30 10.40 APPENDIX: Maximum Allowable Gas Influx Volume Based on Casing Burst & Surface Equipment Rating Max Allowable Surface Pressure ? Near Surface Casing ID ? Near Surface Annular Temperature ? Gas Gradient at Max Surface Pres: Near Surface Annular Capacity: At Minimum Pore Pressure Gradient: Max Allowable Gas Height at Surface: Max Allowable Gas Vol. on Shut-in: At Maximum Pore Pressure Gradient: Max Allowable Gas Height at Surface: Max Allowable Gas Vol. on Shut-in: (psi) (inch) (deg. F) (psi/ft) (bbl/ft) 5000 8.83 70 0.103 0.06019 (ft) 11630 (bbl) infinite Comments: Extends to hole TD (ft) 11233 Extends to hole TD (bbl) infinite 9.70 9.80 9.90 Po~.~essure G~lcli~nt 10.20 10.30 10.40 POST THIS NOTICE IN THE DOGHOUSE S-110i Rig site Summary of Drilling Hazards Standard Operating Procedures for H2S precautions should be followed at all times. The highest level of H2S recently measured on S-pad in the last 12 months was on S-40 @ 70 ppm, (January 2001). Well S-102 is located 30' south and S-108 is located 30' north of planned well center. S-102 and S-108 wells both have close approach issues in the surface hole. All wells pass major risk criteria. Nearby well S-102 at 30' center will be as close as 15.65' center-center @ 706' MD. S-108 is as close as 22.40' center-center @ 926' MD. Hydrates have occasionally been encountered at S pad. No other shallow gas has been reported. S-100i and S-101 did not encounter any shallow gas problems. S-102 encountered hydrate shows at 2700', 2850' TVD; however, there were no associated complications. All Aurora S pad wells drilled this year have contained oil at the top of the Ugnu. For this reason 7" casing will be cemented to 500' above the Ugnu Ma sand (the uppermost significant hydrocarbon). Lost circulation while drilling has been experienced while running 7" casing on S-102 and partial losses while drilling S-103. The SSD lost circulation tree should be followed if lost fluid returns are encountered. Continue best practices for well control during drilling operations across Ugnu, Schrader, and Kuparuk formations. Monitor for signs of a kick. Continue best practices for well control during openhole wireline logging operations. Monitor for signs of a kick especially while logging up and POOH. Expect small coal stringers while drilling the Schrader intervals. Take care while back reaming t o avoid mechanical sticking influences. CONSULT THE PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION. S-110i -1500- 1500 3OOO 4500 6O00 75OO REFERENCE INFOI~,~[ ION Co-o~iina~ (N~E) Reference: Well Ceca-e: S-110. Tree No~h Veak~al (TVD} Refereaoe: D-14 70.8ff 70.80 Section (VS) Reference: Sl~ - (O.OON.O.OOE) Measured Deplh Referem~e: D-14 70.80' 70.~0 Cakulafion Method: Mm Cul'~mum SURVEy PROGRAM Depth Fm Depth To Sm'~y,Plan 70.8010~0.00 Phm~d: S-110,.1~07 V I 1 ~00.00 g751.63 Plarmed: S- 110 ,al~O7 V I Tool CB-GYRO-SS M~D- IFR- MS Plan: S-110 ~p07 (S-110/Plan S-II0) Created Ely: Ken Allen lYa~e: 5~ 16/2001 Checked: Date: . . Relier, ed: ..... Date: _ . . FORMATION TOP DETAILS No. TVDPath MDPath Formation I : ";.80 1670.21 SV6 2 -~ -,L80 2059.97 Base Permafrost 3 - '<}.80 2407.83 SV5 4 '::':}.80 2710.43 SV4 5 ' , :).80 3255.10 SV3 6 :-~ ,L80 3497.18 SV2 7 ,' ~.80 4034.29 SVI 8 :' s.80 4548.71 UG4 t 9 .... ~.80 4624.36 UG4A l0 , -~L80 5100.95 UG3 ---- - Start Dir 1°/100': 300' MD, 300'TVD 11 ' - :L80 5902.84 UGI 12 :* ~.80 6403.10 Ma (Top Shrader Bluff) I Start Dir 2°/100': 600' MD, 599.86'TVD 13 -':'-~.80 6682.04 WS2 (N sands) 14 - ,m.80 6814.34 WS1 (O sands) :~ 15 -: :~.80 7132.77 Obfbase 1000 16 -' -.80 7132.77 Top ColvilleMudstone ! - StartDir3°/100': 1150.46'MD, II43.45q'VD 17 :.~ :~.80 8224.44 CMl (ColvilleShalesK-10) 18 : , .80 8301.57 THRZ ' ~ 19 ....'.80 8456.63 BHRZ (Kalubik) _ exr~ 20 ~- % .80 8456.63 Kuparuk D 21 ..... .80 8462.63 TKUP ~ ~X---------EndDir: 1872.11'MD 1796.91'TVD -~,~ . -. on o,~-~ v ..... · 2 ' ,.~.~ -~.ou o,*u~.u.~ txulJo, l u~ ~ ~ ~000 '~ Start Dir 6°/100': 2066.68' MI), 1956.YTVD 23 ~ '~: x.80 8512.63 LCU t~ase rerma~rost ~ End Dir: 2296.68' MD 2127.34' TVD 24 '-'~: :.80 8538.63 Kupamk A 9 5/8" ~x'~2 SV2 6000 ~ Start Dir 4°/100': 6272.32' MD, 4755.01'TVD Shrader Blur0 ~ ......... .~ ~x~ WS2 (IN sarlds) - Start Dir 1.63°/100': 6814.34' MD, 5180.83WD : ._~%~l~ville Mudstone 8OOO : THRZ -,~ : End Dir: 8462.6Y MD, 6768.8' TVD BHRZ (Kalubik/ q .~UP : i 'I'MLV __ :: ~T ID th 1 ..... - ~ .................. -- 7" i om ep : 875 .63' MD, 7057.8' TVD WELL DETAILS Name ~N.:-S =F~-WN~nlhing Eaamg LalitudeLongitude SIol S-II0 -185_44 100737 5980685.00 618930.~O 70':21'21.178N 149'~02'02395. W NA TARGET DETAILS Name FVD ~N~.S-E~-W ~xthin~ Faming Shal~ S-II0 TI6768.80 2190.68 M8021 5982930.46 622374.70 Polyson S-IIOSBOA 5180~0 210635 33493059828.t428 622245.16 Polygtn~ SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec T~get I 70.80 0.00 0.00 70.80 0.00 0.00 0.00 0.00 0.00 2 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 3 600.00 3.00 78.00 599.86 1.63 7.68 1.00 78.00 7.37 4 1150.46 14.00 74.00 !143.45 23.05 86.02 2.00 354.93 85.06 5 1872.11 35.00 60.00 1796.91 152.13 352.33 3.00 337.91 379.19 6 2066.68 35.00 60.00 1956.30 207.93 448.99 0.00 0.00 490.71 7 2296.68 48.63 56.71 2127.34 288.67 578.87 6.00 -10.41 643.65 8 6272.32 48.63 56.71 4755.01 1926.35 3072.68 0.00 0.00 3626.58 9 6814.34 26.95 57.27 5180.80 2106.55 3349.30 4.00 179.31 3956.69 S-Il0 SBOA 10 8462.63 0.08 57.27 6768.80 2312.94 3670.42 1.63 180.00 4338.40 Soil0 TI 11 8601.63 0.08 57.27 6907.80 2313.05 3670.59 0.00 0.00 4338.60 12 8751.63 0.08 57.27 7057.80 2313.17 3670.77 0.00 0.00 4338.82 ANNOTATIONS No. TVD MD Annotation I 300.00 300.00 Start Dh' !°/100': 300' MD, 300~VD 2 599.86 600.00 Start Dir 2°/100': 600' MD, 599.86'rvD 3 1143.44 1150.46 Start Dir 3°/100': 1150.46' MD, 1143.45'TVD 4 1796.91 1872.11 End Dh.: 1872.11'MD, 1796.91'TVD 5 1956.30 2066.68 Start Dh' 6°/100': 2066.68' MD, 1956.YTVD 6 2127.34 2296.68 End Dir: 2296.68' MD, 2127.34' TVD 7 4755.01 6272.32 Start Dir 4°/100': 6272.32' MD, 4755.01'TVD 8 5180.80 6814.34 Start Dh' 1.63°/100': 6814.34' MD, 5180.8'TVD 9 6768.80 8462.63 End Dir: 8462.6Y MD, 6768.8'TVD 10 7057.79 8751.62 Total Depth: 8751.63' MD, 7057.8' TVD CASING DETAILS No. TVD MD Name Size i 2860.80 3406.40 9 5/8" 9.625 2 7057.79 8751.62 7" 7.000 All TVD depths are ssTVD plus 70.8' for RKBE. 0 1500 3000 4500 6000 7500 9000 10500 12000 13500 Vertical Section at 57.78° [ 1500fi/in] COMPANY DETAILS REFERENCE INFORI~LAIION SURVEY PROGRAM Plan: S-I II) wp0? (S-110tPlan §-I I0~ BP Amoco Co-ordinate Ct~'E) Reference: Well Centre: S-110. True Nonh Deplh Fm Depth To Sur~e2,'~Plaa 1ool Created By: Ken Allen Date: 5/16/2001 Veaic~l (IVD) Re~'~eoce: D-14 70.8ff 70.80 Calculation Metlxxt Mininmm Curealure Section (VS} Reference: Slot - (0.00N.0.00E) 70.80 1000.00 Planmd: S-110 v,!~07 VI CB~GYRO-SS Chocked: Date: Error S2,'s~ern: ISCWSA Mea~nu'ed Dep~ Reference: D-1470.80' 70.80 lO00.00 8751.63 Planned: S-l lO v, pOTVI MWD*IFR-MS - ' Scan Melhod: Tray Cylin~r North Calculation Method: M~imum Cun-aaa-e Reviev, ed: _ _ _ [)ale: Error Surface: Ellipfcal: Casing W~,,,;,~ Metlx~ Rules Based ,~pproveo: __._ l~,a~e: FORMATION TOP DETAILS No. TVDPath MDPath Formation I 1625.80 1670.21 SV6 2 1950.80 2059.97 Base Permafrost 3 2200.80 2407.83 SV5 4 2400.80 2710.43 SV4 5 2760.80 3255.10 SV3 6 2920.80 3497.18 SV2 ~72'. _ 250ff 7 3275.80 4034.29 SV1 - All TVD depths are 8 3615 80 4548 71 UG4 ~ ' ' ' · · ! ..... ~ .... - - - 650t~ ' - ~,0 ~9~:g:10° ~16~:~ ~I^ ssTVD plus 70.8 for RKBE. I~60~-~-~,TotalDepth:8751.6yMD.7057-8,T\ -- 11 4510.80 5902.8 UG ..... -[, .-00~1~ 'lq . , 4 I ............. I 5500 EndDir .8462.63' ' 6403.0 : MD, 6768.8 TVD - 13 5065.80 6682.04 WS2 (lq sands) i i 14 5180.80 6814.34 WSI (Osands) i : 15000'. ~/ '?, I ' _ 15 5470.80 7132.77 Obfbase ~ : I ~-; |l VD 16 5470.80 7132 77 Top Colville Mudstone i : - 1 !272 32 MD 47 5 01'TVD [ ~'~'"~"' '/'start Dir !.63°1100': 6814.34' MD, 5180.8q' .,,~,, 17 6530 80 8224.44 CMl (Colville Shales K-10) i Start Dir 4° 100': 6 . ' , 5 . ~- '.~';',' __ ~|_ _ z.w~u 18 6607.80 8301.57 THRZ ! 19 6762.80 8456.63 BI-tRZ (Kalubik) i i ' - - 20 6762.80 8456.63 KupamkD '--- F ............ ~ ......... ~ .... ~ ............. 4500 ~ 95% conf. ' 21 6768.80 8462.63 TKUP ! ; - 22 6768.80 8462.63 Kupamk C ..... ~ -: -- ~ - - ~ ........ ~ ...... ~ -- 23 6818.80 8512.63 LCU ; - 24 6844.80 8538.63 Kuparuk A i ~ .. 25 6907.80 8601.63 TMLV i i - · : 4000 ~ _ ___ .__________ _ - ~/' I 2860.80 3406.40 9 5/8" 9.625 I000-- i } 3000 8751.62 7" 7.000 ......... } ...... ..... ~'o2-o2a95w _ } 2 500-- ! sas ~ob'so, ' ........ i .... ---_-----::5: ........ i ......... . .......... i; ..... .... StartDtr6 100 206668 MD 19563TVD - 1500 TFace VSec Target 1000 - 506 0.00 0.00 i 0.00 0.00 i :~. - , - ~ } 3 600.00 3.00 78.00 599.86 1.63 7.68 1.00 78.00 7.37 0- :\ StartDir2O/100':600'MD, 599.86'TVD :. 4 1150.46 14.00 74.00 1143.45 23.05 86.02 2.00 354.93 85.06 ...... ?_ Star~DirlO/100,.: 300, MD,,30tYrvi~ ..... ~ ......... ~ .... 5 1872.11 35.00 60.00 1796.91 152.13 352.33 3.00 337.91 379.19 6 2066.68 35.00 60.00 1956.30 207.93 448.99 0.00 0.00 490.71 : 7 2296.68 48.63 56.71 2127.34 288.67 578.87 6.00 -10.41 643.65 ..... ~ ........ ~ ........ ~ .... ~ · 8 6272.32 48.63 56.71 4755.01 1926.35 3072.68 0.00 0.00 3626.58 : 9 6814.34 26.95 57.27 5180.80 2106.55 3349.30 4.00 179.31 3956.69 S-II0 SB OA 10 8462.63 0.08 57.27 6768.80 2312.94 3670.42 1.63 180.00 4338.40 S-II0 TI 11 8601.63 0.08 57.27 6907.80 2313.05 3670.59 0.00 0.00 4338.60 : i 12 8751.63 0.08 57.27 7057,80 2313.17 3670.77 0.00 0.00 4338.82 -5oo ' ' ' I .... i .... I .... I .... I .... I .... I .... 0 500 1000 1500 2000 2500 3000 3500 4000 4500 West(-)/East(+) [500fi/in] ., BP Amoco Planning Report- Geographic Company: BP Amoco Date: 511612001 Time: 16:54:05 Page: Field: Prudhoe Bay COOrdinate(NE) Reference: Well: S-110, True North Site: PBS Pad Verlkal (TVD) Reference: D-14 70.80' 70.8 Well: S-110 Section (VS) Reference: Well (0.00N,0.00E,57.78Azi) Weilpath: Plan S-110 Plan: S-110 wp07 'Field': North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: BGGM2000 Site: PBS Pad TR-12-12 UNITED STATES · North Slope Site Position: Northing: 5980854.54 ft Latitude: 70 21 23.002 N From: Map Easting: 617919.92 ft Longitude: 149 2 32.343 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.90 deg Well: S-110 Slot Name: Surface Position: +N/-S -185.44 ft Northlng: 5980685.00 ft Latitude: 70 21 21.178 N +E/-W 1007.37 ft Easting: 618930.00 ft Longitude: 149 2 2.895 W Position Uncertainty: 0.00 ft Reference Point: +N/-S -185.44 ft Northing: 5980685.00 ft Latitude: 70 21 21.178 N +E/-W 1007.37 ft Easting: 618930.00 ff Longitude: 149 2 2.895 W Measured Depth: 70.80 ff Inclination: 0.00 deg VerticaIDepth: 70.80 ff Azimuth: 0.00 deg Weiip~[h: .... Plan S-110 Drilled From: Well Ref. Point Tie-on Depth: 0.00 ft Current Datum: D-14 70.80' Height 70.80 ft Above System Datum: Mean Sea Level Magnetic Data: 3/22/2001 Declination: 26.56 de9 Field Strength: 57463 nT Mag Dip Angle: 80.78 de9 Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ff ff ff deg 0.00 0.00 0.00 57.78 Plan: S-110 wp07 Date Composed: 5/16/2001 Version: 1 Principal: Yes Tied-to: From Well Ref. Point Plan Section Information 70.80 0.00 0.00 70,80 0.00 0.00 0.00 0.00 0.00 0.00 300.00 0.00 0.00 300.00 0.00 0.00 0.00 0.00 0.00 0,00 600.00 3.00 78.00 599.86 1.63 7.68 1.00 1.00 0.00 78.00 1150.46 14.00 74.00 1143.45 23.05 86,02 2.00 2.00 -0.73 354.93 1872.11 35.00 60.00 1796.91 152.13 352.33 3.00 2.91 -1.94 337.91 2066.68 35.00 60.00 1956.30 207.93 448.99 0.00 0.00 0.00 0.00 2296.68 48.63 56.71 2127.34 288.67 578,87 6.00 5.93 -1.43 -10.41 6272.32 48.63 56.71 4755.01 1926.35 3072.68 0.00 0.00 0.00 0.00 6814.34 26,95 57.27 5180.80 2106.55 3349.30 4.00 -4.00 0.10 179.31 8462.63 0.08 57.27 6768.80 2312.94 3670.42 1.63 -1.63 0.00 180.00 8601.63 0.08 57.27 6907.80 2313.05 3670.59 0.00 0.00 0.00 0.00 8751.63 0.08 57.27 7057.80 2313.17 3670.77 0.00 0.00 0.00 0.00 S-110 SB OA S-110 T1 Section 1 : Start ft ==: :"::deg = deg,: : : ......... ~'6':'i/~ 0:~'~'~':~ ....................... ~'~'¢ ....................... -6':~;0- ................ /~:'~ ..................... ~:6'~ ............... ~7~' ............. ~:'~'~ .............. '~:~ ................... -~:~ '1 100.00 0.00 0.00 100.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 200.00 0.00 0.00 200.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 ..... 3?0:?? ?:07 ................ ?:.07 300:0? 0.'.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 511612001 Time: 16:54:05 Page: 2 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: S-110, True North Site: PBS Pad Vertical (TVD) Reference: D-14 70.80' 70.8 Well: S-110 Section (VS) Reference: Well (0.00N,0.00E,57.78Azi) . _we!!_P. ?th!__ ?!a_ n_. _S.-. 1_1_o_ .................................................................. ~!_a ?_: .............................. S_..-!.10_ _w. P0_7. Section 2: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO .......... .................. ........ .................. .................... _._ ............ ............. ......... ......... 400.00 1.00 78.00 399.99 0.18 0.85 0.82 1.00 1.00 0.00 0.00 500.00 2.00 78.00 499.96 0.73 3.41 3.28 1.00 1.00 0.00 0.00 'L__ 600.00 3.00 78.00 599.86 1.63 7.68 7.37 1.00 1.00 0.00 0.00 Section 3: Start MD Inel Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft deg/100ft degll00ft deg .................................................................................................... ._. ...................................................... _.. .................. .. ........................................ -_ 700.00 5.00 75.97 699.61 3.23 14.46 13.96 2.00 2.00 -2.03 -5.07 800.00 6.99 75.10 799.06 5.85 24.57 23.91 2.00 2.00 -0.87 -3.04 900.00 8.99 74.61 898.08 9.49 37.99 37.20 2.00 2.00 -0.49 -2.18 1000.00 10.99 74.30 996.56 14.14 54.70 53.82 2.00 2.00 -0.31 -1.70 1100.00 12.99 74.09 1094.37 19.81 74.69 73.75 2.00 2.00 -0.22 -1.39 1150.46 14.00 74.00 1143.45 23.05 86.02 85.07 2.00 2.00 -0.17 -1.18 Section 4: Start , :: deg';:' : i ' fi:,: ::'=i:ft i:... :degl'lOOff.:degllOOff'deg/:lOOft deg 1300.00 18.23 68.61 1287.09 36.58 125.21 125.43 3.00 2.85 -3.29 -20.05 1400.00 21.12 66.19 1381.24 49.56 156.27 158.63 3.00 2.89 -2.42 -16.90 1500.00 24.04 64.33 1473.57 65.66 191.11 196.70 3.00 2.91 -1.86 -14.62 1600.00 26.97 62.85 1563.82 84.84 229.65 239.52 3.00 2.93 -1.48 -12.91 1700.00 29.91 61.64 1651.74 107.03 271.78 287.00 3.00 2.94 -1.21 -11.57 1800.00 32.87 60.63 1737.09 132.19 317.38 338.99 3.00 2.95 -1.01 -10.51 1872.11 35.00 60.00 1796.91 152.13 352.33 379.19 3.00 2.96 -0.88 -9.69 Section 5: Start 1900.00 35.00 60.00 1819.76 160.13 366.18 395.18 0.00 0.00 0.00 0.00 2000.00 35.00 60.00 1901.67 188.81 415.86 452.49 0.00 0.00 0.00 0.00 2066.68 35.00 60.00 1956.30 207.93 448.99 490.72 0.00 0.00 0.00 0.00 Section 6: Start Section 7: Start "? .......... ~ ~':~:' ~'i 7' := 'i;;-C'i:~iiT !'i='- '-'~i;;; 'i'~ 'i~i i-~,' '!-~ ~'~;'~' ~: "::'~i¥:i ~;~'!:i '~iT':-~-~-~' .............. ;~ ..................... i~L-~ ....... ~i~;;'ii-~ ............. -~';;';;; ......... "'"'-~i~ ............................................................ 2300.00 48.63 56.71 2129.53 290.04 580.95 646.14 0.00 0.00 0.00 0.00 2400.00 48.63 56.71 2195.63 331.23 643.68 721.17 0.00 0.00 0.00 0.00 2500.00 48.63 56.71 2261.72 372.42 706.41 796.20 0.00 0.00 0.00 0.00 2600.00 48.63 56.71 2327.81 413.61 769.15 871.23 0.00 0.00 0.00 0.00 2700.00 48.63 56.71 2393.90 454.80 831.88 946.27 0.00 0.00 0.00 0.00 2800.00 48.63 56.71 2459.99 495.99 894.61 1021.30 0.00 0.00 0.00 0.00 2900.00 48.63 56.71 2526.09 537.18 957.34 1096.33 0.00 0.00 0.00 0.00 3000.00 48.63 56.71 2592.18 578.37 1020.07 1171.36 0.00 0.00 0.00 0.00 3100.00 48.63 56.71 2658.27 619.56 1082.80 1246.40 0.00 0.00 0.00 0,00 3200.00 48.63 56.71 2724.36 660.76 1145.53 1321.43 0.00 0.00 0.00 0.00 3300,00 48.63 56.71 2790.45 701.95 1208.26 1396.46 0.00 0.00 0.00 0.00 3400.00 48.63 56.71 2856.55 743.14 1270.99 1471.49 0.00 0.00 0.00 0.00 3500.00 48.63 56.71 2922.64 784.33 1333.72 1546.53 0.00 0.00 0.00 0.00 3600.00 48.63 56.71 2988.73 825.52 1396.46 1621.56 0.00 0.00 0.00 0.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 5/1612001 Time: 16:54:05 Page: 3 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: S-110, True North Site: PBS Pad Vertical (TVD) Reference: D-14 70.80' 70.8 Well: S-110 Section (VS) Reference: Well (0.00N,0.00E,57.78Azi) ~!!.._:.~!.._._.P.!_a_"__s_:!..~_o_ .................................................................. ~?.-'_ ............................... S_-_~__! _o_~_o~ ......................................................... Section 7: Start MD lncl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ff deg deg ft ft ft ft degll00ft deg/100ff degll00ft deg 3700.00 48.63 56.71 3054.82 866.71 1459.19 1696.59 0.00 0.00 0.00 0.00 3800.00 48.63 56.71 3120.91 907.90 1521.92 1771.62 0.00 0.00 0.00 0.00 3900.00 48.63 56.71 3187.00 949.09 1584.65 1846.66 0.00 0.00 0.00 0.00 4000.00 48.63 56.71 3253.10 990.28 1647.38 1921.69 0.00 0.00 0.00 0.00 4100.00 48.63 56.71 3319.19 1031.47 1710.11 1996.72 0.00 0.00 0.00 0.00 4200.00 48.63 56.71 3385.28 1072.66 1772.84 2071.75 0.00 0.00 0.00 0.00 4300.00 48.63 56.71 3451.37 1113.85 1835.57 2146.79 0.00 0.00 0.00 0.00 4400.00 48.63 56.71 3517.46 1155.05 1898.30 2221.82 0.00 0.00 0.00 0.00 4500,00 48.63 56.71 3583.56 1196.24 1961.03 2296.85 0.00 0.00 0.00 0.00 4600.00 48.63 56.71 3649.65 1237.43 2023.76 2371.88 0.00 0.00 0.00 0.00 4700.00 48,63 56.71 3715.74 1278.62 2086.50 2446.92 0.00 0.00 0.00 0.00 4800.00 48.63 56.71 3781.83 1319.81 2149.23 2521.95 0.00 0.00 0.00 0.00 4900.00 48.63 56.71 3847.92 1361.00 2211.96 2596.98 0.00 0.00 0.00 0.00 5000.00 48,63 56.71 3914.02 1402.19 2274.69 2672.01 0.00 0.00 0.00 0.00 5100.00 48.63 56.71 3980.11 1443.38 2337.42 2747.05 0.00 0.00 0.00 0.00 5200.00 48.63 56.~1 4046.20 1464.57 2400.15 2822.08 0.00 0.00 0.00 0.00 5300.00 48.63 56.71 4112,29 1525.76 2462.88 2897.11 0.00 0.00 0.00 0.00 5400.00 48.63 56.71 4178.38 1566.95 2525.61 2972.14 0.00 0.00 0.00 0.00 5500.00 48.63 56.71 4244.48 1608.15 2588.34 3047.18 0.00 0.00 0.00 0.00 5600.00 48.63 56.71 4310.57 1649.34 2651.07 3122.21 0.00 0.00 0.00 0.00 5700.00 48.63 56.71 4376.66 1690.53 2713.81 3197.24 0.00 0.00 0.00 0.00 5800.00 48.63 56.71 4442.75 1731.72 2776.54 3272.27 0.00 0.00 0.00 0.00 5900.00 48.63 56.71 4508.84 1772.91 2839.27 3347.31 0.00 0.00 0.00 0.00 6000.00 48.63 56.71 4574.93 1814.10 2902,00 3422.34 0.00 0.00 0,00 0.00 6100,00 48.63 56.71 4641.03 1855.29 2964.73 3497.37 0.00 0.00 0.00 0.00 6200.00 48.63 56.71 4707.12 1896.48 3027.46 3572.40 0.00 0.00 0.00 0.00 6272.32 48.63 56.71 4755.01 1926.35 3072.68 3626.58 0.00 0.00 0.00 0.00 Section 8: Start 6300.00 47.52 56.73 4773.50 1937.65 3089.90 3647.18 4.00 -4.00 0.07 179.31 6400.00 43.52 56.80 4643.55 1976.75 3149.56 3718,50 4.00 -4.00 0.07 179.30 6500.00 39.52 56.88 4918.41 2013.01 3205.05 3784.77 4.00 -4,00 0.08 179.25 6600.00 35.52 56.98 4997.70 2046.24 3256.08 3845.66 4.00 -4.00 0.10 179.19 6700.00 31.52 57,10 5081.05 2076,28 3302.41 3900,88 4.00 -4.00 0.12 179.11 6800.00 27.53 57.25 5168.04 2103.00 3343.81 3950.14 4.00 -4,00 0.15 179.01 6814,34 26,95 57.27 5180.80 2106.55 3349.30 3956.68 4.01 -4.01 0.16 178.99 Section 9: Start 6900.00 25.55 57.27 5257.62 2127.04 3381.17 3994.57 1.63 -1.63 0.00 180.00 7000,00 23,92 57.27 5348.44 2149.66 3416.38 4036.42 1,63 -1.63 0.00 180.00 7100.00 22.29 57,27 5440.42 2170.88 3449.39 4075.66 1.63 -1.63 0.00 180.00 7200.00 20.66 57.27 5533.47 2190.68 3480.19 4112.27 1.63 -1.63 0.00 180.00 7300.00 19.03 57.27 5627.52 2209.04 3508.75 4146.23 1.63 -1.63 0.00 180.00 7400.00 17.40 57.27 5722.51 2225.94 3535.05 4177.49 1.63 -1.63 0.00 180.00 7500.00 15.77 57.27 5818.34 2241.37 3559,07 4206.04 1.63 -1.63 0.00 180.00 7600.00 14.14 57.27 5914.95 2255.33 3580,78 4231.85 1.63 -1.63 0.00 180.00 7700.00 12.51 57.27 6012.25 2267.79 3600.18 4254.90 1.63 -1.63 0,00 180.00 7800.00 10.88 57.27 6110.17 2278.76 3617,23 4275.17 1.63 -1.63 0.00 180.00 7900.00 9.25 57.27 6208.63 2288.21 3631.94 4292.65 1.63 -1.63 0.00 180.00 8000.00 7.62 57.27 6307.54 2296.14 3644.28 4307.33 1.63 -1.63 0.00 180.00 8100,00 5.99 57.27 6406.83 2302.55 3654.26 4319.18 1.63 -1.63 0.00 180.00 8200.00 4.36 57.27 6506.42 2307.43 3661.85 4328.21 1.63 -1.63 0.00 180.00 8300.00 2.73 57.27 6606.23 2310.78 3667.06 4334.40 1.63 -1.63 0.00 180.00 8400.00 1.10 57.27 6706.17 2312.59 3669.87 4337.75 1.63 -1.63 0.00 180.00 8462.63 0.08 57.27 6768.80 2312.94 3670.42 4338.40 1.63 -1.63 0.00 -180.00 BP Amoco Planning Report - Geographic Company: BP Amoco Date: 511612001 Time: 16:54:05 Page: 4 Field: Prudhoe Bay Ce-erdinate(NE) Reference: Well: S-110, Tree North Site: PBS Pad Veylteal ~TVD) Reference: D-14 70.80' 70,8 Well: S-110 Section (VS) Reference: Well (0.00N,0.00E,57.78Azi) Wellpatb: Plan S-110 Plan: S-110 wp07 Section 10: Start MD Incl Azim T~D +N/-S +E/-W VS DLS Build Turn TFO ft deg deg ft ft ft ft deg/100ft degll00ft deg/100ft deg ....... ............ ....... ........ .... .... ............ ...... ............ ................ 8601.63 0.08 57.27 6907.80 2313.05 3670.59 4338.60 0.00 0.00 0.00 0.00 Section 11 : Start ...... MD Incl Azim TVD +N/-S +E/-W VS DLS Build Turn TFO ff deg deg ff ff ft ft deg/100ff deg/100ft deg/100ft deg . 875!.63 ........ 0:~8 .... 57:27 70_57'8_0 ....... 23_!.3:~!.~7_ ........ 3.6~0:,7_7 ......... ~33..8:8.! ............. O.:0__0 ....... _.0_._0_.0_ .......... _0_.?_0 .............. _0;.0~ Survey Map Map <--- Latitude -->, <-- Longitude --> , , MD Incl Azim TVD +NI-S . +El-W,, ,: Northing Easting:, Deg Mln Sec Deg Min Sec 70.80 0.00 0.00 70.80 0.00 0.00 5980685.00 618930.00 70 21 21,178 N 149 2 2,895 W 100.00 0.00 0.00 100.00 0.00 0.00 5980685.00 618930.00 70 21 21.178 N 149 2 2,895 W 200.00 0.00 0.00 200.00 0.00 0.00 5980685.00 618930.00 70 21 21,178 N 149 2 2,895 W 300.00 0.00 0.00 300.00 0.00 0.00 5980685.00 618930.00 70 21 21.178 N 149 2 2.895 W 400.00 1.00 78.00 399.99 0.18 0.85 5980685.19 618930.85 70 21 21.180 N 149 2 2.870 W 500.00 2.00 78.00 499.96 0.73 3.41 5980685.78 618933.40 70 21 21.185 N 149 2 2.796 W 600.00 3.00 78.00 599,86 1.63 7.68 5980686.75 618937.65 70 21 21.194 N 149 2 2,671 W 700.00 5.00 75.97 699.61 3.23 14.46 5980688.46 618944.41 70 21 21.210 N 149 2 2,473 W 800.00 6.99 75.10 799.06 5.85 24.57 5980691.24 618954.47 70 21 21.236 N 149 2 2.177 W 900.00 8.99 74.61 898.08 9.49 37.99 5980695.09 618967.83 70 21 21,271 N 149 2 1,785 W 1000.00 10.99 74.30 996.56 14.14 54.70 5980700.01 618984.47 70 21 21.317 N 149 2 1.296W 1100.00 12.99 74.09 1094.37 19.81 74.69 5980705.99 619004.36 70 21 21,373 N 149 2 0.712W 1150.46 14.00 74.00 1143.45 23.05 86.02 5980709.41 619015,64 70 21 21,405 N 149 2 0,381 W 1200.00 15.39 71.89 1191.37 26.74 98.03 5980713.30 619027.58 70 21 21,441 N 149 2 0.030W 1300.00 18.23 68.61 1287.09 36.58 125.21 5980723.56 619054.60 70 21 21,538 N 149 1 59.235W 1400.00 21.12 66.19 1381.24 49.56 156.27 5980737.03 619085.45 70 21 21,666 N 149 1 58.327W 1500.00 24.04 64.33 1473.57 65.66 191.11 5980753.68 619120.03 70 21 21,824 N 149 1 57,309W 1600.00 26.97 62.85 1563.82 84.84 229.65 5980773.47 619158.26 70 21 22.012 N 149 1 56.182W 1700.00 29.91 61.64 1651.74 107.03 271.78 5980796.33 619200.02 70 21 22,231 N 149 I 54,951 W 1800.00 32.87 60.63 1737.09 132.19 317.38 5980822.20 619245.21 70 21 22,478 N 149 1 53.617W 1872.11 35.00 60.00 1796.91 152.13 352.33 5980842.69 619279.84 70 21 22,674 N 149 1 52.596W 1900.00 35.00 60.00 1819.76 160.13 366.18 5980850.91 619293.56 70 21 22,753 N 149 1 52.191W 2000.00 35.00 60.00 1901.67 188.81 415.86 5980880.37 619342.77 70 21 23.035 N 149 I 50.739W 2066.68 35.00 60.00 1956.30 207.93 448.99 5980900.01 619375.59 70 21 23,223 N 149 1 49,770W 2100.00 36.97 59.40 1983.26 217.81 465,89 5980910.16 619392.34 70 21 23.320 N 149 1 49,276W 2150.00 39.93 58.59 2022.42 233.83 492.53 5980926.60 619418.72 70 21 23.478 N 149 1 48.497W 2200.00 42.89 57.88 2059.91 251.24 520.64 5980944.45 619446.55 70 21 23.649 N 149 1 47.675W 2250.00 45.86 57.25 2095.65 269.99 550.15 5980963.67 619475.75 70 21 23.833 N 149 1 46,813W 2296.68 48.63 56.71 2127.34 288.67 578.87 5980982.80 619504.17 70 21 24.017 N 149 I 45,973W 2300.00 48.63 56.71 2129.53 290.04 580.95 5980984.20 619506.23 70 21 24.030 N 149 1 45.912W 2400.00 48.63 56.71 2195.63 331.23 643.68 5981026.38 619568.29 70 21 24.435 N 149 I 44.078W 2500.00 48.63 56.71 2261.72 372.42 706.41 5981068.56 619630.35 70 21 24,840 N 149 1 42,244W 2600.00 48.63 56.71 2327.81 413.61 769.15 5981110.73 619692.42 70 21 25,246 N 149 1 40,410W 2700.00 48.63 56.71 2393.90 454.80 831.88 5981152.91 619754.48 70 21 25.651 N 149 1 38.576W 2800.00 48.63 56.71 2459.99 495.99 894.61 5981195.09 619816.55 70 21 26.056 N 149 1 36,742W 2900.00 48.63 56.71 2526.09 537.18 957.34 5981237.27 619878.61 70 21 26,461 N 149 1 34.908W 3000.00 48.63 56.71 2592.18 578.37 1020.07 5981279.45 619940.67 70 21 26,866 N 149 1 33,074W 3100.00 48.63 56.71 2658.27 619.56 1082.80 5981321.62 620002,74 70 21 27,271 N 149 1 31,240W 3200.00 48.63 56.71 2724.36 660.76 1145.53 5981363.80 620064.80 70 21 27.676 N 149 I 29.406W 3300.00 48.63 56.71 2790.45 701.95 1208,26 5981405.98 620126.87 70 21 28,081 N 149 I 27.572W 3400.00 48.63 56.71 2856.55 743.14 1270.99 5981448.16 620188.93 70 21 28.486 N 149 1 25.737W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 511612001 Time: 16:54:05 Page: Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: S-110, True North Site: PBS Pad Vertical (TVD) Reference: D-14 70.80' 70.8 Well: S-110 Section (~S) Reference: Well (0.OON,0.00E,57.78Azi) . .W_e!i?"~.h~. _ ..P?? ? !_0_ .................................................................. ??.?.! ................................. ?:_1. ~.0._~?.? Survey Map Map <-- Latitude ---> <--- Longitude ---> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ft deg deg ff ff ff ff ff 3500.00 48.63 56.71 2922.64 784.33 1333.72 5981490.34 620250.99 70 21 28.891 N 149 1 23.903 W 3900.00 48.63 56.71 3187.00 949.09 1584.65 5981659.05 620499.25 70 21 30.511 N 149 1 16.566 W 4000.00 48.63 56.71 3253.10 990.28 1647.38 5981701.23 620561.31 70 21 30.916 N 149 1 14.732 W 4100.00 48.63 56.71 3319.19 1031.47 1710.11 5981743.40 620623.38 70 21 31,321 N 149 1 12.898 W 4200.00 48.63 56.71 3385.28 1072.66 1772.84 5981785.58 620685,44 70 21 31.726 N 149 1 11.063 W 4300.00 48.63 56.71 3451.37 1113.85 1835.57 5981827.76 620747.50 70 21 32.131 N 149 1 9.229 W 4400.00 48.63 56.71 3517.46 1155,05 1898.30 5981869.94 620809.57 70 21 32,535 N 149 1 7.395 W 4500.00 48.63 56.71 3583.56 1196.24 1961.03 5981912,12 620871.63 70 21 32.940 N 149 1 5.560 W 4600.00 48.63 56.71 3549.65 1237.43 2023.76 5981954,29 620933.70 70 21 33.345 N 149 1 3,726 W 4700.00 48.63 56.71 3715.74 1278.62 2086.50 5981996.47 620995.76 70 21 33.750 N 149 1 1.891 W 4800.00 48.63 56.71 3781.83 1319.81 2149.23 5982038.65 621057.82 70 21 34,155 N 149 1 0.057 W 4900.00 48.63 56.71 3847.92 1361.00 2211.96 5982080.83 621119.89 70 21 34,560 N 149 0 58.223W 5000.00 48.63 56.71 3914.02 1402.19 2274.69 5982123.01 621181.95 70 21 34,965 N 149 0 56,388W 5100.00 48.63 56.71 3980.11 1443.38 2337,42 5982165.18 621244.02 70 21 35.370 N 149 0 54.554W 5200.00 48.63 56.71 4046.20 1484.57 2400.15 5982207.36 621306.08 70 21 35.775 N 149 0 52.719W 5300,00 48.63 56.71 4112.29 1525.76 2462.88 5982249.54 621368.14 70 21 36,180 N 149 0 50,884W 5400.00 48.63 56.71 4178.38 1566.95 2525.61 5982291.72 621430.21 70 21 36,585 N 149 0 49.050W 5500,00 48.63 56,71 4244.48 1608.15 2588.34 5982333.90 621492.27 70 21 36.990 N 149 0 47,215W 5600.00 48.63 56.71 4310.57 1649.34 2651.07 5982376.08 621554.33 70 21 37.394 N 149 0 45.381 W 5700.00 48.63 56.71 4376.66 1690,53 2713.81 5982418.25 621616,40 70 21 37,799 N 149 0 43.546W 5800.00 48.63 56.71 4442.75 1731.72 2776.54 5982460.43 621678.46 70 21 38,204 N 149 0 41,711 W 5900.00 48.63 56.71 4508.84 1772.91 2839.27 5982502.61 621740.53 70 21 38.609 N 149 0 39.877W 6000.00 48.63 56.71 4574.93 1814.10 2902.00 5982544.79 621802.59 70 21 39.014 N 149 0 38.042W 6100.00 48.63 56.71 4641,03 1855.29 2964.73 5982586.97 621864.65 70 21 39.419 N 149 0 36.207W 6200,00 48.63 56.71 4707.12 1896.48 3027.46 5982629,14 621926.72 70 21 39.824 N 149 0 34.373W 6272.32 48,63 56.71 4755.01 1926.35 3072.68 5982659.72 621971.45 70 21 40.117 N 149 0 33.050W 6300.00 47.52 56.73 4773.50 1937.65 3089.90 5982671.30 621988.49 70 21 40.228 N 149 0 32.546W 6400.00 43.52 56.80 4843.55 1976.75 3149.56 5982711.34 622047.52 70 21 40.613 N 149 0 30,801 W 6500.00 39.52 56.88 4918.41 2013.01 3205.05 5982748.46 622102.42 70 21 40.969 N 149 0 29.178W 6600,00 35.52 56.98 4997.70 2046.24 3256.08 5982782.50 622152.91 70 21 41.296 N 149 0 27.686W 6700.00 31.52 57.10 5081.05 2076.28 3302,41 5982813.27 622198.75 70 21 41,591N 149 0 26.331W 6800.00 27.53 57.25 5168.04 2103.00 3343.81 5982840.64 622239.72 70 21 41,853 N 149 0 25.120W 6814,34 26.95 57.27 5180.80 2106,55 3349,30 5982844.28 622245.16 70 21 41,888 N 149 0 24.959W 6900.00 25.55 57.27 5257,62 2127.04 3381.17 5982865.26 622276.70 70 21 42,090 N 149 0 24.027W 7000.00 23.92 57.27 5348.44 2149.66 3416.38 5982888.44 622311.53 70 21 42.312 N 149 0 22.997W 7100.00 22.29 57.27 5440.42 2170.88 3449.39 5982910.18 622344.20 70 21 42.521 N 149 0 22.032W 7200.00 20.66 57.27 5533.47 2190.68 3480.19 5982930.46 622374.68 70 21 42,715 N 149 0 21,131 W 7300.00 19.03 57.27 5627.52 2209.04 3508.75 5982949.27 622402.95 70 21 42.896 N 149 0 20.295W 7400.00 17.40 57.27 5722.51 2225.94 3535,05 5982966.59 622428.97 70 21 43.062 N 149 0 19,526W 7500.00 15.77 57.27 5818.34 2241.37 3559.07 5982982.40 622452.74 70 21 43.213 N 149 0 18,824W 7600.00 14.14 57.27 5914.95 2255.33 3580.78 5982996.70 622474.23 70 21 43,351 N 149 0 18,188W 7700.00 12.51 57.27 6012,25 2267.79 3600.18 5983009.47 622493.42 70 21 43.473 N 149 0 17,621 W 7800,00 10.88 57.27 6110.17 2278,76 3617.23 5983020.70 622510.30 70 21 43.581 N 149 0 17.122W 7900.00 9,25 57.27 6208,63 2288.21 3631.94 5983030.39 622524.85 70 21 43,674 N 149 0 16,692W 8000.00 7.62 57.27 6307.54 2296.14 3644.28 5983038.51 622537.07 70 21 43,752 N 149 0 16.331 W 8100.00 5.99 57.27 6406.83 2302.55 3654.26 5983045.08 622546.94 70 21 43.815 N 149 0 16.039W 8200.00 4.36 57.27 6506.42 2307,43 3661.85 5983050.08 622554.45 70 21 43.863 N 149 0 15.817W 8300.00 2.73 57.27 6606.23 2310.78 3667.06 5983053.51 622559.60 70 21 43.895 N 149 0 15,665W 8400.00 1.10 57.27 6706.17 2312.59 3669.87 5983055.36 622562.39 70 21 43.913 N 149 0 15.583W 8462.63 0.08 57.27 6768.80 2312.94 3670.42 5983055.72 622562.93 70 21 43.917 N 149 0 15.567W 3600.00 48.63 56.71 2988.73 825.52 1396.46 5981532.51 620313.06 70 21 29.296 N 149 1 22,069W 3700.00 48.63 56.71 3054.82 866.71 1459.19 5981574.69 620375.12 70 21 29.701 N 149 1 20,235W 3800.00 48.63 56.71 3120.91 907.90 1521.92 5981616.87 620437.18 70 21 30.106 N 149 1 18.401 W BP Amoco Planning Report - Geographic Company: BP Amoco Date: 5/16/2001 Time: 16:54:05 Page: 6 Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: S-110, True North Site: PBS Pad Vertical (TVD) Reference: D-14 70.80' 70.8 Well: S-110 Section (VS) Reference: Well (0.00N,0.00E,57.78Azi) Wellpath: Plan S-110 Plan: S-110 wp07 Survey Map Map <-- Latitude ---> <-- Longitude --> MD Incl Azim TVD +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec ff deg deg ff ff ff ff ff 8500.00 0.08 57.27 6806.17 2312.97 3670.46 5983055.75 622562.98 70 21 43.917 N 149 0 15.565 W 8601.63 0.08 57.27 6907.80 2313.05 3670.59 5983055.83 622563.10 70 21 43.918 N 149 0 15.562 W 8700.00 0.08 57.27 7006.17 2313.12 3670.71 5983055.91 622563.21 70 21 43.919 N 149 0 15.558 W 8751.63 0.08 57.27 7057.80 2313.17 3670.77 5983055.96 622563.28 70 21 43.919 N 149 0 15.556 W H191151 DATE ! CHECK NO. ~01~1151 ....... AL,~SI~AO ILA OO DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET )&OlO1 C½0&OlOl~ 100..00 100. O0 PYMT COMMENTS: PERffIIT TO DRILL FEE HANDLINO INST: S/H - TERRIE HUBELE X4628 A'FI'ACHEP CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. ~11 ~] ~_~ ~ ] 100_ OO 1 OO., OO ,BP ExPLORATI! P.O.. BOX '196612 ANCHORAGE:, )AY" Fo The ]RDER 0~ ..:i:: ::?' :i!i."~!}': .... ~F~'D~R-hSUITE' · FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAl' CITY BANK CI' EVELAND, OHIO 56.389 ******************************************** coN's~LID~{~ED cOMMERci'AL ACCOUNT 00191151 OIL AND OAS 'i':: "i":i!)'i2 ','" ",'.,~i3{' NOT'~AEiD'AFTEI{"i:~ODAYS C:OMM I SS I ON i,!.::::.~ .,: ..... ~E'~"~E '? .... '~MOUNT $100..':00::,' , . ;. . TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~'~-- \ \ '~ CHECK 1 CHECK WHAT APPLIES STANDARD LETTER DEVELOPMENT DEVELOPMENT REDRILL EXPLORATION INJECTION WELL INJECTION WELL REDRILL ADD-ONS (OPTIONS) MULTI LATERAL (If api number last two (2) digits are between 60-69) PILOT HOLE (PH) ANNULAR D~SPOSAL ~_)NO ANNULAR DISPOSAL ( ) YES ANNULAR DISPOSAL THIS WELL DISPOSAL INTO OTHER ANNULUS (, )YEs+ SPACING EXCEPTION "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 AP1 number stated above. In accordance with 20 AAC 25.005(0, 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 has not been requested... Annular Disposal of drilling wastes will not be approved... Annular Disposal of drilling wastes will not be approved... Please note that an disposal of fluids generated... 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. (Company Name} will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST' COMPANY z~ WELL NAME/~z~'~¢' ~'-/z*,~ PROGRAM: exp dev ~ reddl serv wellbore seg ann. disposal para req FIELD & POOL -~'G/c:)/~_..~ INIT CLASS ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available, in drilling unit ............ 8. If deviated, is wellbore plat included ............. ... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can.be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 27. 28. 29. GEOLAREA ¥~ ¥ ~ YN ¥ N GEOLOGY 30. 31 32. .~'R D TE 33. ANNULAR DISPOSAL35. APPR DATE GEOLOGY: UNIT# ~/--~_, ~'~ . ON/OFF SHORE Conductor string provided .................... ~~~N~ Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ CMT will cover all known productive horizons. ' Casing designs adequate for C, T, a & permafrost ....... ~-~ Adequate tankage or reserve pit ................. ~"'~ N ~'(-~%~'\~,,~ ~'~c_ hr.., ~'~._~ If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ....... ; ...... If diverter required, does it meet regulations .......... Drilling .fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ........ ~ ~... ~ . . BOPE press rating appropriate; test to f:~>L) ~ psig. Choke manifold complieS w/APl RP-53 (May 84) ........ Work will' occur without operation shutdown ........... Is presence of H2S gas probable ................. Y Permit can be issued wlo hydrogen sulfide measures ..... Y N Data presented on potential overpressure zones ....... Y ~,/' .~ ,, ~,,.] seismic analysis of shallow gas zones... .......... Y.//N /'/./~ ~ , Seabed condition survey (if off-shore) ............. Contact name/phone for weekly progress reports [exploratory on, f] Y N Y N Y N YN Y N Y N With proper cementing records, this plan (A) will contain waste in a sUitable receiving zonei ....... (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 n~ot circumvent 20 AAC 25.252 or 20 AAC 25.412. ENGINEERING: ' UICIAnnular COMMISSION: ,, ,,. " Commentsllnstructions: 0 Z 0 -I Z .-I -1- c:Imsoffice\wordia n~diana\checklist (rev. 111011100) Well History File APPENDIX Information of detailed nature that is not ,padiculady 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 SRevision: 3 $ LisLib SRevision: 4 $ Fri Mar 01 09:12:23 2002 Reel Header Service name ............. LISTPE Date ..................... 02/03/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Tape Header Service name ............. LISTPE Date ..................... 02/03/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Nuraber ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Comment Record TAPE HEADER Aurora MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: # WELL CASING RECORD S-ll0 500292303000 BP Exploration (Alaska), Inc Sperry-Sun Drilling Services 01-MAR-02 MWD RUN 1 MWD RUN 2 MWD RUN 4 AK-MM-ii134 AK-MM-ii134 AK-MM-II134 J. MARTIN J. MARTIN J. SACK L. VAUGHAN A. MADSEN A. MADSEN 35 12 12 4481 4498 69.55 36.40 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 20.000 113.0 2ND STRING 8.750 9.625 3466.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUNS 1 & 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 4. NO DATA WERE ACQUIRED ON MWD RUN 3 DUE TO A FAILED CASING TEST. 5. MWD RUN 4 COMPRISED DIRECTIONAL, DGR, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITHO-DENSITY (SLD). MWD DATA ARE CONSIDERED PDC PER E-MAIL FROM D. SCHNORR (GEOQUEST/BP) TO R. OAKLEY (SSDS), DATED 12/03/01, QUOTING AUTHORIZATION FROM ED WESTERGAARD (BP). 7o MWD RUNS 1, 2, AND 4 REPRESENT WELL S-Il0 WITH API#: 50-029-23030-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8792'MD / 7116'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY {MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME (SEDP). SPSF = SMOOTHED NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW- COUNT BIN). SLDSLIDE = SLIDE INTERVAL ADJUSTED FOR THE SLD SENSOR-TO-BIT DISTANCE PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 8.75" MUD WEIGHT: 10.3 - 10.5 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 21,932 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR ROP NCNT FCNT NPHI PEF FET RPD R?M RPS RPX DRHO RHOB $ # 61 0 113 5 3389 0 3389 0 3389 5 3398 5 3443 5 3443 5 3443 5 3443 5 3443.5 3468.0 3468.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD $ # REMARKS: 8762 8792 8698 8698 8697 8707 8754 8754 8754 8754 8754 8707 8707 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 61.0 1758.0 2 1758.0 3480.0 4 3480.0 8792.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD FT/H 4 1 68 GR MWD API 4 1 68 RPX MWD OHMM 4 1 68 R?S MWD OHMM 4 1 68 RPM MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 RHOB MWD G/CM 4 1 68 DRHO MWD G/CM 4 1 68 PEF MWD BARN 4 1 68 FCNT MWD CNTS 4 1 68 NCNT MWD CNTS 4 1 68 NPHI MWD PU-S 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 36 10 40 11 44 12 48 13 52 14 Name Service Unit Min Max DEPT FT 61 8792 ROP MWD FT/H 0 838.19 GR MWD API 7.07 409.53 RPX MWD OHMM 0.25 1037.49 R?S MWD OHMM 0.23 2000 R?M MWD OHMM 0.2 2000 RPD MWD OHMM 0.19 2000 FET MWD HOUR 0.12 130.27 RHOB MWD G/CM 1.23 3.304 DRHO MWD G/CM -0.334 0.564 PEF MWD BARN 1.89 14.8 FCNT MWD CNTS 402 1018 NCNT MWD CNTS 2008 3352 0. First Last Mean Nsam Reading Reading 4426.5 17463 61 8792 165.928 17358 113.5 8792 74.2996 17403 61 8762 6.80543 10623 3443.5 8754.5 7.74741 10623 3443.5 8754.5 9.03107 10623 3443.5 8754.5 15.5039 10623 3443.5 8754.5 1.44227 10623 3443.5 8754.5 2.2644 10479 3468 8707 0656403 10479 3468 8707 4.46008 10618 3398.5 8707 534.229 10596 3389 8698 2646.86 10619 3389 8698 NPHI MWD PU-S 23.57 84.47 First Reading For Entire File .......... 61 Last Reading For Entire File ........... 8792 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 44.5899 10594 3389.5 8697.5 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 61.0 1705.0 RO? 113.5 1758.0 $ LOG HEADER DATA DATE LOGGED: 15-AUG-01 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.16 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 1758.0 TOP LOG INTERVAL (FT): 113.0 BOTTOM LOG INTERVAL (FT) : 1758.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: .0 MAXIMUM ANGLE: 30.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02066HG8 $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12.250 DRILLER'S CASING DEPTH (FT): 113.0 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S): 340.0 MUD PH: 8.2 MUD CHLORIDES (PPM) : 400 FLUID LOSS (C3) : 5.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 .0 MUD AT MAX CIRCULATING TERMPERATURE: .000 75.2 MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 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 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 61 1758 909.5 3395 ROP MWD010 FT/H 0.06 663.99 82.3136 3290 GR MWD010 API 20.94 98.79 51.7011 3289 First Reading For Entire File .......... 61 Last Reading For Entire File ........... 1758 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 First Reading 61 113.5 61 Last Reading 1758 1758 1705 Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 1705.5 ROP 1758.5 $ 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: 3427.0 3480.0 16-AUG-01 Insite 66.16 Memory 3480.0 1758.0 3480.0 34.1 53.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02066HG8 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 12.250 BOREHOLE CONDITIONS MUD TYPE: Spud Mud MUD DENSITY (LB/G): 9.40 MUD VISCOSITY (S) : 289.0 MUD ?H: 8.0 MUD CHLORIDES (PPM): 300 FLUID LOSS (C3): 5.0 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): .000 MUD AT MAX CIRCULATING TERMPERATURE: .000 MUD FILTRATE AT MT: .000 MUD CAKE AT MT: .000 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ............... ...... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 .0 71.6 .0 .0 Name Service Unit Min Max Mean Nsam DEPT FT 1705.5 3480 2592.75 3550 ROP MWD020 FT/H 7.3 651.77 179.945 3444 GR MWD020 API 26.07 126.65 77.3491 3444 First Reading 1705.5 1758.5 1705.5 Last Reading 3480 3480 3427 First Reading For Entire File .......... 1705.5 Last Reading For Entire File ........... 3480 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 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 ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 .5000 DEPTH INCREMENT: FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI PEF GR FET RPD RPM RPS RPX DRHO RHOB ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE START DEPTH 3389.0 3389.0 3389.5 3398.5 3427.5 3443.5 3443.5 3443.5 3443.5 3443.5 3468.0 3468.0 3480.5 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 8698 0 8698 0 8697 5 8707 0 8762 0 8754 5 8754 5 8754.5 8754.5 8754.5 8707.0 8707.0 8792.0 24-AUG-01 Insite 66.16 Memory 8792.0 3480.0 8792.0 2.8 50.1 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY PB02104HWRGV6 EWR4 ELECTROMAG. RESIS. 4 PB02104HWRGV6 CNP COMPENSATED NEUTRON PB02104HWRGV6 SLD STABILIZED LITHO DEN PB02104HWRGV6 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.750 DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam DEPT FT 4 1 ROP MWD040 FT/H 4 1 GR MWD040 API 4 1 RPX MWD040 OHMM 4 1 RPS MWD040 OHMM 4 1 RPM MWD040 OHMM 4 1 RPD MWD040 OHMM 4 1 FET MWD040 HOUR 4 1 RHOB MWD040 G/CM 4 1 DRHO MWD040 G/CM 4 1 PEF MWD040 BARN 4 1 FCNT MWD040 CNTS 4 1 NCNT MWD040 CNTS 4 1 NPHI MWD040 PU-S 4 1 3466.0 LSND 10.30 48.0 9.5 400 4.4 2.600 1.534 2.200 2.700 Rep Code Offset Channel 68 0 1 68 4 2 68 8 3 68 12 4 68 16 5 68 20 6 68 24 7 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 68.0 120.0 68.0 68.0 Name Service Unit Min DEPT FT 3389 ROP MWD040 FT/H 0 GR MWD040 API 7.07 RPX MWD040 OHMM 0.25 RPS MWD040 OHMM 0.23 RPM MWD040 OHMM 0.2 RPD MWD040 OHMM 0.19 FET MWD040 HOUR 0.12 RHOB MWD040 G/CM 1.23 DRHO MWD040 G/CM -0.334 PEF MWD040 BARN 1.89 FCNT MWD040 CNTS 402 NCNT MWD040 CNTS 2008 NPHI MWD040 PU-S 23.57 Max Mean Nsam 8792 6090.5 10807 838.19 187.277 10624 409.53 80.2813 10670 1037.49 6.80543 10623 2000 7.74741 10623 2000 9.03107 10623 2000 15.5039 10623 130.27 1.44227 10623 3.304 2.2644 10479 0.564 0.0656403 10479 14.8 4.46008 10618 1018 534.229 10596 3352 2646.86 10619 84.47 44.5899 10594 First Reading For Entire File .......... 3389 Last Reading For Entire File ........... 8792 First Reading 3389 3480.5 3427.5 3443.5 3443.5 3443.5 3443.5 3443.5 3468 3468 3398.5 3389 3389 3389.5 Last Reading 8792 8792 8762 8754.5 8754.5 8754.5 8754.5 8754.5 8707 8707 8707 8698 8698 8697.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 02/03/01 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 02/03/01 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Reel Trailer Service name ............. LISTPE Date ..................... 02/03/01 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Scientific Technical Services Physical EOF Physical EOF End Of LIS File
