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190-146
. XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original - Pages: [] Other Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED -[] Logs-of vadous kinds . n Other COMMENTS: Scanned by Dianna Vincent Nathan Lowell TO RE-SCAN Notes: - Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: is~ STATE OF ALASKA f ,R .: ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LO la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other IN Abandoned '❑Suspended 1 b. Well Class 20AAC25.105 20AAC25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero ®Development•0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: . BP Exploration(Alaska) Inc. 3/18/2014 ✓• 190-146 312-477 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 12/4/1990 • 50-029-22098-00-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 12/17/1990 PBU 09-47 1170'FSL, 113'FWL, Sec. 01,T1ON, R15E, UM 8. KB(ft above MSL): 52' 15.Field/Pool(s) Top of Productive Horizon: 2672'FSL,5191' FWL, Sec.01,T1ON, R15E, UM GL(ft above MSL): 19.67' Prudhoe Bay/Prudhoe Bay • Total Depth: - 9. Plug Back Depth(MD+TVD) 2693'FSL, 129'FWL, Sec.06,T1ON, R16E, UM 10510' 8872' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 718499 y- 5942641 Zone- ASP4 10844' 9153' • . ADL 028327&028345 TPI: x- 723530 y- 5944292 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 723748 Y- 5944320 Zone- ASP4 None 18.Directional Survey: 0 Yes ®No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: GR/SP/DIL/BHCS, GR/CNL/LDT, CET/CBT/GR, Gyro N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 115' Surface 115' 30" 40 sx Arctic Set Cement 10-3/4" 45.5# J-55 Surface 4009' Surface 3516' 13-1/2" 1335 sx CS III, 3220 sx Class'G', 300 sx CS II 7-5/8" 29.7# L-80 Surface 10833' Surface 9143' 9-7/8" 127 Bbis MTC,275 sx ARC Cement,225 sx CS I 24. Open to production or injection? 0 Yes 0 No 125. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): 4-1/2", 12.6#x3-l/2"9.3#, L-80 10316' 10216'/8625' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No SCANNED MAY 2 1 ?Wit DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 10510' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested. Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 No Sidewall Core(s)Acquired? 0 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 RBDMS APR 17 2q--' Form 10-407 Revised 10/2012 CONTII ED ON EVE E Submit 0 iginal Only 1/l l= 1/Z316� /' Y � � ,,, ,_2� /y G 29. GEOLOGIC MARKERS(List all formations an, kers encounter 30. FORMATION TESTS NAME MD TVD Well Tested? 0 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. Colville Mudstone 9641' 8144' None HRZ 10175' 8590' Top Sadlerochit 10443' 8816' Base Sadlerochit 10686' 9020' Formation at Total Depth: 31.List of Attachment: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Mel Rixse,564-5620 Email: Mel.Rixse@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: Phone 564-4091 Date:4/15/J J' 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'leach 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 10/2012 Submit Original Only 09-47, Well History (Pre Rig Sidetrack) Date Summary 03/01/14 T/I/O=BPV/0/0. Remove dryhole tree. Install new 4"CIW tree.Torque to API specs. Pulled BPV#540 Set TTP#547 PT'd tree(PASSED). Pulled TTP#547. Installed tree cap and PT'd(PASSED). RDMO. Final WHP's 0/0/0. 03/02/14 RIG UP SLICKLINE UNIT SWCP 4515. SET 3-1/2"WHIDDON CATCHER IN STA.#7 @ 10,127'SLM (unable to pass). 03/03/14 ATTEMPT TO SET RK-DGLV IN STA#6, SAT DOWN IN STA#4 @ 8,682'SLM(dropped valve) RATTLED MANDRELS 1 to 6, SAT DOWN @ 10,104'SLM(23'above catcher) UNABLE TO WORK DEEPER. MADE THREE RUNS W/10'x 2.25" PUMP BAILER TO 10,106'SLM-2 GALLONS OF PLASTIC COATING RECOVERED. 03/04/14 MADE 3 RUNS w/2.50" PUMP BAILER, RECOVERED-2.5 GALLONS OF PLASTIC COATING TO 10,116'SLM. RAN 1.75 LIB TO ST#6 @ 9682'SLM (9714'MD)(open pocket). SET RK-DGLV IN ST#6 @ 9687'SLM (9714'MD). PERFORMED MIT-IA to 3000 psi(Passed). >>»»NOTE: 3-1/2"WHIDDON CATCHER SUB LEFT IN HOLE @ 10,127'SLM«««. >>»»NOTE: 1-1/2" RK-DGLV LOST DOWN HOLE UNKNOWN DEPTH«««. 03/05/14 T/I/O=SSV/0/0.Temp=SI. MIT-IA to 3000 psi. (CTD Prep). No wellhouse or flowline. Drilling scaffolding on well. Issues with P-sub valves,job postponed until resolved. SV,WV, SSV=C. MV=O. IA&OA= OTG. 17:00. 03/05/14 CTU 3 w/1.75"0.134"wall CT-32.9 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon, & WRP. Drift for whipstock. Grease Crew service WH Valves, RD Drillers Platform and RU Scaffolding. 03/06/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon, & WRP. Drift for whipstock. RU Scaffolding-MIRU CTU#3. MU BOT jars/2.15"OD modified Bowen Short Catch overshot w/1.19"basket grapple.Tag frac sleeve @ 2201'. Could NOT work thru-POOH-MU new ctc-knuckle jnt. 03/07/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon,& WRP. Drift for whipstock. RIH w/BOT jars/knuckle Jnt/2.15"OD modified Bowen Short Catch overshot w/1.19"basket grapple.Tag @ SSSV w/Frac Slv @ 2219' not work past-POOH- RIH w/2.25"JSN- RIH Clean out to 9750'-pump 2 sweeps-POOH-Swap BOP's-. 03/08/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon,& WRP. Drift for whipstock. Complete 7 day BOP Tests-MU OverShot w/Mule Shoe& Indexing Tool- RIH-Tag @ SSSV w/stuck frac slv @ 2219'-Index three times and made it thru-RIH.Take 100' bites w/5 bbl gel sweeps from 9750'-10050'.Take 100'bite w/10 bbl sweep from 10050'to tag @ 10145'. Repeat 10 bbl sweep from 10050'to 10145'. Circulate bottoms up. RIH to tag. Cycle indexing tool 11 times/12 tags for full 360 degree rotation of indexing/overshot. Pump final 10 bbl sweep from 10100'- 10045'. Chase out. Circ bottoms up at 5000'. FP surface lines. Pump meth/wtr down backside while POOH for FP cap. BD Over Shot(NO GLV, but mule shoe dented in like top of Whiddon Catcher)& Indexing Tool. MU 3"GS Spear-RIH-Tag @ 10,147'-POOH-Retrieved-Whiddon Catcher w/Dummy GLV Inside-BD BOT Tools to ctc. 03/09/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon, & WRP. Drift for whipstock. Retrieved-Whiddon Catcher w/Dummy GLV Inside-BD BOT Tools to ctc. MU DJN- RIH.Tag WRP @ 10157.Jet and chase out 2 gel pills at top of WRP, chase out/circ bottoms up.At 5005', pump meth/wtr down backside for pipe displacement/FP cap on well. MU WOT WRP wash over assembly w/tattle tails and eqalizing sleeve. RIH-Tag @ 10,156'-. Page 1 of 2 09-47, Well History (Pre Rig Sidetrack) Date Summary 03/10/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon,& WRP. Drift for whipstock. POOH w/Equalizing Tools for WRP-BD WOT Tools-Tattle Tails Not Bent- MU Wash Over Assembly w/Venturi .Tag WRP @ 10152'(ctm up). Recip on WRP w/venturi @ 0.5 0.7 and 1.0 bpm. Dry tag again. Same. Cycle pump on tag twice. POOH. FP backside. BD WOT Venturi (about 1/2 cup of plastic flakes and metal shavings). 03/11/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon,& WRP. Drift for whipstock. RIH w/Venturi-Wash Over Assembly w/Tattle Tails-Tag @ 10,156-Pump 1.4 bpm-tag 3 times-dry tag- 1 jar lick-POOH-all tattle tails bent- 1/2 cup of plastic/metal shavings. MU/RIH pulling tool w/collets/EQ sleeve/Mule shoe, baited on GS spear.Tag frac sleeve @ 2201'. Make all possible attempts to pass. NO. POOH to reconfigure.Add KJ/Swivel above GS, rotate&dress muleshoe 180 degree. RIH.Tag same.Attempt to pass, NO. POOH,turn over to S/L to fish WRP. Coil is standing by with S/L rigged on top of coil BOP's. 03/11/14 RAN 3-1/2"GS&3-1/2"WFD WRP PULLING TOOL. SD IN SVLN @ 2185'SLM (2219'MD),ABLE TO LIGHTLY HAND SPANG THROUGH BROKEN FRAC SLEEVE. SD ON TOP OF 3-1/2"WRP @ 10,133' SLM. UNABLE TO LATCH. RAN 3-1/2"GR&3-1/2"WFD WRP PULLING TOOL. SD @ SAME DEPTH &STILL UNABLE TO LATCH. 03/12/14 RAN 3-1/2"GS&3-1/2"WFD WRP PULLING TOOL. SET WFD PULLING TOOL @ 10,133'SLM FOR COIL. 03/12/14 CTU 3 w/1.75"0.134"wall CT-32.1 bbl Vol. Job Scope: Clean out and Fish 1-1/2"GLV,Whiddon, & WRP. SL tried to latch WRP-No Luck-SL left 3.5 WRP Retrieval Tool on Top of WRP @ 10,133'SLM- SL RDMO. MU WOT fishing string w/jars&3"GS.Tag bait/fish @ 10152'down. Pick up bait, RIH/Jar to engage fish. Move, park, let elements relax. POOH, pulling heavy, Popped free @ 10145', pull heavy continue OOH. Stick in frac sleeve @ 2192'. One jar lick, popped free. POOH. FP backside w/30 bbl meth/wtr.WRP recovered. Missing 2.5 of 3 rubbers. RDMO. Page 2 of 2 North America-ALASKA-BP Page 1,gRgx Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:OOAM 'Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00©52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/8/2014 22:00 - 00:00 2.00 MOB P PRE HOLD PJSM WITH SECURITY AND START _ MOVING RIG FROM DS03 TO DS09. 3/9/2014 00:00 - 00:20 0.33 MOB P PRE 'COMPLETE MOVING RIG FROM DS03 TO •DS09 AND PARK RIG ON SIDE OF PAD. 00:20 - 06:00 4.67 MOB N WAIT PRE 'WAIT FOR WELL 09-47 TO BE READY FOR RIG. PERFORM WORK ON FLUID-END OF MUD PUMP#2. 06:00 - 18:00 12.00 MOB N WAIT PRE MOVE SAT OFFICE TO DS09 AND RU TO TEST SLB THROUGH BIT LOGGING TOOLS WHILE WAITING FOR WELL PREP TO BE COMPLETED.LEAK ON THE PAD FROM A FAILED POWER STEERING PUMP ON A PICK UP.ALL MANAGEMENT NOTIFIED AND TRACTION REPORT WAS ENTERED.SRT I CAME OUT,CLEANED IT UP AND CALLED IT 2 TBSP(TABLESPOONS)OF FLUID ON THE —. GROUND. 18:00 - 22:00 4.00 MOB N WAIT PRE I COMPLETE RIG-UP TEST ON CATWALK WITH SLB'THROUGH BIT'OH-LOGGING TOOLS.MU TOOLS TO BHI UQC/LQC/X-OVER AND SUCCESSFULLY POWER UP.LOOKING ALL GOOD.COMPLETE TEST AND LOAD OUT ALL LOGGING TOOLS OFF RIGFLOOR. 22:00 - 00:00 2.00 MOB N WAIT PRE 'CONTINUE WORK ON FLUID-END OF MUD PUMP#2 WHILE WAITING FOR WELL PREP ON 09-47. 3/10/2014 00:00 - 09:00 9.00 MOB N WAIT PRE CHANGE OUT VALVES ON REELHOUSE 2" IRON AND PERFORM GENERAL MAINTENANCE. PAUSE ALL WORK FOR 1 HR WHILE PARKER 272'S RIG-MOVE IS BLOCKING EMERGENCY ACCESS. 09:00 - 10:00 1.00 MOB N WAIT PRE SHUT DOWN OPERATIONS ON RIG WHILE PARKER IS BLOCKING THE ACCESS ROAD TO DS 9 TO MOVE THEIR RIG 10:00 - 18:00 8.00 MOB N WAIT PRE RESUME OPERATIONS AND CONTINUE WORK ON MUD PUMP#2. 18:00 - 00:00 6.00 MOB N WAIT PRE FINISH WELDING ON PUMP#2 SUCTION MANIFOLD AND INSTALL SAME.REMOVE BAKER BEAMS IN PIPESHED. 3/11/2014 00:00 - 12:00 12.00 MOB N WAIT PRE BEGIN INSTALLING PLUMBING ON MUD PUMP #2 SUCTION MANIFOLD AND CONTINUE WORK ON BAKER BEAMS IN PIPE SHED. ULTRASONIC TEST LOW PRESSURE MUD LINES IN PUMP ROOM FOR WALL THICKNESS.PREP AND PAINT PIPE SHED. 12:00 - 00:00 12.00 MOB N WAIT PRE COMPLETE FLUID END INSTALLATION OF MUD PUMP#2.PREP AND PAINT PIPE SHED. I WORK ON BAKER BEAMS IN PIPE SHED. 3/12/2014 00:00 - 06:00 6.00 MOB N WAIT PRE WAIT FOR WELL 09-47 TO BE READY FOR RIG.PREP AND PAINT PIPE SHED.REPLACE WATER PUMP ON BOILER. PERFORM GENERAL HOUSEKEEPING AROUND THE RIG. Printed 3/31/2014 11.37 40AM North America-ALASKA-BP Page 246,1, Operation Summary Report Common Well Name 09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824.290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00 00AM Rig Release: Rig Contractor:NORDIC CALISTA I UWI:500292209800 Active datum:68:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 18:00 12.00 MOB N WAIT PRE CONTINUE TO WAIT ON WELL PREP ON DS 109.47. RIG CREW CONDUCTING ;MAINTENANCE ON RIG. -UPDATED AOGCC WITH TENTATIVE BOP TEST START TIME OF NOON ON THURSDAY, MARCH 13TH. 18:00 - 23:00 5.00 MOB N WAIT PRE CONTINUE TO WAIT ON WELL PREP ON DS 09-47. RIG CREW CONDUCTING MAINTENANCE ON RIG. -COIL UNIT SUCCESSFULLY RETRIEVED PLUG AND BEGINS TO RD. BEGIN WARMING RIG MOVE SYSTEM IN PREP TO MOVE TO WELL 09-47 AT 20:00 HRS. 23:00 - 00:00 1.00 MOB N WAIT PRE CONTINUE TO WAIT ON WELL PREP ON DS 09-47.COIL UNIT COMPLETED RD AND MOVED OFF OF WELL.HARDLINE CREW ON LOCATION TO COMPLETE RIG DOWN ON WELL. 3/13/2014 00:00 - 06:00 6.00 MOB N WAIT PRE CONTINUE TO WAIT ON WELL PREP ON DS 9-47.HARDLINE CREW COMPLETE RIG DOWN ON WELL.VALVE CREW ON LOCATION TO SET BPV,INSTALL TEST SPOOL,TORQUE AND MARK TREE BOLTS AND TEST TREE. 06:00 - 18:00 12.00 MOB N WAIT PRE CREW WORKED ON TREE THROUGHOUT DAY. MOVED SATELLITE CAMP AND SUPPORT EQUIPMENT TO LOCATION NEAR WELL. CONTINUED WITH MAINTENANCE ON WATER PUMPS,MIXERS,WELDING IN PIPE SHED. SENT INITIAL UPDATE TO AOGCC AT 10800 HRS AND SENT SECOND UPDATE IN EVENING BEFORE CHANGEOUT. -CONDUCTED PRE-SPUD WITH CREW -CONTACTED BY AOGCC REP AT 1750 HRS, AOGCC HAS WAIVED WITNESS OF INITIAL BOP TEST FOR DS 9-47A 18:00 - 19:30 1.50 MOB N WAIT PRE CONTINUED WITH BHI TOOL RACK INSTALLATION.PREPARE TO MOVE RIG BY LAYING RIG MATS AT WELL 09-47A. 19:30 - 21:00 1.50 MOB P PRE PJSM ON MOVING RIG OVER WELL.VERIFY ALL TREE VALVES ARE CLOSED.CONFIRM 0 PSI ON IA,OA.SHUT IN IA AND OA.SPOT RIG AT WELL. TEST ESD.MOVE RIG OVER WELL 09-47A. RIG ACCEPTED AT 2100 HRS. 21:00 - 22:30 1.50 BOPSUR P PRE SECURE CELLAR.RU OUTSIDE EQUIPMENT. INSTALL ANNULUS GUARDS AND PRESSURE SENSORS.HOOK UP THE SSV HOSE. 22:30 - 00:00 1.50 BOPSUR P PRE OPEN SWAB,SSV,AND MASTER VALVE. I VERIFY 0 PSI AT WING VALVE. CLOSE SWAB, SSV,AND MASTER VALVE. RU TO WING VALVE AND LEAK TIGHT TEST PER WELL PLAN.GOOD TEST,BLEED PRESSURE TO 0 PSI,CLOSE THE SSV AND MONITOR VOID ,FOR PRESSURE WITH THE OA SENSOR WHILE BREAKING CONTAINMENT TO NU THE BOPE.ND TREE CAP FLANGE.NU BOP. Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 3 e Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 • Active datum:69:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) _ • (usft) 3/14/2014 00:00 - 03:00 3.00 BOPSUR P PRE NU BOP.INSTALL FLOOR DRAIN.RECORD RKB.CHARGE ACCUMULATOR.SPOT FLOW BACK TANK.CONDUCT PRESSURE CROSSCHECK WITH HARDLINE CREW.RU •AND PT HARDLINE. 03:00 - 04:00 1.00 BOPSUR P PRE SET TEST PLUG.FLUID PACK BOP AND CHOKE.PRESSURE TEST MUD PUMP 2. 04:00 - 04:30 0.50 BOPSUR P PRE CONDUCT RIG H2S EVACUATION DRILL AND AAR. 04:30 - 06:00 1.50 BOPSUR P PRE PJSM ON PRESSURE TESTING BOP. CONDUCT PRESSURE CROSSCHECK PRIOR TO TESTING.CONDUCT BOP TEST PER AOGCC,NORDIC AND BP REGULATIONS AND REQUIREMENTS. MONITOR PRESSURE BELOW BOP TEST PLUG THROUGH WING VALVE. 06:00 - 16:30 10.50 BOPSUR P PRE CONDUCT CREW CHANGE OUT. CONTINUE WITH BOP TESTING. CONDUCT ACCUMULATOR DRAWDOWN TEST FUNCTIONING RAMS FROM DRILLER'S CONSOLE;FUNCTION TEST RAMS FROM CTS REMOTE PANEL. -INSTALL COIL CONNECTOR,PULL TEST TO 40KAND CONDUCT VISUAL VERIFICATION PRESSURE TEST. BOTH GOOD. STAB ON WITH INJECTOR,PRESSURE TEST PACKOFFS AND INNER REEL IRON/VALVE. ALL GOOD. -SET INJECTOR TO SIDE,EMPTY STACK AND I _ PULL BOP TEST PLUG. 16:30 - 17:00 0.50 RIGU P PRE CONDUCT RIG EVACUATION DRILL SIMULATING H2S GAS IN PITS. CREW RESPONDED WELL,MUSTERED AT PRIMARY MUSTER AREA FOR HEAD COUNT AND AAR. GAVE ALL CLEAR,CREW RE-ENTERED RIG. 17:00 - 19:30 2.50 BOPSUR P PRE VALVE CREW ON LOCATION. STAGE VEHICLES. CONDUCT PJSM ON JOB SCOPE FOR TORQUE AND TEST ON TREE BOLTS AND MOBILIZING LUBRICATOR TO RIG FLOOR. -ONE CREW BEGIN WORK ON TORQUE AND TEST OF TREE BOLTS,OTHER CREW MOBILIZE LUBRICATOR TO RIG FLOOR AND WAIT ON COMPLETION OF TORQUE AND TEST 19:30 - 20:00 0.50 BOPSUR P PRE PJSM.MOBILIZE VALVE CREWS LUBRICATOR AND BPV-RETRIEVING RODS TO RIG FLOOR. MU LUBRICATOR AND RETRIEVING RODS. STAB ON AND PRESSURE TEST LUBRICATOR PER CRITERIA IN WELL PLAN. MOVE SENSOR FROM BETWEEN SSVAND SWAB AND PLACE ONTO OA. OPEN SSV,THEN MASTER AND SWAB VALVES AGAINST CLOSED CHOKE. Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 4.e(3a Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 22:30 2.50 BOPSUR P PRE PER VALVE CREW RP,ATTEMPT TO PUMP THROUGH BPV TO CONFIRM NO PRESSURE BELOW BPV(I.E.BPV IS EQUALIZED.) -PRESSURE QUICKLY INCREASES TO 250 PSI.PRESSURE REMAINS CONSTANT.DID NOT OBSERVE LOW PRESSURE BREAKOVER WHICH WOULD INDICATE FLUID FLOWING THROUGH BPV. -SLOWLY INCREASE PRESSURE TO 500PSI. PRESSURE REMAINS CONSTANT. -BLEED OFF AND DISCUSS PLAN FORWARD -APPLY STEAM TOO TREE TO THAW UP ANY POTENTIAL ICE-PLUG ON TOP OF BPV 22:30 - 22:50 0.33 BOPSUR P PRE CONDUCT SAFETY MEETING.REVIEWED 'FLOW CHART FOR TAKING POSSIBLE GAS RETURNS TO FLOWBACK TANK.ASSESS POTENTIAL FOR GAS BELOW BPV (DOWNHOLE CEMENT PLUG DID NOT PASS MIT).INFORM AND DISCUSS PLAN FORWARD WITH ODE. • 22:50 - 23:20 0.50 BOPSUR P PRE DECIDE TO APPLY 1,000PSI AND PULL BPV. COMMENCE PUMPING,PRESSURE BREAKS OVER AT 600PSI LATCH INTO BPV AND RECOVER BPV TO SURFACE -WELL IS HOLDING STABILIZED PRESSURE OF 600 PSI. • 23:20 - 00:00 0.67 BOPSUR P PRE ESTABLISH BARRIERS AND BREAK OFF LUBRICATOR.CONFIRM BPV IS RECOVERED. -NOTICE FAIR AMOUNTS OF GREASE ON BPV LD LUBRICATOR AND EXTENSION RODS 3/15/2014 00:00 - 01:00 1.00 BOPSUR P PRE STAB ON WITH INJECTOR AND PRESSURE TEST 7"OTIS CONNECTION TO 250/3500 PSI. POP OFF WITH INJECTOR AND STAND BACK INSTALL NIGHTCAP. PRESSURE TEST NIGHTCAP TO 250/3500 PSI.GOOD TEST. -SIMOPS:MOBILIZE LUBRICATOR OFF RIG FLOOR. 01:00 - 01:30 0.50 BOPSUR P PRE LINE UP TO TAKE RETURNS TO FLOW BACK TANK.BLOW DOWN LINES TO FLOWBACK TANK.CLOSE CHOKE,OPEN UP WELL AGAINST CLOSED CHOKE.OBSERVE PRESSURE INCREASE TO 480 PSI.OPEN CHOKE AND BLEED PRESSURE TO 5 PSI. OBSERVE RETURN OF 0.3 BBLS.OPEN BLEEDER VALVE ON NIGHT CAP AND FLOW CHECK THE WELL.OBSERVE GOOD NO FLOW. 01:30 - 02:45 1.25 CLEAN N DPRB 10,278.00 PRE PJSM ON PU AND MU OF MILLING BHA. MOBILIZE BAKER TOOLS TO RIG FLOOR. VERIFY TOOLS ARE DRIFTED.MU MILLING BHA#1 W/2.72"PIRANHA MILL,STRING REAMER,X-TREME MOTOR,CIRC SUB, HI-LOAD DISCONNECT,JARS,WEIGHT BARS, ACCELERATOR,BPV,2 JTS 2-1/16"CSH. Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 5/44- Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:45 - 03:15 0.50 CLEAN N DPRB 10,278.00 PRE RIH WITH MILLING BHA#1 AT 100 FPM WHILE PUMPING AT 0.16 BPM WITH 50 PSI CIRCULATING PRESSURE.TAG FRAC SLEEVE AT 2214'AND SET DOWN 10K.SHUT DOWN PUMPS AND PU.RIH AND TAG A SECOND TIME AND SET DOWN 12K.PU AND BRING ON PUMPS TO 0.5 BPM.RIH AND SUCCESSFULLY PASS THROUGH FRAC SLEEVE. 03:15 - 04:40 1.42 CLEAN N DPRB 10,278.00 PRE RIH FROM 2214'AT 100 FPM WHILE PUMPING AT 0.11 BPM WITH 70 PSI CIRCULATING PRESSURE. TAG TOP OF CEMENT AT 10278'. 04:40 - 06:00 1.33 CLEAN N DPRB 10,278.00 PRE PU.CIRCULATE AT 1.50 BPM WITH 1900 PSI FREE SPIN.RIH AND BEGIN MILLING AT 10276'. PUMP AT 1.45-1.54 BPM WITH 2980-3274 PSI CIRC PRESSURE. WOB=660-1602 LBS ROP=11-21 FPH. MILL TO 10286'. 06:00 - 13:00 7.00 CLEAN N DPRB 10,290.00 PRE MONITOR SHAKER,NO DEBRIS OVER SHAKER. SWAP OVER TO 8.4 PPG 1%KCL WITH VISCOSIFIER. FIRST PIECE OF RUBBER DEBRIS ACROSS SHAKER WITH RETURN OF BOTTOMS UP. CONTINUE MILLING WITH 200-250 PSI DIFFERENTIAL PRESSURE(MOTORWORK)AND PUMPING SWEEPS. SOME RUBBER RETURNS BUT NOT ENOUGH FOR CONFIDENCE THAT IT IS ALL UP;EXPECTATION IS TO FIND APPROXIMATELY 1 TO 1-1/2 CUPS OF RUBBER. ON BOTTOM AGAIN WITH INCREASED WOB AND PUMP ANOTHER HI-VIS SWEEP. ONE PIECE OF RUBBER BACK. FLUSHED MICROMOTION,DUMPED POSSUM BELLY IN ATTEMPT TO FIND MORE RUBBER;FOUR MORE SMALL PIECES FOUND. APPROXIMATELY 1/2 CUP OF RUBBER RETURNED FROM WELL. -2400-2650 PSI AT 1.4-1.5 BPM HOLDING-250 DIFFERENTIAL PSI DURING MILLING OPERATIONS -DISCUSS VARIABLES,DECIDE TO OPEN CIRC SUB FOR HIGHER FLOW RATE 13:00 - 13:45 0.75 CLEAN N DPRB 10,290.00 PRE PJSM ON DROPPING BALL. FLOW CHECK WELL,ALL GOOD. LOCK OUT/TAG OUT EQUIPMENT,DROP 3/8"BALL. LAND ON SEAT,BALL SHEAR AT 3380 PSI. MOVE BHA TO BOTTOM AND BRING RATE UP TO 2.6 BPM, 3920 PSI. 13:45 - 17:00 3.25 CLEAN N DPRB 10,290.00 PRE PICK UP HOLE CHASING POTENTIAL JUNK FROM BOTTOM AT 2.65-2.80 BPM,3800-3930 PSI. A LOT OF BRITTLE CUTTINGS MIXED WITH SCALE COMING BACK. HAVE DOUBLED THE AMOUNT OF RUBBER CAUGHT COMING ACROSS THE SHAKER. NO ISSUES PULLING UP THROUGH FRAC SLEEVE AT 2200'. -PULL TO SURFACE,FLOW CHECK WELL. PJSM FOR LAYING DOWN BHA. TOTAL OF-1 CUP OF RUBBER BACK Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 6.o Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: 'X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor NORDIC CALISTA UW:500292209800 Active datum:69 47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth I Phase Description of Operations (hr) (usft) 17:00 - 18:00 1.00 CLEAN N DPRB 10,290.00 • PRE POP OFF,STAND BACK INJECTOR. LD BHA. RETRIEVE 3/8"BALL FROM CIRC SUB. MOBILIZE MOTOR AND JARS OFF OF RIG. 18:00 - 20:40 2.67 I STMILL P WEXIT CLEAR AND CLEAN RIG FLOOR. CONDUCT •CREW CHANGEOUT. PJSM FOR SLACK MANAGEMENT. STAB ON WITH INJECTOR AND PUMP SLACK BACK.POP OFF WITH INJECTOR AND MAKE UP COIL CUTTER.CUT 265'OF COIL WHICH PROVIDES 1.8%EXCESS SLACK. MU CTC. PULL TEST CTC TO 35K.PRESSURE TEST THE COIL TUBING CONNECTOR TO 4000 PSI. 20:40 - 21:10 0.50 STMILL P WEXIT STAB ON WTH INJECTOR.PUMP SLACK FORWARD.PRESSURE TEST 7"OTIS CONNECTION.GOOD TEST.OPEN WELL TO CLOSED CHOKE.VERIFY HOLE IS FULL AND 0 PSI SHUT IN PRESSURE.FLOW CHECK AND • i _ CONFIRM GOOD NO FLOW. 21:10 - 22:30 1.33 STMILL P WEXIT POP OFF WITH INJECTOR.HEAD UP WITH BAKER INTEQ TOOLS. TEST E-LINE.MAKE UP UPPER QUICK CONNECT AND PT. 22:30 - 23:00 0.50 STMILL P WEXIT PJSM FOR MAKING UP PILOT HOLE MILLING BHA#2. -GAUGE MILL: 2.74"GO/2.73"NO GO -GAUGE STRING REAMER:2.73"GO/2.72"NO GO. -MU MILLING BHA WITH 2.74"DIAMOND PARABOLIC MILL,2.73"STRING REAMER, X-TREME MOTOR W/0.90 AKO,FLOATS,AND COIL TRAK.RIH TO 60.09' • CONDUCT KICK DRILL WHILE MAKING UP • . • BHA FOLLOWED BY AAR. GOOD RESPONSE BY CREW. 23:00 - 23:30 0.50 STMILL P WEXIT STAB ON WITH INJECTOR.OPEN EDC AND PUMP SLACK FORWARD.TEST QUICK TEST SUB TO 250/3500 PSI. 23:30 - 00:00 0.50 STMILL P WEXIT RIH WITH PILOT HOLE MILLING BHA#2. 3/16/2014 00:00 - 02:30 2.50 STMILL P WEXIT RIH TO 10130'.LOG TIE IN TO 10192'.APPLY -15'CORRECTION.CLOSE EDC.RIH TO 10178'.OBTAIN SLOW PUMP RATES. 02:30 - 03:45 1.25 STMILL P WEXIT RIH TO 10276'.ORIENT 20 DEG ROHS. COMMENCE DRILLING 2.74"CEMENT PILOT • HOLE. ON BOTTOM MILLING CMT PILOT HOLE FROM 10276'TO 10297' FREE SPIN=2620 PSI AT 1.55 BPM • ;RATE IN=1.55-1.65 BPM RATE OUT=1.53- 11.64 BPM 1 ROP=16-24 FPH WOB=1.75-2.14 K CIRC PSI=2787-2990 PSI MW IN=8.42 PPG MW OUT=8.42 PPG ECD • =9.77 PPG IAP=348 PSI OAP=20 PSI PVT=291 OBSERVE MOTOR STALLS AT 10297'AND I DECREASE IN ROP. Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 7 041 Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:45 - 06:00 2.25 STMILL P WEXIT ON BOTTOM MILLING CMT PILOT HOLE.MILL FROM 10297'TO 10320'.MAINTAIN TOOLFACE AT 20 DEG ROHS. RATE IN=1.56 BPM RATE OUT=1.54 BPM ROP=18-27FPH WOB=1.21-2.10 K CIRC PSI=2714-2950 PSI MW IN=8.42 PPG MW OUT=8.42 PPG ECD =9.79 PPG IAP=352 PSI OAP=20 PSI PVT=290 BBLS. OBSERVE SOME SMALL PIECES OF RUBBER ACROSS SHAKERS MILLED CEMENT RETURNS. RUBBER CLEANED UP AFTER SHORT TIME. 06:00 - 08:15 2.25 STMILL P WEXIT MILL CEMENT PILOT HOLE FROM 10320'TO 10360' -MAINTAIN TOOLFACE AT 20 DEG ROHS WITH LITTLE DIFFICULTY 3060-3090 PSI AT 1.6 BPM,WOB 1.6-1.9K, ROP AVERAGING 15-20 FPH -MW IN AND OUT 8.45 PPG 108:15 - 08:45 0.50 STMILL P WEXIT CONDUCT WIPER TRIP UP TO TOP OF CEMENT. RECORD SLOW PUMP RATES. MOVE DOWN,TAG BOTTOM. 08:45 - 11:15 2.50 STMILL P WEXIT MILL CEMENT PILOT HOLE FROM 10360'TO 10400'. FREE SPIN 2945 PSI AT 1.6 BPM. -MAINTAIN TOOLFACE AT 20 DEG ROHS -3220-3270 PSI AT 1.65 BPM,WOB 1.6-1.9K, ROP AVERAGING 17-20 FPH -MW IN AND OUT 8.45 PPG -CIRCULATING PRESSURE CLIMBED UP, PUMPED A HI-VIS SWEEP TO HELP REMOVE CEMENT CUTTINGS FROM WELLAND POSSIBLY LOWER CIRC PRESSURE 11:15 - 11:45 0.50 STMILL P WEXIT PILL OUT OF BIT. CONDUCT WIPER UP TO 10,200'TO CHASE PILL OUT OF HOLE. TURN AROUND AND MOVE BACK DOWN SLOWLY AS PILL COMES TO SURFACE. 11:45 - 16:00 4.25 STMILL P WEXIT BACK ON BOTTOM AT 10,400'. FREE SPIN 2885 PSI AT 1.6 BPM,3125 PSI AT 1.65 BPM. -1.65-1.7 BPM,3125-3325 PSI,WOB.9-1.8K -PUMP ANOTHER SWEEP TO HELP CLEAN THE FINE CUTTINGS. CONDUCT A SHORT WIPER TO ENSURE IT IS CLEAN AROUND THE BHA. -SIGNIFICANT AMOUNTS OF WAX-LIKE BLACK CHUNKS COMING ACROSS WITH RETURNS FROM 10,440-10,480'. GRADUALLY DIMINISHED BUT STILL COMING ACROSS SHAKER. PUMP SWEEP. -ORIENTER QUICKLY JUMPED TO 130°AT 10,480'COIL DEPTH;PICK UP,SWEEP OUT OF BIT. 16:00 - 16:30 0.50 STMILL P WEXIT CONDUCT WIPER TO CHASE SWEEP UP HOLE. RUN BACK DOWN WITH NO ISSUES. ORIENTER SHOWED POSSIBLE CONTACT AGAIN AT 10,480'COIL DEPTH. 16:30 - 17:15 0.75 STMILL P WEXIT CONTINUE MILLING AHEAD. FREE SPIN 3030 PSI AT 1.65 BPM. 1.65-1.68 BPM,3333-33340 PSI,WOB 1.6-1.8K Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 84134 Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time: 12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00 Q52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:15 - 18:15 1.00 STMILL P WEXIT COMBINED RIG EVACUATION DRILL WITH PBOC EMERGENCY RESPONSE TEAM. SIMULATED H2S IN PIT AREA WITH MAN DOWN. FIRE DEPARTMENT RESPONDED WITH PERSONNEL TO ENTER RIG,EVACUATE MAN DOWN AND CLEAR THE RIG. BOTH CREWS INVOLVED WITH EXERCISE. CONDUCTED RIG EVACUATION AND H2S AAR WITH RIG CREW. -LOG TIE-IN AND APPLY+2'DEPTH CORRECTION. 18:15 - 18:45 0.50 STMILL P WEXIT RIH TO 10498'TO CONTINUE MILLING CEMENT PILOT HOLE. 18:45 - 21:05 2.33 STMILL P WEXIT BACK ON BOTTOM TO MILL CEMENT PILOT HOLE FROM 10498'TO 10540'. FREE SPIN=3070 PSI AT 1.65 BPM RATE IN=1.65-1.67 BPM RATE OUT=1.62- 1.67 BPM ROP=12-18 FPH WOB=1.00-1.60 K CIRC PSI=3250-3300 PSI MW IN=8.47 PPG MW OUT=8.45 PPG ECD =9.88 PPG IAP=471 PSI OAP=7 PSI PVT=291 21:05 - 21:15 0.17 , STMILL P WEXIT POOH AT 20 FPM FROM 10540'TO 10345'. 21:15 - 21:50 0.58 STMILL P WEXIT ORIENT TOOLFACE 45 DEG ROHS AND REAM FROM 10345'TO 10310'AT 1 FPM. 21:50 - 22:30 0.67 STMILL P WEXIT RIH FROM 10310'TO 10350'AT 5 FPM.ORIENT TOOLFACE 45 DEG LOHS AND REAM FROM 10350'TO 10310'AT 1 FPM. 22:30 - 22:50 0.33 STMILL P WEXIT RIH.LOG TIE IN.APPLY+1'DEPTH CORRECTION. 22:50 - 23:10 0.33 STMILL P ' WEXIT POH TO 10000'. 23:10 - 23:45 0.58 STMILL I P WEXIT LOG CCL FROM 10000'TO 10540'AT 1000 FPH. PUMP 15 BBL SWEEP DOWN COIL WHILE LOGGING CCL. 23:45 - 00:00 0.25 STMILL P t WEXIT POOH WITH PILOT HOLE MILLING BHA.PUMP AT 1.71 BPM W/3153 PSI AND CHASE HI VIS PILL.POOH FROM 10540'TO 10195'.FLOW CHECK.GOOD NO FLOW.OPEN EDC.POOH. 3/17/2014 00:00 - 02:00 2.00 STMILL , P WEXIT POOH FROM 10195'TO 61.09'AT 100 FPM. PUMP AT 2.30 BPM WITH 3318 PSI.FLOW CHECK-CONFIRM GOOD NO FLOW. 02:00 - 03:00 1.00 STMILL P WEXIT PJSM ON LAYING DOWN PILOT HOLE MILLING BHA#2.POP OFF WITH INJECTOR AND STAND BACK. LD PILOT HOLE MILLING BHA. -GAUGE MILL: 2.74"GO/2.73"NO GO -GAUGE STRING REAMER:2.73"GO/2.72"NO GO. MOBILIZE CALIPER TOOLS AND DUMMY WHIPSTOCK DRIFT TO RIG FLOOR. 03:00 - 04:00 1.00 EVAL P WEXIT PJSM ON MAKING UP CALIPER LOG BHA#3. MU CALIPER LOG BHA#3 WITH CALIPER LOGGING TOOL, 2.63"DUMMY WHIPSTOCK DRIFT,AND COILTRAK CONFIRM CALIPER ARMS FUNCTION PROPERLY.STAB ON WITH INJECTOR. PRESSURE TEST QUICK TEST SUB. 04:00 - 06:00 2.00 EVAL P WEXIT RIH WITH CALIPER LOG BHA#3 FROM 70.64'. Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 9 992,1 Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: TX3-012XR-C:(3,824,290.00) Project Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00 OOAM Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292209800 Active datum:69:4712/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 09:15 3.25 EVAL P WEXIT RIH WITH CALIPER AND 2.63"WHIPSTOCK DRIFT ASSEMBLY. DRIFT DOWN TO 10,530' WITH ASSEMBLY WITH NO ISSUES. RECIPROCATE NEAR BOTTOM WHILE WAITING ON ARMS TO OPEN. 09:15 - 09:45 0.50 EVAL P WEXIT FLOW CHECK AT BOTTOM. ALL GOOD. CALIPER ARMS OPEN,BEGIN LOGGING. LOG I,'UP AT 50 FPM WITH A 24-ARM CALIPER. 09:45 - 11:45, 2.00 EVAL P WEXIT 1POH WITH CALIPER AND DRIFT ASSEMBLY. FLOW CHECK WELL,ALL GOOD. PJSM FOR LAYING DOWN THE BHA. 11:45 - 12:15 0.50 EVAL P WEXIT POP OFF WITH INJECTOR. LD BHA. MOBILIZE CALIPER COMPONENTS OFF OF RIG. CLEAR AND CLEAN RIG FLOOR. 12:15 - 13:45 1.50 WHIP P WEXIT MOBILIZE WHIPSTOCK ASSEMBLY ONTO RIG. BAKER REP MAKE UP TOOL STRING IN PIPE SHED AND VERIFY SCRIBE IS HIGH-SIDE. PJSM ON MAKING UP ASSEMBLY. MU 2-5/8"X 3-1/2"X 5-1/2"MONOBORE WHIPSTOCK ASSEMBLY WITH RA PIP TAGS ONTO BHI SMART TOOLS. STAB ON WITH INJECTOR. -NOTIFIED BY PDS REP THAT DATA IS GOOD, BEING SENT TO HOUSTON FOR BUILDING FILE 13:45 - 16:30 2.75 WHIP P WEXIT PRESSURE TEST QUICK TEST SUB. RIH WITH WHIPSTOCK BHA. NO ISSUES RUNNING PAST FRAC SLEEVE AT 2200'. CONTINUE RUNNING DOWN TO 8700'WHEN RESULTS OF CALIPER LOG COME IN. DATA SHOWS THAT PILOT HOLE MAY BE 180°OUT. 16:30 - 18:20 1.83 WHIP N DPRB 10,490.00 WEXIT FLOW CHECK AT 8700',ALL GOOD. POH FOR IBHAINSPECTION WHILE ODE HAS CONSULTATION WITH TOWN TEAM FOR PLAN FORWARD. 18:20 - 18:40 ' 0.33 WHIP I N DPRB 10,490.00 � WEXIT •PERFORM FLOWCHECKAT SURFACE, ACHIEVE GOOD NO-FLOW.PULL BHA TO SURFACE. 18:40 - 20:30 1.83 WHIP N DPRB 10,490.00 WEXIT LD BAH#4,THEN FUNCTION-CHECK HOT AS WELL AS HIGH-SIDE SCRIBE.CANNOT IDENTIFY ANY ISSUES WITH SCRIBE,ALSO HOT IS CALIBRATED AND FUNCTIONS CORRECTLY,NO ISSUE HERE. DISCUSS NEW WHIPSTOCK SETTING DEPTH WITH ODE,GEO,DIRECTIONAL DRILLER AND BAKER HAND.SINCE 7-5/8" JOINT-CONNECTION CAN BE LOCATED AT 10,504',DECIDE TO ADJUST NEW WHIPSTOCK SETTING DEPTH TO 10,510'. 20:30 - 21:00 0.50 WHIP N DPRB 10,490.00 WEXIT HOLD PJSM,THEN MU WHIPSTOCK RUNNING BHA(BHA#5)INCLUDING 2-5/8"X 3-1/2"X 5-1/2"MONOBORE WHIPSTOCK ASSEMBLY WITH RA PIP TAGS AND BHI SMART TOOLS (BHA#5 IS IDENTICAL TO BHA#4). 21:00 - 2125 0.42 WHIP N DPRB 10,490.00 WEXIT STAB ON INJECTOR AND PRESSURE-TEST QTS TO 300 PSI/5 MINS AND 3,500 PSI/ 5MINS. 21:25 - 23:30 2.08 WHIP N DPRB 10,490.00 WEXIT 'COMMENCE RIH WITH BHA#5.PUMP AT •0.4BPM SEEING CIRC PRESSURE=1,234 PSI. PVT=273 BBLS. HAVE NO ISSUES RUNNING PAST FRAC SLEEVE. Printed 3/31/2014 11:37:40AM North America-ALASKA-BP Page 1041111 Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date. X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:30 - 00:00 0.50 WHIP N DPRB 10,490.00 WEXIT PERFORM TIE-IN LOG AND APPLY-15'DEPTH CORRECTION AT 10,485.70'. 3/18/2014 00:00 - 00:50 0.83 WHIP P WEXIT RIH TO 10486'.UNABLE TO ORIENT. PU ABOVE CEMENT PILOT HOLE TO 10199'. CONFIRM HOT IS FUNCTIONS CORRECTLY. ORIENT TOOLFACE TO 150 DEG ROHS. RIH AND POSITION COIL AT 10518.7'(BIT-DEPTH) WHICH PLACES TOP OF WHIPSTOCK AT 10510'(WHIPSTOCK LENGTH:8.73').CONFIRM WHIPSTOCK ORIENTATION IS 150°ROHS. PICK UP TO BRING COIL IN TENSION,CLOSE EDC AND BRING ON PUMPS.OBSERVE PRESSURE-DROP AT 4190 PSI CIRC PRESSURE.SLACK OFF-4 KLBS CT WEIGHT ON WHIPSTOCK TO CONFIRM WHIPSTOCK IS PROPERLY SET-NO MOVEMENT OBSERVED. 00:50 - 03:15 2.42 WHIP P WEXIT POOH WITH WHIPSTOCK SETTING BHA#5. FLOW CHECK PRIOR TO PULLING BHA ACROSS STACK-CONFIRM GOOD NO FLOW. 03:15 - 03:45 0.50 WHIP P WEXIT PJSM.LD WHIPSTOCK SETTING BHA#5. 03:45 - 04:10 0A2 STWHIP P WEXIT PJSM.MAKE UP WINDOW MILLING BHA#6. -GAUGE MILL: 2.75"GO/2.74"NO GO -GAUGE STRING MILL:2.74"GO/2.73"NO GO. -MU MILLING BHA WITH 2.75"DIAMOND PARABOLIC MILL,2.74"STRING REAMER, X-TREME M1XP MOTOR W/0.6°AKO,FLOATS, AND COIL TRAK.RIH TO 60.82' 04:10 - 04:30 0.33 STWHIP P WEXIT STAB ON WITH INJECTOR AND PT QUICK TEST SUB.250 PSI LOW/3500 PSI HIGH. GOOD TEST. 04:30 - 06:00 1.50 STWHIP P WEXIT RIH W/WINDOW MILLING BHA#6.PUMP AT 0.4 BPM W/1,069 PSI CIRCULATING PRESSURE.PVT=274 BBLS. 06:00 - 08:30 2.50 STMILL P WEXIT RIH WITH MILLING ASSEMBLY TO 10,450' 08:30 - 09:15 0.75 STMILL P WEXIT LOG TIE-IN WITH-15'CORRECTION. RECORD SLOW PUMP RATES. DOWN ON PUMPS AND DRY TAG WHIPSTOCK AT 10,515.5'. PICK BACK UP,PUW 30 K. BRING ON PUMPS TO 1.7 BPM. Printed 3/31/2014 11:37:40AM a North America-ALASKA-BP Page 11464 Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00 @52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 09:15 - 18:00 8.75 STMILL P WEXIT FREE SPIN OF 3070 PSI AT 1.7 BPM. MOVE DOWN WITH PUMPS ON AND TAG WHIPSTOCK AT 10,515'. ,-BEGIN MILLING FROM 10,510'AT 1.7 BPM, Lk lrLtl'A 13280 PSI,.4 K WOB HOLDING A 150° ORIENTATION. TIME MILL INITIAL FOOT AT 1 FPH USING.4-.6 K WOB INITIALLY,WORKING UP TO 1.6K WOB AT END OF FIRST FOOT. -WOB INCREASED FROM 1.6K TO 2.0K AT 1-1/2'IN. AT 1-1/2',WOB INCREASED TO 2.25K,MAINTAINING 3300 PSI. CONSISTENTLY TAKING 1.8-2.3K WITH EVERY TENTH FROM 1.8'AND ON -CONTINUE WITH TIME MILLING WITH WOB CONSISTENTLY MAINTAINED AT 2.3K INITIAL AND FALLING TO 1.6K AT FINAL BEFORE MOVING TO NEXT 1/10TH. -MAINTAINING TIME MILL OF A TENTH EVERY 6 MINUTES,INITIAL WOB 2.4K FALLING TO 1.6-1.7K WITH EACH TENTH -CALCULATE MIDPOINT AT 4.4'INTO MILLING OPERATION. WOB BEGAN TO REDUCE AT 5' INTO MILLING OPERATION AND CIRCULATING PRESSURES INCREASED. AT 5.1',INITIAL WOB IS 1.6KAND FELL OFF TO 1.1KAS MILL DRILLED OFF THE 1/10TH,INDICATING THAT BHA IS INTO OPEN HOLE. -CONTINUE MILLING PER TIME SCHEDULE OF 2 FPH WITH REDUCED WOB SO THAT STRING REAMER WILL CLEAN UP WINDOW AND KEEP IT IN GAUGE 18:00 - 20:30 2.50 STMILL P WEXIT MILLING OPERATIONS CONTINUING VERY SMOOTHLY.CONTINUE TIME MILLING ATA TENTH EVERY 6 MINUTES WHILE WORKING STRING REAMER THROUGH WINDOWAT 10,517'TO 10518'.INITIAL WOB=0.35- 0.51 KLBS,FINAL WOB=0.15-0.24 KLBS WITH EACH TENTH. -AS STRING REAMER CLEARED WINDOW, CONTINUE TO MILL INTO OPEN FORMATION. INCREASED WOB TO 1.20-1.60 KLBS.PUMP AT 1.70 BPM WITH 3150 TO 3260 CIRCULATING PRESSURE. -MW IN=8.48 PPG;MW OUT=8.46 PPG. -MILL TO 10522'IN NEW FORMATION,PUMP UP SAMPLES FOR GEO. 20:30 - 21:35 1.08 STMILL P WEXIT MAKE FIRST REAM PASS THROUGH WINDOW 1 FPM AND 1.69 BPM WITH 3150 PSI. OBSERVE MINOR DIFFERENTIAL MOTOR WORK SPIKES AT 10514'AND 10511'-10510'. CONTINUE UP UNTIL ASSEMBLY FULLY ABOVE WHIPSTOCK. -RIH THROUGH WINDOW AND MAKE SECOND REAM PASS UP THROUGH WINDOW AT 1 FPM AND 1.73 BPM WITH 3240-3270 PSI. OBSERVE MINOR MOTOR WORK THROUGH WINDOWAT SAME DEPTHS. -RIH THROUGH WINDOW WITH NO ISSUES AND MAKE THIRD REAM PASS UP AT 1.73 BPM WITH 3220-3270 PSI. OBSERVE MINOR MOTOR WORKAS WITH SECOND PASS. Printed 3/31/2014 1:06:37PM 4 North America-ALASKA-BP Page 1 2.dgert Operation Summary Report Common Well Name:09-47 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/8/2013 End Date: X3-012XR-C:(3,824,290.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:NORDIC 1 Spud Date/Time:12/4/1990 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292209800 Active datum:69:47 12/4/1990 00:00©52.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:35 - 21:40 0.08 STMILL P WEXIT PULL ABOVE WHIPSTOCK,DOWN ON PUMPS AND CONDUCT DRY DRIFT 10522'WITH NO ISSUES. PICK BACK UP THROUGH WINDOW WITHOUT PUMPS,AGAIN NO ISSUES.BRING ON PUMPS TO 1.60 BPM,RIH THROUGH WINDOW WITH NO ISSUES. PUMP HI-VIS SWEEP OFF BOTTOM TO CLEAN UP ANY METAL DEBRIS. CIRCULATE UP,PICK UP OFF BOTTOM CLEAN. -CHECK TREE BOLTS,ALL GOOD 21:40 - 22:00 0.33 STMILL P WEXIT POOH WITH WINDOW MILLING BHA#6 FROM 10522'TO 10200'AT 30 FPM.FLOW CHECK- CONFIRM GOOD NO FLOW. 22:00 - 23:30 1.50 STMILL P WEXIT OPEN EDC.POOH FROM 10200'TO 250'. FLOW CHECK PRIOR TO PULLING BHA ACROSS STACK. 23:30 - 00:00 0.50 STMILL P WEXIT PJSM FOR LD OF MILLING BHA.POP OFF WITH INJECTOR AND STAND BACK.BLOW DOWN BHA.LD WINDOW MILLING BHA#6. GAUGE MILL:2.74"GO/2.73"NO-GO STRING MILL:2.74"GO/2.73"NO-GO 3/19/2014 00:00 - 01:30 1.50 DRILL P PROD1 MU 2.70"X 3.0"BUILD BHA#7 W/BHI ULTRA X/LS MOTOR W/2.5°AKO AND COIL TRAK. STAB ON WITH INJECTOR AND PT QTS 250 PSI LOW/3500 PSI HIGH. • 01:30 - 03:15 1.75 DRILL P PROD1 OPEN EDC.RIH W/3.0"BUILD DRILLING BHA #7 TO 7500'. C-CAT SYSTEM STOPPED WORKING. STOP, TROUBLESHOOT AND REBOOT SYSTEM. 03:15 - 03:50 0.58 DRILL P PROD1 RIH FROM 7500'TO 10200'. BRING DOWN PUMPS TO 0.34 BPM W/1140 PSI CIRCULATING PRESSURE FOR RUNNING THROUGH PILOT HOLE.RIH AT 30 FPM FROM 10200 TO 10450'. 03:50 - 04:20 0.50 DRILL P PROD1 LOG TIE IN FROM 10450'TO 10493'. APPLY -15'DEPTH CORRECTION. 04:20 - 04:30 0.17 DRILL P PROD1 RIH.SLOW DOWN TO 5 FPM WHEN PASSING THROUGH WINDOW.NO ISSUES.DRY TAG BOTTOM AT 10524' 04:30 - 06:00 1.50 DRILL P PROD1 DIRECTIONAL DRILL AHEAD IN 4.50"BUILD SECTION FROM 10522'.PERFORM MUD SWAP WHILE DRILLING AHEAD. FREE SPIN:2915 PSI AT 1.65 BPM ROP=3-20 FPH,WOB=1.24-1.58 K LBS, CIRC PRESSURE=3080-3285 PSI @ 1.65- 1.71 BPM MM IN / MM OUT=1.65-1.71 BPM MW IN=8.46 PPG / MW OUT=8.45 PPG Printed 3/31/2014 11.37.40AM r- TRS= 4-1/16"CIW FLS 0 9�4 WELLHEAD= FMC SAFETY NOTES: ACTUATOR= BAKER C OKB.ELEV= 52' BF.ELEV= CONDUCTOR —I ? — KOP= 900' Max Angle= 40°@ 2500' 2219' 14-1/2"CAMCO BAL-O SSSV NIPw/STUCK Datum MD= 10486' CD 1 FRAC SLV(SET 06/05/91),ID=2.75" Datum TVD= 8800'SS 11-1/2"EXT CSG SLV-EXTENDS 3-1/2"BELOW — 114' \ 3284' —14-1/2"X 3-1/2"XO,ID=2.992" STARTING HEAD, CONDUCTOR REMOVED GAS LIFT MANDRELS FROM STARTING HEAD DOWN 11'10-1/2"(1/31/14) ST NDd17 DEV TYPE VLV LATCH FORT DATE 4-1/2"TBG-IPC, 12.6#,L-80 BTC MOD, H 3284' Li, �I 1 3383 3008 36 Iv1VK3 DMY RK 0 10/18/11 .0152 bpf,U=3.958" 2 6076 5202 39 MNG DMY RK 0 10/18/11 1 3 7825 6630 35 MMG DMY RK 0 10/18/11 10-3/4"CSG,45.5#,J 55,ID=9.953" —I 4009' 4 8712 7371 33 MUG DMY RK 0 12/20/90 5 9289 7851 34 MAG DMY RK 0 12/20/90 6 9714 8205 33 MIG DMY RK 0 03/04/14 Minimum ID =2.75" @ 2219' 7 10134 8556 35 MMS EQ DMY RK 0 12/20/90 FRAC SLV INSIDE 4-1/2" SSSV NIP 10215' H 3-1/2"BKR GBH-22 LOC SEAL ASSY,ID=3.00" M� �� 10216' —I7-5/8"X 3-1/2"BKR FB-1 PERM PKR ID=? \ 10234' H 5-112"MILLOUT EXTENSION,ID=5.00" 10239' I-15-1/2"X 3-1/2"XO,ID=2.992" TOC(01/22/13) — 10280' 10308' —I 3-112"OTIS XN NIP,ID=2.75" 3-1/2"TBG IPC,9.3#,L-80 EUE 8RD MOD, H 10316' ii' m r � 10315' —{3-1/2"BKR SOLID NOSE SHEA ROUT SUB .0087 bpf,ID=2.992" , 10316' H3-1/2"TT/WLEG,ID=2.992" 10304' --I ELMD TT LOGGED 03/20/91 PERFORATION SUMMARY RQ-LOG: DIL ON 12/18/90 ANGLE AT TOP PERF:33°@ 10444' )>404 -....",:::y/•"' Note:Refer to Production DB for historical pert data • . SIZE SPF INTERVAL Opn/Sqz SHOT SQZ t;• 2-1/2" 2 10444-10448 S 03/20/92 01/22/13 10510' H WHIPSTOCK(03/18/14) 2-1/2" 2 10456-10468 S 03/20/92 01/22/13 { ♦r. 2-1/2" 2 10492-10504 S 03/20/92 01/22/13 • , �ilsi 10540' -I MLLED CEMENT(03!16/14) 2-1/2" 2 10518-10524 S 03/20/92 01/22/13 r------10 2-1/2" 2 10530 10534 S 03/20/92 01/22/13 2-1/2" 2 10556-10560 S 03/22/92 01/22/13 2-1/8" 6 10586-10590 S 03/19/95 01/22/13 2-1/8" 6 10598-10603 S 11/15/95 01/22/13 ; 2-1/8" 4 10618-10632 S 11/15/95 01/22/13 .;4;10** 2-1/8" 4 10640-10658 S 11/15/95 01/22/13 5......44. 2-1/8" 4 10666-10686 S 08/17/91 01/22/13 ;. ,': %:,x' 10839' —FISH-(2)4"ELEMENTS FROM R PKR STIM(LOST 08/22/96) PBTD —1 10750' 1111111111 7-5/8"CSG,29.7#,L-80,ID=6.875" 10833' 111111111111111111 11111111111111111111 44 ttattt• Al TD H 10844' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/20/90 N28E INITIAL COMPLETION 03/11/14 JA/PJC SET EXT CSG SLV WELL:139-47 01/29/13 JJL/JMD CMT SQZ/P&A PRE CTD 03/11/14 DU/PJC TRII C/O(03/01/14) PERMIT No: 1901460 09/10/13 TJI-/JMD SET WRP/GLV CJO(08/21/13) 03/12/14 LEF/PJC PULL WFD API No: 50-029-22098-00 11/09/13 PJC CMT SQZ DATE CORRECTION SEC 1,T1ON,R15E,1170'FSL&113'FWL 01/22/14 PJC PRE RIG UPDATE 03/04/14 LEF/PJC GLV C/O BP Exploration(Alaska) • • \ �//7: 4\ STATE Alaska Oil and Gas N�-- � °fALAS� Conservation Commission i GOVERNOR SEAN PARNELL 333 West Seventh Avenue .- Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 CiF ` , Jessica Sayers Sat41451 Well Intervention Engineer Q — 14-Co BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09-47 Sundry Number: 313-421 Dear Ms. Sayers: 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. F•erster // Chair DATED this I w day of August, 2013. Encl. - STATE OF ALASKA V( ALASOOIL AND GAS CONSERVATION COMMIION 117 4 AUG 09 201: APPLICATION FOR SUNDRY APPROVAL °TS iris/,t-3 20 AAC 25.280 AOGCC 1. Type of Request: ❑Abandon ❑Plug for Redrill ❑Perforate New Pool ❑Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate ❑Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ❑Alter Casing ®Other. Surface Casing Repair • 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 190-146 , 3. Address: ® Development ❑Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-22098-00-00 ' 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 09-47 • Will planned perforations require a Spacing Exception? ❑Yes ®No 9. Property Designation 10.Field/Pool(s): ADL 028327&028345' Prudhoe Bay/Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10844' . 9153' , 10280' 8679' 10280'(TOC) 10839' Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 4009' 10-3/4" 4009' 3516' 3580 2090 Intermediate 10833' 7" 10833' 9143' 6890 4790 Production Liner Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): Squeezed: 10444'-10658' Squeezed:8817'-8997' _ 4-1/2", 12.6#x 3-1/2", 9.3# L-80 10316' Packers and SSSV Type: 7-5/8"x 3-1/2"Baker FB-1 Permanent Packer Packers and SSSV 10216'/8625' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ❑BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: August 15,2013 . ®Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ❑Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jessica Sayers,564-4281 Printed Name: Jessica Sayers Title: Well Intervention Engineer Email: Jessica.Sayers @bp.com Signature: C�L't 1/ Phone: 564-4281 Date: °12 1 10`2 J Commission Use Only Conditions of ap val: Notify Commission so that a representative may witness Sundry Number 3 '"cta' ❑Plug Integrity ❑BOP Test ❑Mechanical Integrity Test ❑Location Clearance p p 2013-),' Other: I k RiBr> L OCT 1 0 ph67 f-0 eve�w7r� f rt-p Spacing Exception Required? ❑Yes [y]No Subsequent Form Required: /( — 1 0 4 {� —/� APPROVED BY l Approved By: / i COMMISSIONER THE COMMISSION Date: /3 Form 10-403 Revised 1,J/2012 Appro,�a�a o i 1 r 12 months from the date of approval Submit In Duplicate ' .,, V c 9/91/3 V Rt� I I V H L ,�eM) t • • by Date: August 2, 2013 To: AOGCC From: Jessica Sayers, Well Intervention Engineer Subject: Sundry Notice 10-403 Approval Request BPXA Well 09-47 This application for Sundry approval for BPXA Well 09-47 is for the inspection and 7 repair of surface casing. Currently, part of the surface casing on this well is exposed to atmosphere, most likely as a result of corrosion. 09-47 has been determined to have a surface casing leak at an estimated 5 feet from surface. BPXA requests approval to inspect and repair the surface casing. With approval, inspection and repair of the surface casing will follow the general, outlined procedure below: 1. Secure the well from the reservoir with plug(s), kill weight fluid and BPV. 2. Remove the cellar, wellhouse, tree, flowline and other equipment necessary for repair. 3. Survey existing utilities and other critical infrastructure, including the wellhead. 4. Drive piles to support the wellhead and well support frame. Drive sheet piling for excavation around well. 5. Install wellhead and well support frame. 6. Excavate inside the parameters of the sheet piling, to a bottom depth of 20 feet. 7. Install nitrogen purge equipment for conductor (and OA if needed) so that hot work may be conducted in a safe manner. 8. Cut windows in the conductor casing and remove cement from the outside of the surface casing for inspection. Remove additional conductor as necessary. Notify AOGCC inspector for opportunity to inspect. 9. Install repair patch needed to return the casing to operational integrity. ✓ 10.Patch will be inspected for acceptance. 11.Perform MIT-OA. 12.Install external wrap on casing to safeguard against future, potential corrosion. 13.Backfill and compact around well and install cellar. 14.Demobilize wellhead and well support frame. 15.Reinstall tree, flowline and wellhouse. Remove plug(s), BPV and hand well over to well integrity for evaluation. 16.File 10-404 with AOGCC post repair, complete with pictures demonstrating repair. 1 RECEIVED • STATE OF ALASKA • Mil:1-' 1 '` 20 ALASKA OIL AND GAS CONSERVATION COMMISSION••►, WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ® Suspended ' 1b. Well Class 20AAC 25.105 20AAC 25.110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Co . pletions Zero • ® Development ❑ Service 2. Operator Name: 5. Date Comp , Sus or Aban : 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 1/21/2013 190 - 146 • 312 - 477 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 12/4/1990 50 - 029 - 22098 - - - 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 12/17/1990 PBU 09-47 • 1170' FSL, 113' FWL, Sec. 01, T1ON, R15E, UM 8. KB (ft above MSL): 52' • 15. Field / Pool(s) Top of Productive Horizon: 2607' FNL, 89" FWL, Sec. 06, T1ON, R16E, UM GL (ft above MSL): 19.67' Prudhoe Bay / Prudhoe Bay , Total Depth: 9. Plug Back Depth (MD +TVD) 2584' FNL, 128' FWL, Sec. 06, T1ON, R16E, UM 10280' 8679' 4b. Location of Well (State Base Plane Coordinates, NAD : 10. Total Depth (MD +TVD) 16. Property Designation. Surface: x- 718499 • y- 5942641 • Zone- ASP4 • 10844' 9153' • ADL 028327 & 028345 TPI: x- 723532 y- 5944290 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 723748 y 5944320 Zone- ASP4 None 18. Directional Survey: El 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: GR / SP / DIL / BHCS, GR / CNL / LDT, CET / CBT / GR, Gyro N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H - 40 Surface 115' Surface 115' 30" 40 sx Arctic Set Cement 10 -3/4" 45.5# J -55 Surface 4009' Surface 3516' 13 -1/2" 1335 sx CS III, 3220 sx Class 'G', 300 sx CS II 7' 29.7# L -80 Surface 10833' Surface 9143' 9 - 7/8" 127 Bbls MTC, 275 sx ARC Cement, 225 sx Cs 24. Open to production or injection? ❑ Yes ® 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): 4-1/2", 12.6#x3-1/2"9.3#, L -80 10316' 10216' / 8625' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. scAtaED APR c� 213 WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ❑ No 3 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 10280' 30.5 Bbls Class 'G' Cement 27. ' ' PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested Production For OIL -BBL: GAS -MCF: WATER-BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes ® No • Sidewall Core(s) Acquired? ❑ Yes ® No • If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS MAR 15 2013 Form 10 -407 Revised 10/2012 � ONTINUED ON REVERSE , Original Only I t // 4 3 ,may, / 6 4. y4- t3 G 129. GEOLOGIC MARKERS (List all formations arkers encounter 30. FORMATION TESTS ! NAME TVD Well Tested . Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Colville Mudstone 9641' 8144' None HRZ 10175' 8590' Top Sadlerochit 10443' 8816' i Base Sadlerochit 10686' 9020' Formation at Total Depth: 31. List of Attachment: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Email: Ron.Phillips @bp.com Ron Phillips, 564 -5913 Printed Name: Jo fka Title: Drilling Technologist Signature: � � Phone 5644091 Date: 3/ 1 3 13 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 10/2012 Submit Original Only • • 09 -47, Well History (Pre Rig Sidetrack) Date Summary 12/20/12 DRIFTED W /5' X 2.25" DRIVE DOWN BAILER TO HARD BOTTOM @ 10,617' SLM / 10,633' ELMD (Recovered small sample of asphaltenes). RAN SBHPS AS PER PROGRAM - (good data). 12/26/12 T /I /O =SSV /200/0, Temp =S1. PPPOT -T (PASS), pre CTD. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (ET), all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 01/21/13 CTU #9 w /1.75 "CT. Job Objective: Plug and Abandon (Pre -CTD). RIH w/ 2" BDN. Bullhead 200 bbls of 1% KCI followed by 105 bbls of diesel for underbalance. Tag TD at 10,649'CTM. Spear in w/ 5 bbls FW, lay in 30.5 bbls of 16.7 ppq Class G Cement at 1:1 taking returns to 40 bbl OTT, diplace w/ 30 bbls of • FW. Well locked up almost immediately. PUH to safety. Bump up WHP to 1000 psi sqz pressure. Achieve sqz pressure and hold for 15 minutes. Minimal losses. Cmt plug in place. Circulate 3/4" ball down CT w/ 50 bbls of 1.5# Biozan. Make 3 contamination passes from WCTOC at 8600'MD to 5' above est TOC at 10,280'MD. 01/22/13 CTU #9 w /1.75 "CT. Job Objective: Plug and Abandon (Pre -CTD). Leave TOC at — 10,280'MD. Chase OOH at 80% w/ 1% Slick KCI. Wash mandrels. FP to 2500' w/ 60/40. Wash BOPs. Begin RD. Wait on weather to lower mast. 01/29/13 UNABLE TO DO JOB DUE TO LEAK TIGHT TEST FAILED. { 02/03/13 TAGGED TOP OF CEMENT @ 10257' SLM W/ 2.50" CENT. S.BAILER. 02/04/13 DRIFTED THROUGH FRAC SLEEVE WITH 2.74" x 6' LONG DRIFT. RAN LIB TO 2187' SLM. IMPRESSION OF 4 -1/2 G- FISHING NECK. UNABLE TO DRIFT THROUGH FRAC SLEEVE WITH 2.77' OR 2.80" DRIFT. TAG CEMENT @ 10267' SLM W/ 2.74" WRP DRIFT W/ 2.75" SWAGE. 02/10/13 T /1 /0= 380/350/0; Conduct PJSM; Start barriers list= MV & SSV independently bled off, LTT passed; Rig up Lubricator with BPV and setting tool; Test to 300 and 3500 psi for 5 min. LTT passed; Open barriers and set 4- 1/16" FMC "ISA" BPV #545 thru tree for Nordic 1 Pre -CTD torque & test; 1 -1' ext. used, tagged at 96 "; Bleed off tree and torque tree flanges to API specs using 32 -023 lube van equipment calibrated 2/10/13; No movement on any studs; S/I barriers and install pulling tool, retest lubricator to above criteria; Open barriers and pull BPV; S/I barriers and replace BPV with TTP #530; Retest lubricator to above criteria, open barriers and set TTP; S/I barriers and replace setting tool with pulling tool, retest lubricator to above criteria; Open barriers and Shell test tree to 700 and 5000 psi for 5 min. LTT passed and charted; Pull TTP, S/I barriers and install tree cap; Test SV to 300 and 3500 psi for 5 min. LTT passed and charted; RDMO. 02/16/13 T /I /O =SSV /310/0. Temp =S1. IA & OA FL (FB request). AL spool dropped. IA has integral installed = inspection current. IA & OA FL near surface. Cellar is full of ice and @ the 12'0 clock position has heaved up and lifted the grating. Unable to verify OA valve position. SV, WV, SSV =C. MV =O. IA =OTG. OA = ? ?. NOGVP. 0400. 02/16/13 T /I /0 = SSV /310/0. Temp = SI. WHPs IEval Glaciation). AL spool dropped. Cellar full of ice & OA casing valve half engulfed in ice Installed heater in well house. Tree cap bled to 0 psi. SV, WV, SSV = C. MV = 0. IA = OTG. NOVP. 09:00 hrs. Page 1 of 2 • • 09 -47 Well History (Pre Rig Sidetrack) Date Summary 02/17/13 T /I /O = SSV /310/0. Temp = SI. Thaw for MIT -OA (Sample, vac cellar). AL spool dropped. IA has integral installed = inspection current. Cellar is full of water & ice. Heater in well house working, called for vac truck. Sample to lab. Unable to verify OA valve position. SV, WV, SSV = C. MV = O. IA , OA = OTG. 0830. 02/19/13 T /I /O = SSV /300/0 +. Temp = SI. WHPs (Thaw for MIT x OA). AL disconnected. IA has integral installed = inspection current. Cellar is thawed, no standing fluids. Heater in well house working. OA valve is verified open. SV, VW, SSV = C. MV = O. IA , OA = OTG. 0830 hrs. 02/20/13 T /I /O= 306/310/0 Temp. - SI (Pre -CTD) MIT T to 2500 psi. FAILED six times,rig up to IA, MIT -IA to 3000 PASSED lost 101 and 30 psi took 5.6 bbls crude to reach test pressure bleed IA back to 500 rig up to OA PT lines. %.)%r _ e7 v 02/21/13 MIT -OA to 2000 Pumped 13.6 bbls crude into OA fluid started coming out of flutes shut down pump bleed d , S (! OA pressure down to 0 called supervisor,area authority,spill response,WIE monitor OA pressure stayed at 0 rig down (swab closed wing closed ssv closed master open annulus valves open to gauges) 'T, t Ul F WH P= 866/572/0. 02/21/13 T/I/0 = SSV /600Nac. Temp = SI. Assist LRS w/ MIT -OA. (Eval possible SC leak). AL spool dropped. IA FL @ surface. OA FL near surface. Surface casing leak confirmed. See log for details. Final WHPs = a SSV /565Nac. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:40. �.ti`t' 02/21/13 T /I /O =ssv /534 /vac Temp =Sl MIT OA 2000 psi FAILED (Pre -CTD) Pumped 1.3 bbls of -30` diesel to reach 20 psi fluid to service @ the ready w /dirty vac trk Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp's =ssv /565 /vac. Page 2 of 2 • • ACTTUATORR = OTIS • 9 -47 SAFETY NOTES: KB. E EV = 52' MI BF. ELEV = 2219' 4-1/2" CAMCO BAL -O SSSV NP w / STUCK 900' � KOP = 90a pig r FRAC SLV (SET 06/05/91), V= 2.75' Max Angle = 40° @ 2500' Datum MB = 10486' 3284' H 4-1/2' X 3-1/2" XO, ID= 2.992" j ir k Datum ND = 8800' SS 4-1/2" TBG- PC, 12.6#, L -80 BTC MOD, 3284 ~ GAS LIFT MAICRELS ■ .0152 bpf, ID= 3.958" ST M) ND' DEV TYPE VLV LATCH PORT DATE 1 3383 3008 36 MG DMY RK 0 10118/11 110 -314' CSG, 45.5#, J-55, D = 9.953" H 4009' 2 6076 5202 39 MMG ❑IufY RK 0 10118111 3 7825 6630 35 NAG DMY RK 0 10/18/11 4 8712 7371 33 hili/G CMY RK 0 12/20/90 5 9289 7851 34 NAG DRAY RK 0 12/20/90 Minimum I D = 2.75" G 2219' 6 9714 8205 33 14/6 DMY RK 0 02/1N99 7 10134 8556 35 MMG EQ DRAY RK 0 12/20/90 FRAC SLV INSIDE 4 -1/2" SSSV NIP 10215' I - 13 - 1/2" BKR GBH-22 LAC SEAL ASSY, D = 3.00" I +� ��� 10216' H7 - 5/8 " X3- 1/2 " BKR FB- 1 FUN Fkli, ID =7 10324' I -j5 -1/2" MLLOUTEXTENSION, D = 5.00" I 10239' I 1 5-1/2' X 3-1/2" XO, ID = 2.992' ITOC (01/22/13) H 1 0280' I I 7 { 10308' H3-1/2" OTIS XN NP, D = 2.75" 10315' —13-1/2 BKR SOLD NOSE SI-EAROUF SUB I 3-1 TBGIPC, 9.3#, L-80 E E 8RD MDD IAC, —1 10316' 4 .0087 bpf, D = 2.992" 10316' —13-1/2" TUBING TAL, D = 2.992" I 10304' — 1 RM) TT LOGGLW 03/20/91 PL32FORATIDN SUMWIRY REF LOG: CIL ON 12/18/90 ANGLE AT TOP FEW: 33° @ 10444 Refe to Producon DB for htorical perf da SIZE SPF 14T VAL Opn/Sgz SHOT SQZ 2 -1/2" 2 10444 - 10448 S 03/20/92 01/21/13 -1/2' 2 10456- 10468 S 03/20/92 01/21/13 2 -1/2" 2 10492 - 10504 S 03/20/92 01/21/13 -1/2" 2 10518 - 10524 S 03/20/92 01/21/13 2 -1/2" 2 10530 - 10534 S 03/20/92 01/21/13 2 -1/2" 2 10556 - 10560 S 03/22/92 01/21/13 2 1/8" 6 10586- 10590 S 03/19/95 01/21/1 -1/8" 6 10598- 10603 S 11/15/95 01/21/13 2 1/8' 4 10618 - 10632 S 11/15/95 01/21/13 2 -1/8' 4 10640 - 10658 S 11/15/95 01/21/1 -1/8" 4 10666- 10686 S 08/17/91 01/21/13 X41► . 10839' FISH - (2)4" B_EME 1TS FROM (1 PKR STiM (LOST 08122196) PBTD I 10750' ref•WAY1'►' • 7 -5/8" CSG, 29.7 #, L-80, D = 6.875^ 1� •� •►•�•► •► •� •►•► •� • 4 I� 1083 •► ► ► ► ► ► ► ► ► ► ► ► ► ► ► ► ► ► 1 I TD I 10844' I ,••••••••• 44 DATE ' REV BY Cot I U fTS DATE REV BY COMu N S FRUDHOE BAY UNIT 12/20/90 ORIGINAL COMPLETION WELL: b9-47 09/02/02 BHC/TP FERF CORRECTIONS FERfuIT No: '1901460 01/02/11 PJC DRAWING CORRECTIONS AR No: 50 -029- 22098 -00 01/02/10 JOAN PJC GLV / SSSV CORRECTIONS SEC 1, T1ON, R15E, 1170' FSL 8113' FWL 11/08/11 TA/ PJC GLV CIO (10/18/11) 01/29/13 JJUJA43 GMT SQZ/P&A PRE CID I BP Exploration (Alaska) ' STATE OF ALASKA � R D ALAS�OIL AND GAS CONSERVATION COMMI ION APPLICATION FOR SUNDRY APPROVAL mx,,' i9 ZI['' 20 AAC 25.280 1. Type of Request: A "` "° ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ® Change Approved Program , ❑ Suspend ® Plug Perforations • ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit o ■ ' mnber BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 190 - 1 7 3. Address: 6. API t V • . Dev elopment 0 Service P.O. Box 196612, Anchorage, Alaska 99519 -6612 ► i : - 7. If perforating: 8. Well Name and N AV What Regulation or Conservation Order governs well spacing in this pool? , = U 0 7 Will planned perforations require a Spacing Exception? ❑ Yes No • 9. Property Designatior 10. Field / Pool(s): ADL 028327 & 028345 Prudho : :y / Prudhoe =ay 11. PRESENT WELL CONDITION SUMMARY , Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft) Effective Depth TV : i PI . •s ( as red): Junk (measured) 10844' • 9153' 10750' 9074 ` 1. l C) 10839' Casing Length Size MD b� A st Collapse Structural Conductor 115' 20" 115' 490 470 Surface 4009' 10 -3/4" - 4009' 6' c580 2090 Intermediate 10833' 7" 10833' :t 43' •890 4790 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): tTu.ing Size Tubing Grade: Tubing MD (ft): Squeezed: 10444' - 10658' Squeezed: 8817' - 8997' , 12 • x 3 2 ", 9.3# L -80 10316' Packers and SSSV Type: 7 -5/8" x 3-1/2" Baker FB -1 Permanent Pa ,7, Packers and SSSV 10216' / 8625' IP MD (ft) and TVD (ft): 12. Attachments: \ 3. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketc' ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for ' 15. Well Status after proposed work: Commencing Operation December 20, 2012 • ® Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ❑ Suspended 17. I hereby certify that the foregoing is true and correct to t,f be best of my knowledge. Contact: Ron Phillips, 564 -5913 Printed m Joe La: 1 - Title: Drilling Technologist Email: Ron.Phillips @bp.com A Signature: Phone: 564 4091 Date: ? /�,3 Commission Use Only i ' / Conditions of approval: Notify Commission so tha - representative may witness Sundry Number: l I (,/ ❑ Plug Integrity ❑ BOP Test ❑ Mechanic, Integrity Test ❑ Location Clearance I, Other: SCANNED MAR 21 ZO13 RBC®MS MAR 21 10' Spacing Exception Required? ❑ Yes 12(No Subsequent Form Required: APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: Form ] Q d Q/2Q1 Approved application is valid for 12 months from the date of approval Submit In Duplicate 04 K N A L m ,4'21/;12.s. .t. t • • 09 -47, Well History (Pre Rig Sidetrack) Date Summary 12/20/12 DRIFTED W /5' X 2.25" DRIVE DOWN BAILER TO HARD BOTTOM @ 10,617' SLM / 10,633' ELMD (Recovered small sample of asphaltenes). RAN SBHPS AS PER PROGRAM - (good data). 12/26/12 T /I /O =SSV /200/0, Temp =S1. PPPOT -T (PASS), pre CTD. PPPOT -T: Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (ET), all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. 01/21/13 CTU #9 w /1.75 "CT. Job Objective: Plug and Abandon (Pre -CTD). RIH w/ 2" BDN. Bullhead 200 bbls of 1% KCI followed by 105 bbls of diesel for underbalance. Tag TD at 10,649'CTM. Spear in w/ 5 bbls FW, lay in 30.5 bbls of 16.7 ppg Class G Cement at 1:1 taking returns to 40 bbl OTT, diplace w/ 30 bbls of FW. Well locked up almost immediately. PUH to safety. Bump up WHP to 1000 psi sqz pressure. Achieve sqz pressure and hold for 15 minutes. Minimal losses. Cmt plug in place. Circulate 3/4" ball down CT w/ 50 bbls of 1.5# Biozan. Make 3 contamination passes from WCTOC at 8600'MD to 5' above est TOC at 10,280'MD. 01/22/13 CTU #9 w /1.75 "CT. Job Objective: Plug and Abandon (Pre -CTD). Leave TOC at — 10,280'MD. Chase OOH at 80% w/ 1% Slick KCI. Wash mandrels. FP to 2500' w/ 60/40. Wash BOPs. Begin RD. Wait on weather to lower mast. 01/29/13 UNABLE TO DO JOB DUE TO LEAK TIGHT TEST FAILED. 02/03/13 TAGGED TOP OF CEMENT @ 10257' SLM W/ 2.50" CENT, S.BAILER. 02/04/13 DRIFTED THROUGH FRAC SLEEVE WITH 2.74" x 6' LONG DRIFT. RAN LIB TO 2187' SLM. IMPRESSION OF 4 -1/2 G- FISHING NECK. UNABLE TO DRIFT THROUGH FRAC SLEEVE WITH 2.77' OR 2.80" DRIFT. TAG CEMENT @ 10267' SLM W/ 2.74" WRP DRIFT W/ 2.75" SWAGE. 02/10/13 T /I /0= 380/350/0; Conduct PJSM; Start barriers list= MV & SSV independently bled off, LTT passed; Rig up Lubricator with BPV and setting tool; Test to 300 and 3500 psi for 5 min. LTT passed; Open barriers and set 4- 1/16" FMC "ISA" BPV #545 thru tree for Nordic 1 Pre -CTD torque & test; 1 -1' ext. used, tagged at 96 "; Bleed off tree and torque tree flanges to API specs using 32 -023 lube van equipment calibrated 2/10/13; No movement on any studs; S/I barriers and install pulling tool, retest lubricator to above criteria; Open barriers and pull BPV; S/I barriers and replace BPV with TTP #530; Retest lubricator to above criteria, open barriers and set TTP; S/I barriers and replace setting tool with pulling tool, retest lubricator Shell tree to 700 and 5000 psi for 5 min. LTT passed and to above criteria; Open barriers and She test p p P charted; Pull TTP, S/I barriers and install tree cap; Test SV to 300 and 3500 psi for 5 min. LTT passed and charted; RDMO. 02/16/13 T /I /O= SSV /310/0. Temp =SI. IA & OA FL (FB request). AL spool dropped. IA has integral installed = inspection current. IA & OA FL near surface. Cellar is full of ice and @ the 12'0 clock position has heaved up and lifted the grating. Unable to verify OA valve position. SV, WV, SSV =C. MV =O. IA =OTG. OA = ? ?. NOGVP. 0400. 02/16/13 T /I /0 = SSV /310/0. Temp = SI. WHPs IEval Glaciation). AL spool dropped. Cellar full of ice & OA casing valve half engulfed in ice Installed heater in well house. Tree cap bled to 0 psi. SV, WV, SSV = C. MV = 0. IA = OTG. NOVP. 09:00 hrs. Page 1 of 2 / • • 09 -47, Well History (Pre Rig Sidetrack) Date Summary 02/17/13 T /I /O = SSV /310/0. Temp = SI. Thaw for MIT -OA (Sample, vac cellar). AL spool dropped. IA has integral installed = inspection current. Cellar is full of water & ice. Heater in well house working, called for vac truck. Sample to lab. Unable to verify OA valve position. SV, WV, SSV = C. MV = 0. IA , OA = OTG. 0830. 02/19/13 T /I /O = SSV /300/0 +. Temp = SI. WHPs (Thaw for MIT x OA). AL disconnected. IA has integral installed = inspection current. Cellar is thawed, no standing fluids. Heater in well house working. OA valve is verified open. SV, WV, SSV = C. MV = 0. IA , OA = OTG. 0830 hrs. 02/20/13 T /1 /0= 306/310/0 Temp. - SI (Pre -CTD) MIT T to 2500 psi. FAILED six times,rig up to IA, MIT -IA to 3000 ✓, PASSED lost 101 and 30 psi took 5.6 bbls crude to reach test pressure bleed IA back to 500 rig up to OA PT lines. 02/21/13 MIT -OA to 2000 Pumped 13.6 bbls crude into OA fluid started coming out of flutes shut down pump bleed OA pressure down to 0 called supervisor,area authority,spill response,WIE monitor OA pressure stayed at 0 rig down (swab closed wing closed ssv closed master open annulus valves open to gauges) FWHP= 866/572/0. 02/21/13 T /I /O = SSV /600Nac. Temp = SI. Assist LRS w/ MIT -OA. (Eval possible SC leak). AL spool dropped. IA FL @ surface. OA FL near surface. Surface casing leak confirmed. See log for details. Final WHPs = SSV /565Nac. SV, WV, SSV = C. MV = 0. IA & OA = OTG. 17:40. 02/21/13 T /I /0 =ssv /534 /vac Temp =Sl MIT OA 2000 psi FAILED (Pre -CTD) Pumped 1.3 bbls of -30* diesel to reach 20 psi fluid to service @ the ready w /dirty vac trk Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp's =ssv /565 /vac. Page 2 of 2 • • Lastufka, Joseph N Subject: FW: 09 -47A Joe, Well 09 -47 is awaiting further diagnostics and repair before being placed back on the drilling schedule. Here is a list of the pre -rig work performed on 09 -47. Sundry number 312 -477. Jan. 21, 2013 Service coil laid in 30.5 bbls of 16.7ppg Class G Cement and squeezed to 1000psi for 15 minutes. They made three clean out passes to 10,280'. Feb. 04, 2013 Slickline drifted well down to 10,267'. Confirmed cement up into tubing tail. Feb. 20, 2013 MIT -T to 2500psi failed. MIT -IA to 3000psi passed. Feb. 21, 2013 MIT -OA to 2000psi failed, pumped 13.6bbls crude into OA and fluid starting coming out flutes. Confirmed surface casing leak. Thanks, Ron Phillips Coil Tubing Drilling Engineer Alaska Drilling & Wells Office (907) 564 -5913 Cell (907) 317 -5092 From: Phillips, Ron Sent: Thursday, February 28, 2013 8:53 AM To: Lastufka, Joseph N (Northern Solutions) Subject: 09 -47 Joe, Since 09 -47 (PTD# 1901460) was confirmed to have a Surface Casing leak to atmosphere during a MIT -OA performed on 02/21/2013. The well has been reclassified as Not Operable at this time. The well is currently shut in and freeze - protected. Due to ice road constrainsts the plan is to not drill 09 -47A this ice road season. Thanks, Ron Phillips Coil Tubing Drilling Engineer Alaska Drilling & Wells Office (907) 564 -5913 Cell (907) 317 -5092 1 r TREE' FMC • r a WLHEAD = FMC 09 -47 SAFETY NOTES: ACTUATOR = OTIS KB. aEV = 52' - BF. aEV = 2219' I4 -1/2" CAMCO BA L-0 SSSV NPw/ STUCK KOP = 900' a FRAC SLV (SET 06/05/91), D = 2.75" Max Angle = 40° @ 2500' Datum MD = 10486' I 3284' 1--I4 -112" X 3-1/2" XO, D = 2.992" Datum D = 8800' 4-1/2" TBG-FC, 12.6#, L -80 BTC MOD, —I 3284' GAS LFT MANDRELS .0152 bpf, D = 3.958" • ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 3383 3008 36 MMG DMY RK 0 10/18/11 J 110 -3/4" CSG, 45.5#, J-55, D = 9.953" I I 4009' 2 6076 5202 39 MMG DMY RK 0 10/18/11 3 7825 6630 35 MMG DMY RK 0 10/18/11 4 8712 7371 33 NAG DMY RK 0 12/20/90 5 9289 7851 34 MMG DMY RK 0 12/20/90 Minimum ID = 2.75" ^ 2219' 6 9714 8205 33 MMG DMY RK 0 02/13/99 V 7 10134 8556 35 MMG EQ DMY RK 0 12/20/90 FRAC SLV INSIDE 4 -1/2" SSSV NIP I 10215' H3-1/2" BKR GBH-22 LOC SEAL ASSY, D = 3.00" 1 1 *MI �� 10216' — 17 -5/8" X 3-1/2" BKR FB-1 PERM FKR, D = ? ITOC (01/22/13)1 10280' I 10324' —15-1/2" MLLOUT EXTHVSION, ID = 5.00" ------........ 10239' J 5-1/2" X 3-1/2" XO, D = 2.992" �„ } I 10308' H3-1/2" OTIS XN NP, D = 2.75" 1 1 + 10315' —13-1/2" BKR SOLID NOSE SI- AROUT SUB ( 3-1/2" TBG -PC, 9.3#, L -80 EUE 8RD MOD PC, —I 10316' fr. 4 4 .0087 bpf, D = 2.992" #'i ♦ 'er I 10316' H3-1/2" TUBNG TAIL, ID = 2.992" I 1► I 10304' H ELMD TT LOGGED 03/20/91 • • PERFORATION sUMNARY REF LOG: DL ON 12/18/90 • ANGLE AT TOP FERF: 33° @ 10444' '�i+4'4r Note: Refer to Production DB for historical pert data • ,11 SIZE SPF NTE VAL Opn/Sgz SHOT SQZ ,�� # R♦4 2 -1/2" 2 10456 - 10468 S 03/20/92 01/21/13 # #+F 2 -1/2" 2 10492 - 10504 S 03/20/92 01/21/13 . 2 -1/2" 2 10518 - 10524 S 03/20/92 01/21/131 ♦ 4 2 -1/2" 2 10530 - 10534 S 03/20/92 01/21/13 #+ 2 -1/2" 2 10556 - 10560 S 03/22/92 01/21/13 ►+►+ 2 -1/8" 6 10586 - 10590 S 03/19/95 01/21/13 + 4 4 2 -1/8" 6 10598- 10603 S 11/15/95 01/21/13 1 4 2 -1/8" 4 10618- 10632 S 11/15/95 01/21/13 # 2 -1/8" 4 10640 - 10658 S 11/15/95 01/21/13 4104�1 2 -1/8" 4 10666- 10686 S 08/17/91 01/21/13 C. 10839' 1 FISH - (2)4" aEMENTS FROM - 11;14; PKR STM (LOST 08/22/96) FBTD 10750' ■WATAWA 7 -5/8" CSG, 29.7 #, L -80, ID = 6.875" I 10833' ∎••••••A•1,• •* • 4 I TD — I 10844' DATE REV BY CONVENTS DATE REV BY CONVENTS FRIJDHOE BAY UNIT 12/20 /90 ORIGINAL COMPLETION WELL: '69 -47 09/02/02 BHC/TP PERF CORRECTIONS FERMT No: '1901460 01/02/11 PJC DRAWING CORRECTIONS API No: 50- 029 - 22098 -00 01/02/10 JCM/ PJC GLV/ SSSV CORRECTIONS SEC 1, T1ON, R15E, 1170' FSL & 113' FWL 11/08/11 TA/ PJC GLV C/O (10/18/11) 01/29/13 JJUJIVD CMTSQZ/P&A PRECTD BP Exploration (Alaska) • • Ferguson, Victoria L DOA) From: Lastufka, Joseph N [Joseph. Lastufka @bp.com) Sent: Wednesday, March 13, 2013 2:15 PM To: Ferguson, Victoria L (DOA) Subject: RE: PBU 09- 47(PTD 190 -146, Sundry 312 -477) Victoria, Please withdraw the current sundry application for 09 -47. �i�� 3 l l � ' I will submit a 10 -407 for Suspension tomorrow, if you have any questions or need additional information, please let me know. Thanks!! Joe From: Ferguson, Victoria L (DOA) { mailto :victoria.ferquson(&alaska.govl Sent: Wednesday, March 13, 2013 1:15 PM To: Phillips, Ron; Lastufka, Joseph N Subject: PBU 09- 47(PTD 190 -146, Sundry 312 -477) I have a new sundry(10 -403) you submitted on this well(313 -114) that includes plug work done under sundry 312 - 477(well history and schematic). This work should be included in a 10 -407 as subsequent to plug for redrill sundry 312- 477. Not sure why you submitted a new sundry Please let me know. Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a7alaska.gov 1 V OF Tk • 0� \ \�%% � s ?, THE STATE Alaska Oil and Gas �� ��� ®f � •- - onservation Commission z= , �' GOVERNOR SEAN PARNELL 333 West Seventh Avenue ,,, 0 , �. Anchorage, Alaska 99501 -3572 ALA Main: 907.279.1433 0 16 V Fax: 907.276.7542 John McMullen Engineering Team Leader / L J BP Exploration (Alaska), Inc. 1 . "F P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 09 -47 Sundry Number: 312 -477 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further.time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, 0 '' Daniel T. Seamount, Jr. Commissioner DATED this Zd day of December, 2012. Encl. • • STATE OF ALASKA • 4 ft4 w � E ' V D ALASKA OIL AND GAS CONSERVATION COMMISSION A , APPLICATION FOR SUNDRY APPROVAL0,' DEC 13 2012 20 AAC 25.280 AOGGC 1. Type of Request: ❑ Abandon ® Plug for Redrill • ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5 Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 190 -146 • 3. Address: ® Development. ❑ Service 6. API Numbe P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 22098 -00 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 09-47 • Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior • 10. Field I Pool(s): ADL 028327 & 028345 Prudhoe Bay / Prudhoe Bay • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10844' • 9153' 10750' • 9074' None 10839' • Casing Length Size MD TVD Burst Collapse Structural Conductor 115' 20" 115' 115' 1490 470 Surface 4009' 10 -3/4" 4009' 3516' 3580 2090 Intermediate 10833' 7" 10833' 9143' 6890 4790 Production Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10444' - 10658' . 8817' - 8997' 4 -1/2 ", 12.6# x 3 -1/2 ", 9.3# L -80 10316' Packers and SSSV Type: 7 -5/8" x 3-1/2" Baker FB -1 Permanent Packer Packers and SSSV . 10216' / 8625' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal BOP Sketch• ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development° ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation December 21, 2012 • ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Ron Phillips, 564 -5913 Printed Name: John McMullen Title: Engineering Team Leader Email: Ron.Phillips @bp.com tO 0 Tor(' " tAtir t v t (&,.r ,/� Signature: A 71 /" 1 / � (, Phone: 564 - 4711 Date: I Z - / 1 - 1 1 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry ^ - q-7-7 Sund Number: L ❑ Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance Other: --Y 3 50o p 5O t� e $f RRE MS DEC 21 2012 sz iin Spacing Exception Required? ❑ Yes b No Subsequent Form Required: /(- ( d 7 0 APPROVED BY / 9� /� Approved By: COMMISSIONER THE COMMISSION Date: / !J� Form 4 RRvr S mit In Duplica H Approved application is valid for 12 months from the date of a te � o� • • To: Alaska Oil & Gas Conservation Commission From: Ron Phillips p CTD Engineer Date: December 07, 2012 Re: 09 -47 Sundry Approval Sundry approval is requested for well 09 -47. HISTORY Well 09 -47 is a slant well drilled in 1990 targeting 13P — 26P intervals. The well was fraced in 1991 in the 14P. It screened out early. Analysis of the frac suggests that the frac length and extent is very limited. Post -frac and after additional perforations in zone 2, the well improved but still had 75% WC. Various add perfs and squeezes were performed throughout the well life to improve well performance, but with limited benefit. The well has been largely SI since 2008 due to poor performance. At this time no well work has been identified to improve the well performance, so a sidetrack to 09 -47A is ✓ considered the best utilization for this wellbore. REASON FOR SIDETRACK The well has been largely SI since 2008 due to poor performance. At this time no well work has been identified to improve the well performance, so a sidetrack to 09 -47A is considered the best utilization for this wellbore. PROPOSED PLAN The proposed plan for 09 -47 is to drill a pilot hole through a cement plug, set a 2 -5/8" OH Anchor whipstock in the pilot hole and drill a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing drilling rig. The existing perforations will be isolated by a cement plug to be laid in by service coil pre - rig as well as the primary cement job for the liner. The sidetrack, 09 -47A, will exit the existing 7 -5/8" liner and kick off and land in the Ivishak. This sidetrack will be completed with a 2 -3/8" liner in the production interval. The following describes the work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. J Ilse" co C( r � Lr lP45 /iere I concvl ► ti� w et( KG �eue' ` '1 leo! rU fivf�f`— .202 �� / 1`04 cl ail C ", tip vorh J� o a» Ca G° S 10 � 1 ,,C7eq fi l wee'( Cyr ohd 1 ,G 5104 deco - - ft l rgrJ C�h y,/�,e� 5 ' � -rite 0, e �l 40 �r 3o ap Pp with a l 'I 741'5 k-ell /h 6 ,,, 7 61 � ln � r re -rif s'or / d Q //a " `� ' ( r och f/ g (;,Y; • • Pre -Rig Work: (scheduled to begin December 21 2012) 1. F' MIT- IA to 3,000 psi, MIT -OA to 2,000 psi). ' 2. W Cycle LDS; PPPOT- T to 5,000 psi. 3. C Set 30 bbl, 17 ppg cement plug in the 7 -5/8" casing. Clean out down to 10,280'. 4. S Drift tubing down to 10,280' with 2.75" centralizer. 5. V PT MV, SV, WV. 6. F MIT -T to 2,500 psi. (Wait 24 hours for cement plug to set.) Bleed wellhead pressures ''. down to zero. 7. 0 Bleed production flow lines and gas lines down to zero and blind flange. 8. 0 Remove wellhouse, level pad. 3IZ -`1 OA Rig Work: (scheduled to begin on January 27, 2013) 1. MIRU and test BOPE to 250 psi low and 3,500 psi high. 2. Drill 2.75" pilot hole from top of cement at 10,280' down to 10,540' (50' Rat hole). 3. Calliper Pilot hole using PDC logging conveyed on coil. 4. Run dummy whipstock drift. Set 2 -5/8" OH anchor whipstock at 10,490' (Top of Whipstock) 5. Mill 2.74" window at10,490' and 10' of rathole. 6. Drill Build: 3" OH, 304' (19 deg/100 planned) 7. Drill Lateral: 3" OH, 2,341' (12 deg/100 planned) with resistivity 8. Run Triple Combo Open Hole Logs 9. Run 2 -3/8" 13CR-80 liner leaving TOL at 10,275' MD 10. Pump primary cement leaving TOC at 10,275' MD, 12 bbls of 15.8 ppg liner cmt planned PrD 11. Make a liner cleanout run. 12. MCNL /GR/CCL logging run. 13. Test liner lap to 2,400 psi 14. Perforate liner per asset instructions (-1,200') 15. Freeze protect well, set BPV, RDMO Post -Rig Work: 1. Set 3 -' /2" liner top packer, and test to 2,400 psi (if fails liner lap test) 2. Re- install wellhouse and FL's. 3. Generic GLV's 4. Test separator Ron Phillips CTD Engineer 564 -5913 CC: Well File Sondra Stewman/Joe Lastufka I r IC. NH LHEAD = FMC • 09-47 • keTUATOR = OTIS SAFETY NOTES: (B. ELEV = 52' 3F.ELEV= (�_ r, I 2219' I_ 4-1/2" CAMCO BAL -O SSSV NPw/ STUCK dax Angle = 40 @ 2500' FRAC SLV (SET 06/05/91), D = 2.75" Tatum MD = 10486' Datum ND = 8800' SS / I 3284' H4 -1/2" X 3-1/2" XO, D = 2.992" ND GAS LFT MARE.S 4-1/2" TBG-PC, 12.6#, L -80 BTC MOD, H 3284' 1ST MD TVD DEV TYPE VLV LATCH PORT DATE .0152 bpf, D = 3.958" I 1 3383 3008 36 MMG DONE RK 16 10/14/95 2 6076 5202 39 MMG DOME RK 16 10/14/95 10-3/4" CSG, 45.5 #, J-55, D = 9.953" H 4009' No 3 7825 6630 35 Mv1G SO RK 20 02/13/99 4 8712 7371 33 MNG DMY RK 0 12/20/90 5 9289 7851 34 WIG DMY RK 0 12/20/90 6 9714 8205 33 IVMG DMY RK 0 02/13/99 7 10134 8556 35 MMG EQ DMY RK 0 12/20/90 Minimum ID = 2.75" @ 2219' FRAC SLV INSIDE 4 -1/2" SSSV NIP I 10215' H 3-1/2" BKR GBH-22 LOC SEAL ASSY, D = 3.00" 11'= 10216' H 7-5/8" X 3-1/2" BKR FB-1 PERM PKR, D = ? 10324' H 5-1/2" FLOUT (EXTENSION, D = 5.00" I 10239' H5-1/2" X 3-1/2" XO, D= 2.992" I I 10308" H 3-1/2" OTIS XN NP, D = 2.75" 3-1/2" TBG -PC, 9.3#, L-80 BE 8RD MOD PC 10316' I 10315' H 3-1/2" BKR SOLD NOSE SHEAROUT SUB .0087 bpf, D = 2.992" 1—I ----______ 10316' H 3-1/2" TUBNG TAL, D = 2.992" I L 1 0304' H ELND TT LOGG® 03/20/91 I FEF FORATION SUMNARY FIEF LOG: DL ON 12/18/90 ANGLE AT TOP PERF: 33° % 10444' Note: Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE 2 -1/2" 2 '10444 -10448 0 03/20/92 I 2 -1/2" 2 10456 - 10468 0 03/20/92 2 -1/2" 2 10492 - 10504 0 03/20/92 2 -1/2" 2 10518 - 10524 0 03/20/92 I 2 -1/2" 2 10530 - 10534 0 03/20/92 2 -1/2" 2 10556 - 10560 0 03/22/92 I 2 -1/8" 6 10586 - 10590 0 03/19/95 2 -1/8" 6 10598 - 10603 0 11/15/95 2 -1/8" 4 10618 - 10632 0 11/15/95 I 2 -1/8" 4 10640 - 10658. 0 11/15/95 2 -1/8" 4 10666 - 10686 S 09/19/95 I— 10839' H FISH - (2)4" a vEtVTS FROM PKR STN (LOST 08/22/96) PBTD 10750' . v v 17 - 5/8" CSG, 29.7 #, L - 80, D = 6.875" H 10833' •••••••••••••••• •�•�•1 OW I TD I I 40844• I 11 * * *1t't•t,•* DATE REV BY COMMENTS DATE REV BY COM ENTS PRUDHOE BAY UNIT 12/20/90 ORIGINAL COMPLETION VVELL :'69 -47 09/02/02 BHC/IP FERF CORRECTIONS PERMIT No: 9901460 01/02/11 PJC DRAWN(' CORRECTIONS AR No: 50 -029- 22098 -00 01/02/10 JCM PJC GLV/ SSSV CORRECTIONS SEC 1, T1ON, R15E, 4895.15 FEL, 2585.68 FM- BP Exploration (Alaska) (RED — ' FIGIG NELLHEAD= FMC 09 -47A >, ACTUATOR= OTIS SAY NOTES: re Rig CTD Sidetrack B. B_B/ = 52' 3F.ELEV= • (OP= 900' 2219' 41/2" CAMCO BAL -O SSSV NPw/ STUCK Max Angle = 40 @ 2500' FRAC SLV (SET 06/05/91), D= 2.75" latumIvD= 10486' Tatum TVD = 8800' SS I 3284' H4 X 3-1/2" XO, D = 2.992" GAS LIFT MANDRELS 4-1/2" TBG -IFC, 12.6#, L -80 BTC MOD, H 3284' ST MJ TVD DEV TYPE VLV LATCH FORT DATE _0152 bpf, D= 1958" , 1 3383 3008 36 NMG DONE RK 16 10/14/95 2 6076 5202 39 MMG DOME RK 16 10/14/95 10-3/4" CSG, 45.5#, J-55, D = 9.953" 4009' Ir 3 7825 6630 35 MVG SO RK 20 02/13/99 4 8712 1,',' 1 33 MV1G DMY RK 0 12/20/90 5 9289 7851 34 WAG DMY RK 0 12/20/90 6 9714 8205 33 MMG DMY RK 0 02/13/99 7 10134 8556 35 WIG E Q DMY RK 0 12/20/90 10215'1 BKR GBH-22 LOC SEAL ASSY, ID= 3.00" ��� ��� 10216' — 17 - 5/8" X 3-1/2" BKR FB-1 PERM PKR, D = ? 10324' H 5 MLLOUT EXTENSION, ID = 5.00" 10239' H 2" X 3 - 1/2" XO, ID= 2.992" I Top of Pilot Hole Cement 10,280' MD (inside tubing tail) $ 4 110296' elm dl 13 1 /2 "O11SXN NP, D =2.75" I FERFORATION SUMMARY T �, 10315' — 3-1/2" BKR SOLD NOSE sHFAROUr SUB I REF' LOG: DL ON 12/18/90 ANGLEAT TOP PE RF: 33° @ 10444' l ,>7 . 10316' — 3-1/2" TBG -PC, 9.3#, L -80 E UE 8RD MOD IPC, %''�'» .0087bfD= 2.992" SIZE Refer PF to Prod� for historical � 2 110304' elm d H ELMD TT LOGGED 03/20/91 I 2 -1/2" 2 10444 - 10448 5 PRE RIG , 2 -1/2" 2 10456 - 10468 S PRE RIG 2 -1/2" 2 10492 - 10504 S PRE RIG' , "� , „ 2 -1/2" 2 10518 - 10524 S PRE RIG 2 -1/2" 2 10530 - 10534 S PRE RIG * . "` 2 -1/2" 2 10556 - 10560 S PRE RIG 0 2 -1/8" 6 10586 - 10590 S PRE RIG , 2 -1/8" 6 10598 - 10603 S PRE RIG , . 2 -1/8" 4 10618- 10632 S PRE RIG'' 2 -1/8" 4 10640 - 10658 S PRE RIG 2 -1/8" 4 10666- 10686 S 09/19/95 4. ve , ^ C a r " 10,655' e lmd ( -1 Filed tagged (sticky) several occassions (2011 8 1999) 10839' FISH - (2)4" E LENEN S FROM I FBTD IH 10750' I ` PKR SIN (LOST 08/22/96) 7 -5/8" CSG, 29.7 #, L -80, D= 6.875" H 10833' 0••••••••••1 TD - 10844, 1.�.1.1.�.1At•A t DATE REV BY COMMENTS DATE REV BY COMMENTS PRLDHOE BAY UNIT 12/20/90 ORIGINAL COMPLETION WELL: 09 47/' 09/02/02 BHC/TP PE RF CORRECTIONS PERMIT MIT No i N i 1M 1 01/02/11 PJC DRAINING CORRECTIONS AR No: 50- 029 - 22098 - 01/02/10 JCM/ PJC GLV/ SSSV CORRECTIONS SEC 1, T1ON, R15E, 4895.15 Fa., 2585.68 FNL 07/17/12 ZJS PROPOSED MD SIDETRACK BP Exploration (Alaska) Irat 1-Mt, 09 47A NELLHEAD = FMC • SAFETY NOTES: \tTUATOR= OTS 4 / Proposed CTD Sidetrack B.ELEV= 52' _ — 3F.ELEV = <OP= 900' ( 0 2219' 4 -1/2" CAMCO BAL -O SSSV NPw/ STUCK 1�x Angle = 40 @ 2500' FRAC SLV (SET 06/05/91), D = 2.75" Datum MD = 10486' Datum 11/D VD = -- 8800' SS 1 \ / I 3284' H 4-1/2" X 3-1/2" X0, D = 2.992" GAS LFT MANDRELS 4-1/2" TBG -IFC, 12.6#, L -80 BTC MOD, H 3284' ST MD TVD DEV TYPE VLV LATCH PDRT [a4TE .0152 bpf, D = 3.958" ,1 3383 3008 36 NOG DOME RK 16 10/14/95 2 6076 5202 39 MMG DONE RK 16 10/14/95 10 -3/4" CSG, 45.5#, J-55, D = 9.953" — I 4009' 3 7825 6630 35 MMG SO RK 20 02/13/99 4 8712 ii 33 MMG DMY RK 0 12/20/90 5 9289 7851 34 WAG DMY RK 0 12/20/90 Minimum ID =1.78" a@ 10,275' MD 6 9714 8205 33 MG DMY RK 0 02/13/99 Liner Deployment Sleeve 3" x 2.7" 7 10134 8556 35 MMG EQ DMY RK 0 12/20/90 10215' H3-1/2" BKR GBH-22 LOC SEAL ASSY, ID = 3.00" 1 i H NMI ID - I 7 - 5/8' X 3-1/2" BKR FB-1 PERM PKR, D = ? Ilir 10324' — 5-1/2" MLLOUT IXT134510N, ID = 5.00" 33° INC 10239' — - 1/2" X 3 -1/2" X0, ID = 2.992" — Top of 2 -3/8" Liner / TOC - 10,275' MD Top of Pilot Hole Cement - 10,280' MD - (inside tubing tail) ? 10296' eImdi- 13 -1/2" OTIS XN NP, D =2.75" PERFORATION SUPJvtARY 10315' — 13 - 1/2" BKR SOLD NOSE SF EAROUT SUB REF LOG: DL ON 12/18/90 ANGLE AT TOP PERF: 33° @ 10444' 10316' — 3-1/2" TBG -FC, 9.3#, L -80 Elm 8RD MOD IPC, Note: Refer to Production D8 for historical pert data 0087 bpf, D = 2.992" SIZE SPF INTERVAL Opn/Sqz DATE 10304' elm d —I ELMD TT LOGGED 03/20/91 2-1/7 2 10444 - 10448 S PRE RIG 2 -1/2" 2 10456 - 10468 S PRE RIG 2 -1/2" 2 10492 - 10504 S PRE RIG 41111# 1 2 -1/2" 2 10518 - 10524 S PRE RIG • • 2-1/7 2 10530 - 10534 5 PRE RIG , 2 -1/2" 2 10556 - 10560 S PRE RIG . 2 -1/8" 6 10586- 10590 S PRE RIG 2 -1/8" 6 10598 - 10603 5 PRE RIG . a 2 -1/8" 4 10618 - 10632 S PRE RIG 2 -1/8" 4 10640 - 10658 S PRE RIG t-a� • 2 -1/8" 4 10666- 10686 S 09/19/95 °� ii - 2 -3/8" 4.7# 13CR -80 liner, TD @ 13,135' MD 33° INC ■ Whipstock In Cement Pilot Hole KOP @ 10,490' MD 10,655' e lmd I1 Filed tagged (sticky) several occassions (2011 & 1999) iltrilli 10839' H FISH - (2)4" ELEMENTS FROM FEITD H 10750' ,,, ,�,v PKR STIM (LOST 08/22/96) t •••1$A$ i4 *1 7 -5/8" CSG, 29.7 #, L -80, D = 6.875" I— 10833' • •• •• • • • 1 4.11 TD H 10844' I ■ t� att 4 ������Al DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/20/90 ORIGINAL COMPLETION WELL: 09 -47'. 09/02/02 BHC/TP PERF CORRECTIONS PERMIT No: - 01/02/11 PJC DRAWNG CORRECTIONS API No: 50- 029 - 22098 - "' r. 01/02/10 JCM/ PJC GLV/ SSSV CORRECTIONS SEC 1, T1ON, R15E, 4895.15 FEL, 2585.68 FNL 07/17/12 ZJS PROPOSED CTD SIDETRACK BP Exploration (Alaska) ■ 4 NORDIC CTD RIG# 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM to Choli Prel Standpipe 2" Circulation Line T A M M 11 L©J ,�,,. radLI Driller Gauge 4 F � t � _ Ma nual Choke . ' M10 . mm MM9 CIRCULATING MANIFOLD - . MM 20 MM 22 t a #s :' r SLB Transducer _ MM 6 7- 1/16" 5kpsi BOP mane PV Se nsor • :..�: �_ . • — '' Air Blow down – - 4 4 r MM * Blind Shears ` " Li '� – k k r ' • Baker Choke .(,;. �,. ___ MM21 S BUST r� MM 5 2•' Combi TOT ■� s ;II; Ki Line PIS I� Rev Cir Line i I � . S ' ' eta w, MM14 ° a= �_ i 'cr .. .: ::= + RdMMnu6 s a i .R i *;.4. $ -W:x:4 fl•••, • � • • BOP 24 /P • • III '#. II Coiled Tubing — t��� •�- rwel�rar. ara:. ....::- .rrw�ekl�Iekllrnrr4laklklkkkrla .Ikl�lk. ' 8' Combi — Ba er Choke 2" Combi TOT r I MM 1 • i .. MP1 in • MM 13 w 4 itit , 1• 4=► --- Kill Line Outlet 4 Cement Line to Ground Mud •2 in V i Pu»» .s In .:. Tranducers COILED TUBING i ; Choke Line CIRCULATING SYSTEM Cellar Area '- IN I HP 14 To Inner Reel Outlets • Valve nJ HP7 HP3 11 �, — :.;.. ,I IWO HP 2 HP 1 HP ; cement line N2 SLB NORDICS 2 Circulate Manifold IMIB CHOKE MANIFOLD in Cellar _ - P 11 N2 TriFlow NI /CM 85 C , 11J �p qj p., Gauge L �L@ Ib $19 i _ •M CHOKE LINE r Test Pump Inlet — PI n ® CM3 HDI Gauge CM18 it 111/ 1 Flow fl HC' J m Tr v — . To PITS O 4Way Block CMI4 CM1 CM8 Mr C CM5 CM6 CM11 CM 16 c n'om m HcR Baker Choke Line Baker Choke Line from wall C7 M. CM 13 BAKER CHOKE LINE - - MI- v l PRIMARY FLOW PATH -aker Choke Line IN CM2 CMI9 • �' Micro Bec k — - Motion Back CM20 ,....., CM 26 CM21 M CM4 _ ..._ o'MARY FI.O PATH - M C M 30 CHOKE LINE _is CM 75 CM 10 Tige Tank CM 25 8 Outside • • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 December 30, 2011 VujittiCD FEB 2 611 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission l L) ( Ir 44 333 West 7 Avenue Anchorage, Alaska 99501 07 - Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir 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) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09 -01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09 -02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09 -03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09-08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09 -11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09 -12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09 -13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09 -15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09 -16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09-17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09 -18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09-19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09-22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09-23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09-24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09 -26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09 -27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 , 50029212920100 Dust Cover NA NA NA NA NA 09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09-30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 02 NA 1.7 7/27/2010 09-32 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09 -35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09 -37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 12 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 102 7/17/2010 09-41 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 102 7/18/2010 - - PP' 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 _ Dust Cover NA NA NA 3.4 10/20/2011 ANNULAR INJECTION DATA ENTRY SCREEN Asset ~ ........................................... Legal Desc .;I.;I. Z0:.ESL,...~..1.3:E.~L,...,~c...;I.,~-.;tDI~L..B1,SE. ........................... Research Rig Name .C~r~.c~ed..cop¥..~e~..t~..AQGC. C..;~:.;l.Z:.gZ ............... Inj Well Name .@.~..~[.7... ........................................ Permit Start ....... 1./..:t./..9.;~ ...... Permit End.....1.2~.3..l.J..9.;~... Sur Csg Dep ........................... · ............................................................. Cumulative Data Daily Data 1,760 1,760 Open 1992 Year End Summary ~.,.s,.......9..;~.~. ...................................................... .!..,_2_4.._0...i.' ..................................................................................................................................................................................................... 1..;...2..~.~ ............... .B..r..o.a,...c.. ,h..,,e..d._. U..a....n..u~.a..~_.l._t..h..r..o.~.~ .h_ U...a.,n.~.u,.,a..,.ry_3._,l_ .9.~3.. ................................... Well broched to sudace 1/3/93. Discontinued Injection Operations .... ,, ,, ..... ...... · , , STATE OF ALASKA -- ALASKA &ND GAS CONSERVATION CC ,SSION REPORT SUNDRY WELL OPEHATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1170' FSL, 113' FWL, Sec 1, T10N, R15E, UM. At top of productive interval 2607' FNL, 89' FWL, Sec 6, T10N, R16E, UM. At effective depth At total depth 2584' FNL, 128' FWL, Sec 6, T10N, R16E, UM. 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 52' RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-47 9. Permit number/approval number 90-146 10. APl number 50 - 029-22098 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10844 feet 9141 feet Plugs(measured) PBTD Tagged @ 10657' MD (6/18/96). Effective depth: measured 10657 feet true vertical 8995 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 40 Sx AS cmt 115' 113' Surface 3976' 10-3/4" 1335 Sx CS III, 320 Sx CI G, 4009' 3527' & 300 Sx CS II Production 10800' 7-5/8" 275 Sx ARC, 225 Sx CS I, 10833' 9132' & 110 bbls MTC Perforation depth: measured See perforation interval list attache'd~' L. true vertical See pedoration interval list attached. ? ~ %~,.,.. ' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, IPC~'~.'~284 MD; S-1/~, 9.3~, L-80, IPCT ~ 10316' Packers and SSSV (type and measured depth) 4-1/2" Camco Bal-O SSSV ~ 2219' MD; Baker FB-1 Packer ~ 10216' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure ORI61NAL 14. Prior to well operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Oasing Pressure 340 1344 5076 -- Tubing Pressure 313 Subsequent to operation 615 1724 2924 283 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations x Oil X Gas Suspended -..- Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~_~_ --~, Form 10-404 Rev 06/15/88 RHL cc: JWP Title Engineering Supervisor Date SUBMIT IN DUPLICATE 9-47 DESCRIPTION OF WORK COMPLETED MARCIT GEL SQUEEZE FOR WATER SHUTOFF & GEL BREAKER TREATMENT 9/18/95: A Fullbore MARClT Gel Squeeze was performed for Water Shutoff as follows: MIRU & PT equipment. Pumped the MARCIT Gel Treatment to squeeze the open perforation intervals located at: 10444 - 10448' MD (Z2) 10456 - 10446' MD (Z2) 10492 - 10504' MD (Z2) 10518 - 10524' MD (Z2) 10530 - 10534' MD (Z2) 10556 - 10560' MD (Z2) 10586 - 10590' MD (Z1B) 10599 - 10603' MD (Z1B) 10618 - 10632' MD (Z1B) 10640 - 10653' MD (Z1B) 10666 - 10686' MD (Z1B) Ref. Log: DIL 12/18/90. Pumped: a) 400 bbls of 78° F Seawater Preflush @ 2 - 4 bpm, followed by b) 1000 bbls of 78° F Crosslinked MARCIT Gel at 3000 ppm @ 4 bpm, followed by c) 1940 bbls of 78° F Crosslinked MARCIT Gel at 4500 ppm @ 3.5 - 4 bpm, followed by d) 50 bbls of 78° F Non Crosslinked MARClT Gel at 2000 ppm @ 1 - 4 bpm, followed by e) 285 bbls Crude Overflush, followed by f) Shutdown. Rigged down. 10/26/95' RIH w/CT & jetted a fill cleanout to 10735' MD. 11/15/95- Added Perforations: 10598 - 10599' MD (Z1B) 10653 - 10654' MD (Z1B) 10656 - 10658' MD (Z1B) Ref. Log: DIL 12/18/90. Reperforated: 10599 - 10602' MD (Z1B) 10618 - 10632' MD (Z1B) 10640 - 10653' MD (Z1B) Ref. Log: DIL 12/18/90. Used 2-1/8" carriers & shot all perfs at 4 spf at 90 degree phasing at overbalanced pressures. 8/22/96: A CTU Gel Breaker Treatment was pumped to restore production as follows: MIRU CTU & PT equipment. Loaded the wellbore w/1% KCl Water & Crude, and RIH w/CT mounted inflatable packer. Inflated & set the packer at 10452' MD, then pumped Gel Breaker fluids to treat the perforation intervals below the packer (listed above). Pumped 199 bbls of Calnox Solution w/2% Tetrasodium EDTA @ 0.6 - 0.9 bpm, followed by 50 bbls 1% KCI Water Flush. Released & POOH w/packer. Rigged down. Returned the well to production w/lift gas & obtained a valid production test. 9-47 Open Perforation Intervals (as of 9/9/96) 10444 - 10448' MD 10456 - 10468' MD 10492 - 10504' MD 10518 - 10524' MD 10530 - 10534' MD 10556 - 10560' MD 10586 - 10590' MD 10598 - 10603' MD 10618 - 10632' MD 10640 - 10654' MD 10656 - 10658' MD 10666 - 10686' MD 8816 - 8819' TVD 8826 - 8836' TVD 8856 - 8866' TVD 8878 - 8883' TVD 8888 - 8892' TVD 8910 - 8913' TVD 8935 - 8939' TVD 8945 - 8949' TVD 8962 - 8974' TVD 8981 - 8992' TVD 8994 - 8996' TVD 9002 - 9019' TVD Ref Log' DIL 12/18/90. · AlaSka 0il & Gas Cons. Commissu~r' Schluml~ercjc, r GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 1021'! Company: Alaska Oil & Gas Cons Comrn Attn: Howard Okland 3001 Porcupine Drive Anchorage, AK 99501 5/28/96 Field: Prudhoe Bay Well ,.' D.S. 1-6A 'D.S. 3-24 D.S. 4-29 Log Description CHEMICAl._ CI I]'TER RECORD JEWELRY LOG TUBING cUTrER RECORD Date 951113 95112O 951113 BL D.S. 6-8 TUBING CU'RER RECORD 9 51 I 1 6 I 1 rD.S. 6-19 0e~- /lc{ TUBING PATCH RECORD 951121 1 1 i PERFORATING RECORD I PERFORATING RECORD PERFORATING RECORD qJ"- 951115 D.S. 9-32 D.S. 9-32 D.S. 9-32 951116 951118 PERFORATION RECORD 9 51 1 0 5 I 1 ~O -/c/_~__ PERFORATION RECORD 9 51 1 I 5 I 1 D.S. 9-36C ~).S. 9-47 RF Sepia Anadrill Anadrill Anadrill Survey Program Performance Calct.~lal:ion Lel. ter Floppy Disk SIGNED' DATE: STATE OF ALASKA ALASI' 'L AND GAS CONSERVATION ( .,IlSSlON REPOR'I SUNDRY WELL OPP_RATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X, Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1170' FSL, 113' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 2607' FNL, 89' FWL, Sec. 6, T10N, R16E, UM At effective depth At total depth 2584' FNL, 128' FWL, Sec. 6, T10N, R16E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED APR 1 2 199§ Al~k~ Uti & Gas Cons. Commission Anehora,:,Q 6, Datum of elevation(DF or KB) 52 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-47 9. Permit number/approval number 90-146 10. APl number 50 - 029-22098 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10844 feet 9141 feet Plugs(measured) Fill @ 10638' MD (3/19/95) Effective depth: measured 10638 feet true vertical 8979 feet Junk(measured) feet Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 40 sx AS cmt 115' 113' Sudace 3976' 10-3/4" 1335 sx CS III & 320 sx Class G- Top job 4009' 3527' w/300 sx CS II Production 10800' 7-5/8" 275 ARC & 225 sx CS I & 110' bbls MTC 1 0833' 9132' Perforation depth: measured 10444-10448'; 10456-10468'; 10492-10504'; 10518-10524'; 10530-10534'; 10556-10560'; 10586-10590'; 10599-10603'; 10618-10632'; 10640-10653'; 10666-10686' true vertical 8817-8820'; 8825-8837'; 8857-8867'; 8879-8884'; 8889-8892'; 8910-8914'; 8936-8939'; 8947-8950'; 8963-8974'; 8981-8992'; 9003-9019' Tubing (size, grade, and measured depth) 4-1/2", 12.6#, L-80, IPCT @ 3284' MD; 3-1/2", 9.3#, L-80, IPCT tail @ 10316' MD Packers and SSSV (type and measured depth) Baker FB-1 Perm Packer @ 10216' MD; 4-1/2", Camco BaI-O SSSV @ 2219' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 339 1481 5536 340 1344 5076 Tubing Pressure 331 313 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 1 7. I hereby certify that the forecjoin9 is true and correct to the best of my knowledge. Form 10-404 Rev 06/15~88 cc: KZ, JWP. Title Engineering Supervisor Date /¢'-~?~ SUBMIT IN DUPLICATE 9-47 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 3/1 9/95: MIRU & PT equipment. RIH w/perforating gun & tagged bottom fill at 10638' MD, then PU & shot 22' of add perforations as follows: Added perforations: 1O586 - 10599 - 10618 - 10590' MD (ZlB) 10603' MD (ZlB) 10632' MD (Z1B) Ref. Log: DIL 12/18/90. Used a 2-1/8" carrier & shot 6 spf at 0 degree phasing at underbalanced pressures. POOH w/perf gun. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED APR 1 ~ 1995 0il & Gas Cons. Commission Anchora: :e Drill Site: 9 Well: 47 K-VALVE DESIGN Sun Sep 11 09:11:21 1994 DOME SET PRESSURE: 370 PSIG @ 60 DEG F FTP @ CLOSE (PSIG): 320 PSIG K-VALVE CLASS (A,B,C): A COMMENTS: CC: ENGINEERING FILE /'COORDINATOR PRB 24 (WITH A?TACHMNTS) J.C. S[~t%RT / M.G. SHOEMAKE PRB 20 (WITHOUT ATTACHMENTS) R, a. WELLS/ G. WILLIAMSON PRB 14 (COVER ONLY) Well twinned with 9-48. Wells [ecently had a choke problem resulting in a high del~a P across choke. Thi was cleaned out causing the FTP to drop and the KVLV to dump at wide open choke. Redesign will required weuu B. SEITZ ATO 15 (WITHOUT ATTACHMENTS) STATE OF ALASKA (COVER ONLY) DESIGNED BY: R. T. BURNO]%~ Drill Site: 9 Well: 47 Sun Sep 11 09:11:46 1994 K-V~VE DESIGN SSSV DEP?H (~AS): 2170 FTP @ CLOSE (PSIG): 320 PRESS ADJUSTMENT: 10 TEMP CORRELATION: PIPROF NOTE: LINEAR CORR USES SEP TEMP, PI PROF USES BH TEMP .AND WELL PI CONDITIONS OF WELL TEST: CK LGR FTP OIL %%~R GOR 90 2179 330 329 93.2 7177 CONDITIONS AT CLOSURE: 90 2179 320 332 93.2 7177 ?~LL TEST TEMPERATURE @ SSSV: 148 PRESSURE @ SSSV: 583 SEP COML GLR LIQ PWF PI TEMP PRES DATE SEL 929 4891 2547 4.50 138 0 07/16/94 Y 926 4927 2538 4.50 138 0 @CLOSE 150 572 DOME SET PRESSURE: 370 PRIOR DESIGNS: DATE: 05/29/94 SET PRESSURE: 415 FTP @ CLOSURE: 360 TEMP: LINEAR 0!/01/Sl 0 ~ 0 NA 01/01/81 0 0 NA ESC=EXIT; FI=HELP; F2=WELL TESTS; F4=DISTRIBUTION; F5=SENSITIVITY TABLE; F6=CHECKLIST; F10=ACCEPT; SF8=RESTORE WELL TEST; CF9=CYCLE DATA; WPS C= ..09431e-3 N= 1.000000 NEW C= ..05427e-3 ENTERED N= 1.0000O0 3/29/95 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9380 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 4-19 DuAL BURST-TDT-P 0320'95 I 1 D.S. 4-19 USIT 031 795 I 1 , D.S. 4-19 DUAL BuRST-TDT-P 031795 I I , . D.S. 4-19 CBT 031 795 1 1 ...... D.S. 9-47 PERFRECORD 031 995 1 1 ~ , . ,, ., , , ..... , , .............. , , , ,, , , SIGNED' Please sign and return one copy of this transmittal to Sherrie at the above address. RECEIVED & Gas Cons. Anchorage Thank you. 2/5/94 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9134 Company: Alaska Oil & Gas Cons Corem Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar PWDW 3-1 --~-,_ (~ ~ o/ STATIC BHP SURVEY (11'15-94) ! .... I ' ' D.S. 3-7 7~,~-- (-0 5--__~ PERF RECORD (11-20-94) I I ... D.S. 3-10 .~ ~-c22--/ !INJEC PROFILE (11-17-94) .... I ..... 1 D.S. 3-32A ~" ~ ~'~ ~ ,5- ~x' 'PROD PROFILE (11-14-94) 1 1 D.S. 4-19 .~ , O "z-I DUAL BURST TDT-P (11-21.-94)' ' I 1 D.S. 7-19 ~"~'-'~--17 . CNL ((11-13-94) 1 1 D.s. 9-21 ~ ~- ~ --"//~..0 LEAK DETECTION"(.11-11'94) 1 .... 1 D.S.' 9.-..21~'-,,,, ~-~ .- / ~. O TUBe PATCH RECORD (11-22-94) . I 1 D.S. 9-47 .~ ~),- ~/"~, PROD PROFILE (11-15-94) I 1 5 ' D.S. 9-49 ~'."~_~/'...~' ~ PROD PROFILE (11-14-94) I I ..... D.S. 11-31 _ ~....~- (' ?_:.? R.O.P.E. PERF RECORD (11-14-94) I 1 D.S. 11-32 ~ ~;~ ~ ~/'-[.~.'/ R.O.P.E. PERF RECORD (11-15-94) I 1 D.S. 15-41 ! "~'~,2,--- ~)~'7 GR-CCL (11-11-94) I . . 1 D.S. 16-21 ~-.,,~¢~-:~/'7_. LEAK DETECTION (11-22-94) I .1 D.S. 17-7 ,~'-/'.---(3&~ LEAK DETECTION (11,16-94) I 1 D.S. 17-13 .. ~r- ~--/? ~ LEAK DETECTION (11-16-94) I I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. ARCO Alaska, Inc. Date: Subject- From/Location: Telephone: To/Location: P.O. Box 100360, A .... :horage, AK July 6, 1994 Transmittal #: Kinle¥ Caliper Survey's John E. DeGrey/ATO- 1529 (907) 263-4310 94O55 Distribution Well i Log Date j Tool Type Number, (M-D-Y)1 09-07 i 06-24-94 i/~Ca..iiper Survey 09-47 i 05-02-94 ljCaliper Survey 16-12 I 04-29-94 ?' Caliper Survey 17-03 t 05-19-94 i ,,-'Caliper Survey 17-05 i 05-18-94 ~ ,,'Caliper Survey Number of Records: 5 iContractor ; Kinley Kinley ! Kinle¥ i Kinle¥ Kinley John E. DeGrey Distribution- Central Files BPX State of Alaska ANO-8 Geology Exxon By:Please acknowledg,e,...~ rece~ning and returning a copy of transmittal. Date: JUL 7 ? 1994 Alaska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. Is a Subsldlax7 of AtlantlcRIcttfleldCompeny . Caliper Specialists Since 1953 KINLEY. CORPORATION 5815 Royaiton, Houston, Texas 77081-;~993 U.S.A. Phone (71 3) 664-4501 Telefax (71 3) ISEi4-1 037 SERVICE AVAILABLE WORLDWIDE WITH ALL KINI. EY WIRELINE TOOLS Calipers · Tubing Perforators · Sand Line Cutters · Power Jars · Measuring Line Cutters HL, W TO READ THE SURVEY ABB REVIAT30 NS L.U. = L~.,ver U!~set Con'. -- C~rro~rt U.U. == Ul3t3er U~3set bel3. -' Del3osits u..~,. = Ul=l=er t~ody $caZcL = $caZ~red m.~ =-middle Body Shall '- Shallow L~. = lower Body NUMBERS AND L.,='TTERS ON THE SURVEY All JO ! N'TS in the tubing string a~re numbered, from the tel3 down, starting with the first fui! ~oi'nt beiow the Christmas tree. PUP JOINTS am given decimal numbers. Example: I.I r~presents the first pup joint below joint ~, SPECIAL TOOLS AND NIPPLES a'e identified by letters. Example: "B" is the second speciaJ'to~, or nipple, ' down from the top. Gas Lift Mandrels am numbered from the top. as shown: GLM Cl), GLM (2), GLM (3). etc. TABULATION SYMBOLS WHY IS THE CIRCLE OUR BASIC SYMBOL? The Kinley Caliper records the action of all [ts .o -- fifteen feelers simultaneously, instead of recording justthe action of the one feelerthat is.the fa~'thest · off-center. The Kirtley Caliper Survey has fifteen I~nes, instead of just one line. These fifteen lines' · of information give us a circular view of the inside surface of the tubing. A complete circle on the tzbulation sheets [n~c~tes that ~!I fifteen feelers (or al least fou~een)'found tubing wail reductions At the same level in the well SYM B OLS showing N UM B ER 0 F FEE L.ERS indic'zting tubing wail'reductions atthe sam e IeveL ~ 3to5 ~ ~to9 ~ 10 to 13 ~ 14 or 15 CMP) MEASUREMENT and PERCENTAGE SURVEY symbols (also (MPM) MEASURE, · MENT and PERCENTAGE MODIFIED symbols) - A number alone represents Re penetration, expressed in hundredths of an inch, of the PIT-A deepest piL (In this exampl~ the deepest penetration, probably due to corrosion, measures.08".) A RINC--A groove around the pipe, probaJ31y including corrosion, found by ali(or =tleast 14) of the 1 5 feelers. The number inside the ~rcJe represents the maximum penet~tion'of the ring, ex- pressed in hundredths of an inch. (In this example, a complete pit ring; reaches a maximum pene-.. tmtion of .1 [A PART[AL RINC--A groove, pr~babiy [nc!uding corrosion, found by at least 3 feelers, but no more than 13. (In this example, 10 feelers found penetratiort, resching ~ maximum l=enetr~tion ~ MINOR DAMAGE--tnd[catJorts of "minor" corrosion not sufficiently severe to warr~nl: measurement. [~NO COMMENT--No indication of ~ dam, age is recorded in ~h~-t Joint. Arco (Alaska), Inc. Prudhoe Bay, Alaska D.S. #09-47 May 2, 1994 Survey No. 23853 Chart No. M1276 This is the first survey of this well to be made with the Kinley 30- Feeler Caliper. The condition of the internal surface of the 4 1/2" 12.6# Buttress tubing in the well, from 0' to 2,187.'(WLM), is covered in this report. The condition of the tubing surveyed and analyzed appears good with respect to corrosive damage. As there are no penetrations of any consequence recorded in the survey, the usual cross-sectional drawing and Pit Depth Rank Chart are not included in the report. CALIPER TECHNICIAN Kenneth Bulloch SURVEY ANALYST Jon Chance jc Distribution: ARCO (ALASKA), INC., ATTENTION: Records Processor, Room #AT0-1529, P. O. Box 10-3240, Anchorage, AK 99510-3240 (7R) ARCO (ALASKA), INC., ATTENTION: Mr. Jason Weaver, Room #AT0-1788, P. O. Box 10-3240, Anchorage, AK 99510-3240 (~R) Chart received: Report mailed: 05-02-94 05-31-94 KINLEY CALIPER TALLY SHEET (Composite) DRILL SITE #09-47 Survey # 23853 May 2, 1994 4 1/2" 12.6# BU'FI'RESS Body: 0.271 Upset: 0.271 Penetrations Over 85% (Possible Hole) Penetrations 41 - 85% (pOor) # of Jts Penetrations 21 - 40% (Fair) Penetrations 11 - 20% (Good) Penetrations 1 - 10% (Very Good) No Penetrations Recorded TOTAL JOINTS SURVEYED: 57 57 ( Includes 2 Pup Joints ) KINLE CORROSION ?R OFILE DRILL SITE #09-47 PRUDHOE BA Y, AK May 2, 1994 SURVEY # 23853 4 1/2" 12.6# BUTTRESS CORROSIVE DAMA GE FREOUENC Y DISTRIBUTIONS MAXIMUM PENETRATION NUMBER OF JOINTS % WALL LOSS CONFIGURATION NUMBER OF JOINTS DESCRIPTION BODY PENETRATIONS 1$t JL of 4 1/2" 12.61I BUTTRESS EOS @ 2.187' (WLM) 20 % WALLLOSS 40 60 80 100 6 12 1'8 24 PIT DEPTH (1/100 inch) KINLEY CA. PER JOINT TABULAI_ )N SHEET 4 1/2" 12.6# BUTTRESS Body: 0.271 Upset: 0.271 Chart # M1276 Feeler Ratio 1 · 1 DRILL SITE #09-47 PRUDHOE BAY, AK Survey # 23853 May 2, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION PROFILE NO % INCHES % INCHES COMMENTS o (% WALL) O. 1 Pup ~t. 1 1st full length :~L below Tree . 1.1 Pup .lt. 3 4 5 .. 6I 7 8 10 11 12 13 14 15 16 17 18 19 20 21 22 23 25 , 31 . .re , 33 .. 35 36 [ 37 38 39 41 43 45 47 49 50 JOINT NO KINLEY CAJ ~ER JOINT TAB ULAI ~N SHEET 4 1/2" 12.6~ BUTTRESS Body: 0.271 Upset: 0.271 Chart # M1276 Feeler Ratio 1: I DRILL SITE #09-47 PRUDHOE BAY, AK Survey # 23853 May 2, 1994 Run # 1 MAXIMUM MAXIMUM ~UPSET/MAKEUP BODY PENETRATION PENETRATION COMMENTS DAMAGE PROFILE 100 (% WALL) ends in Jt. #55 @ ARCO Alaska, Inc. Date: May 24, 1994 P.O. Box 100360, '.qorage, AK Transmittal #: 94040 99510,~ ~ Subject' ARCO Cased Hole Finals From/Location- Telephone: To/Location: John E. DeGrey/ATO- 1529 (907) 263-4310 Distribution Well i .urger OWDW- ! SW 1-9A i 1-20 2-4' 2-5 2'5 ~0- ! 2'18 ¢;z-- 2-20 2-20 5-35 6-10 .tO 'l 6-11 ! 6-22A 7-3 7-3 7-23 7-23 9-13 9-26 9-42 9-47 11-36 12-8B 13-8 13-31 Log Date Type (M-D-Y) i Tool 4-29-94i v/,, PITS 5-14-94 i '/'~Pen` Rec 5-7-94 iv/ Pe'rfRec 5-11-94 CNL 5-7-94 v-" Prod Prof 5-7-94 CNL Run, ¢ 1 5" i 1 5" : 1 5" I 1 5" ~ 1 5" 5-8-94 Prod Prof 1 4-30-94 ~Y× Prod Prof 1 5-13-94 J,/ CNL i 1 4-4-94 iv/. Brid~e Plug 5-3-94 iv' Bridge Plu~ 5-9-94 _.L, USIT (Cern & Corr) 5-12-94. iv" Pen` Rec 5-17-944 ~ v/ 5-17-94 1 4-30-94 5-3-94 4-5-94 11 5" 5" Pen' Rec USIT Prod Prof TDT-P Leak Detect 5-14-94 ',-Packer Set Rec Pen' Rec Prod Prof Pen' Rec Set Rec Rec SCH SCH SCH SCH SCH SCH ' SCH ~ SCH i SCH SCH 1 5" SCH 1, 5" SCH i 1 5" SCH 1 5" 1 5" 1 5" 1! 5" 5" 5-14-94 v' 1 5" 5-8-94 1 5" 5-7-04 1, 5" 5-10-94 1, 5" 5-15-94 1, 5" 5-16-94 1, 5" 4-6-94 Pen` Rec 1, 5" 5-15-94 Leak Detect 1, 1" 2" 5" 5-16-94 Packer Set Rec 1, 5" 5-18-94 USIT 1, 5" 5-4-94 ,,/ Prod Pmf I 1, 1" 5" v~. .Ini Pmf i 1, 5" ~ 1, 5" v" USIT ~ ,/~ USlT : 1, 5" 5-2-94 11 11 SCH SCH SCH 5-2-94 13-35 5-10-94 14-7 5-13-94 14-15 5-17-94 14-41 16-26 vTubin9 Patch Rec! 1 ,.~ CNL ~ 1 17-19 18-1 -~-/~ /Dual Burst TDT-P ~'/ Pen` Rec -8-94 -6-94 5-12-94 ~ Pen`Rec ! 5- l~.~v," Pen' Rec SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH 1 5" SCH I 5" SCH SCH ,, ARCO Alask~ Inc. I~ a Sub~idlary of AllantlcRlchf~dC.,ompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 D-ATE: 6-19-92 REFERENCE: ARCO CASED HOLE FINALS ?/~ ~ * 1-1B 4-8-92 GR 72-;~ 7-9 3-22-92' Perf ?~t~ 9-46 2-10-92 Perf Record 9-47 3-22-92 Perf ?~'- ~-~7 14-4 3-6-92 Perf Record 21-..~? 16-13 3-29-92 Perf Record ~'--~9/3 16-18 3-30-92 Perf Record Run 1, 5" HI~ R~_m 1, 5" HLS Run 1, 5" HLS Run 1, 5" HLS Run 1, 5" HLS Run 1, 5" I-ILS Run 1, 5" HLS Please sign and return the 'attached copy as receipt of data. RECEIVED BY ~_~ Have A Nice Day! Sonya Wallace ATO-1529 RECEIVED dUN 2 9 1992 Alaska 0ii & G~s Oon~. Gommission Anchorage # CENTI~JkL FILES # CI-I~VRON D&M # EXTENSION EXPLOI:;L~TION # Ei~ON MARATHON # MOBIL APPROVED Trans# 92122 # PHILLIPS PB WELL FILES R&D # BPX '# STATE OF ALASKA TEXACO * The correct API# for 1-1B is 50-029-21007-01. STATE OF ALASKA ALASK/~ ~-'! AND GAS CONSERVATION C("'- vllSSION REPORT SUNDRY WELL OPERATIONS. 1. Operations performed: Operation shutdown Stimulate X Plugging Perforate X Puli tubing Alter casing Repair well , 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1170' FSL, 113' FWL, Sec. 1, T10N, R15E, UM At top of productive interval 2607' FNL, 89' FWL, Sec. 6, T10N, R16E, UM At effective depth At total depth 2584' FNL, 128' FWL, Sec. 6, T10N, R16E, UM 5. Type of Well Development Exploratory Strafigraphic Service Other 6. Datum of elevation(DF or KB) 52 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-47 9. Permit number/approval number 90-146 10. APl number 50 - 029-22098 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10844 feet 9141 feet Plugs(measured) None Effective depth: measured 10751 feet true vertical 9073 feet Junk(measured) None Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 40 sx AS cmt 115' 113' Sudace 3976' 10-3/4" 133s sx cs iii & 320 sx class G- Top job 4009' 3527' w/300 sx CS II Production 10800' 7-5/8" 275 sx ARC & 225 sx CS I & 110 bbls MTC 1 0833' 9132' Perforation depth: measured 10444-10448'; 10456-10468'; 10492-10504'; 10518-10524'; 10530-10534'; 10556-10560'; 10640-10653'; 10666-10686' true vertical 8817-8820'; 8825-8837'; 8857-8867'; 8879-8884'; 8889-8892'; 8910-8914'; 8981-8992'; 9003-9019' Tubing (size, grade, and measured depth) 4-1/2", 12.6~, L-80, IPCT @3284' MD; 3-1/2", 9.3#, L-80, ICPT Tail @ 10316' MD Packers and SSSV (type and measured depth) Baker FBol Perm Packer @ 10216'MD; 4-1/2", Carnco BaI-O SSSV @ 2219' MD 13. Stimulation or cement squeeze summary REEEiV~ 14. Intervals treated(measured) See attached. APR - 9 199 Treatment description including volumes used and final pressure J~!a"_.~ _nu ~, [~as Cons. c0mm'tss'~o~ Representative Daily Average Production or Injection Data Anchorage OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 337 430 65 -- 296 Subsequent to operation 1022 ' 2997 2927 -- 415 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations . 16. Status of well classification as: Oil ~ Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 Date ~/~/~ '~' SUBMIT IN DUPLICATE 807/7 RAC cc: SW, JWP 9-47 DESCRIPTION OF WORK COMPLETED DATA FRAC, PERF BREAKDOWN, & FRACTURE TREATMENT OF Zl 6/8/91: MIRU & ran Temp/Pressure Logs. PT to 5000 psi. perforations : 10640 - 10653' MD (Z1) 10666 - 10686' MD (Z1) Performed a Data Fracture Treatment, through the Ref. Log: DIL 12/18/90. Pumped 125 bbls 40~ Slickwater w/2 gpt Surfactant, at 15 - 20 bpm, followed by Shutdown. ISIP @ 1625. Resumed pumping 40 bbls 40# Slickwater, @ 15- 20 bpm, followed by Shutdown. ISIP @ 1740. Resumed pumping 180 bbls Crosslinked 40# Gel w/5% Diesel, @ 10 - 20 bpm, followed by 125 bbls Flush, @ 10 - 20 bpm, followed by Shutdown. Ran Temp logs indicating both perf intervals were taking fluid & no channels existed. Rigged down. 6/9/91: Reperforated the perforation intervals (listed above). 6/9/91 6/10/91: MIRU & PT equipment to 9500 psi, then attempted a Hydraulic Fracture Treatment through the perforations (listed above). Pumped 300 bbls 10# Pre Pad, @ 20 bpm, followed by Shutdown. ISIP @ 1735. Resumed pumping 195 bbls Pre Pad, @ 20 bpm, followed by 125 bbls Flush, @ 20 bpm, due to problem w/crosslinker timing, followed by Shutdown. Regelled & PT to 9800 psi, & resumed pumping 300 bbls Crosslinked Gelled Pad w/5% Diesel, @ 20 bpm, followed by 125 bbls Flush, @ 20 bpm, followed by Shutdown. Proppant stages were not pumped due to excessive treating pressures seen while pumping the Pad stage. Pumped 100 bbls of 40# linear Gel in 0.5 - 25 bpm stages, for step rate test. Shutdown. ISIP @ 1870. Pumped another 85 bbls 40# Gel. Shutdown. ISIP @ 1804. Rigged down. 8/1 7/91: Reperforated: 10648 - 10650' MD (Z1) Ref. Log: DIL 12/18/90. 10672 - 10674' MD (Z1) 8/22/91: MIRU & PT equipment to 7950 psi. Pumped a Perforation Breakdown through the perforations (listed above). Pumped 375 bbls 20# Gelled Seawater w/240 ball sealers, @ 20 - 25 bpm, followed by Shutdown. Surged well 5 times to unseat balls. Pumped 50 bbls of 20~ Gelled Seawater, followed by shutdown. ISIP @ 1419. RD. 8/25/91: MIRU & PT equipment to 9500 psi. Pumped a Perforation Breakdown through the perforations (listed above). Pumped 75 bbls 15% HCI Preflush, followed by 75 bbls 6% HCI - 1.5% HF, followed by 100 bbls 2% NH4Cl water, followed by 200 bbls 20# Gelled Fresh Water w/480 ball sealers, followed by 80 bbls 15% HCI, followed by 105 bbls 6% HCI - 1.5% HF, followed by 90 bbls Clayfix, followed by 25 bbls 20# Gelled Freshwater, followed by 100 bbls Seawater Flush. Surged well & resumed pumping 500 bbls Seawater overflush, followed by Shutdown. ISIP @ 1800. Perf friction was reduced by 600 lbs to 708 lbs. Rigged down. 8/29/91: MIRU & PT equipment to 9500 psi. Pumped a Propped Hydraulic Fracture Treatment through the perforations (listed above) using 16/20 mesh proppant. Pumped 250 bbls 20# Pre Pad, @ 25 bpm, followed by Shutdown. ISIP @ 1500. Resumed pumping 250 bbls Crosslinked Gelled Pad w/5% Diesel, followed by 175 bbls Slurry w/proppant stages at 1 - 10 ppg, followed by 34 bbls Flush, followed by Shutdown. Rigged down. Placed a total of 11,100 lbs of proppant into the formation. 8/31/91: Performed a proppant fill cleanout to 10695' MD. 3/20/92: Added perforations: 10444 - 10448' MD (Z1) Ref. Log: DiL 12/18/90. 10492 - 10504' MD (Z1) 10518 - 10524' MD (Z1) 10530 - 10534' MD (Z1) RECEIVED 3/22/92: APR - 9 Added perforations: 10456 - 10468' MD (Z1) Ref. Log; DIL 12/18/90. 10556 - 10560' MD (Zl) AJas~4a, OJJ & Gas Cons, Placed well on fulltime production w/gas lift & obtained a valid production test. Anchorage F'.O. BOX i(90S66, '~. ANCHORAGE, ALA~:K A 9~ :) DATE' 9-i 9-9i REFERENCE' ARCO CASED HOLE FINALS N'~-S 6-'~'~-91 PERF RECORD RUN t 5' · ' -' .=-,J 5-Si mi PERF RECORD RUN i , ~2-9 8-t6-9t F'ERF RECORD RUN t, 5' -2-'26 · 5-Si -9i PERF RECORD RUN ~3-27 8-i6-9i F'ERF RECORD RUN t, ~'~' &N_~-~ 8-6-c'i F'ERF RECORD RUN i ~4-'~'~,'. ~-~-~., ,i PERF RECORD RUN ~5-5. ~-m4-°i. , F'ERF RECORD RUN i , ~.~'" 5-i~. ~ 8-28-9i PERF RECORD RUN t, 5" 7-ii 6-3C~-9i PERF RECORD RUN i, 5" 7-28 7-23-9i PERF RECORD RUN i g-iS 8-i8-9i -PERF RECORD RUN t, 5" . ii-4 ~ ~9-9i PERF RECORD RUN ii-z ~-~'~-9i PERF RECORD RUN '-t~°--i4 8-6-~, . F'ERF RECORD RUN i, .~" -t2-28 =~--~9-~i~ . F'ERF RECORD RUN t, .~" .i~-'m° 8-i9-~i PERF RECURD RUN t ~" ~i4-9B 8-2t -9i PERF RECORD RUN i, d5-25 8-t -9t PERF RECORD RUN t, ~' F'L. EA~E SIGN AND RETURN THE ATTACHED E:OPY AS RECEIPT OF DATA. HAVE A NICE DAY! ~-7. ElM Y A WALLACE ATO- i 529 A F:' F' R 0 V E l_.'.' 'f' I;,' A N 'F.: ~ Yl FIL£' I-IL~ HL~' HLZ FILE: HLZ HLS' I--tLZ HLS HLZ, HL~' HLS HLS' HLZ HLZ, HLS' FI L :~]'. HLZ HLS' HLZ HL. 5' HL$ D I £'TR I BU'F ]: ON · '~ CENTRAL. FILES ~ F':HEVRON 'IF DaM ~ EXTENSION EXPLORATION · ,,.EXXON MARATHON MOBIL 'r ~ F'FIiL. L I FI:? F'B WELL F ILE£.' I';,' * D '"'-.. BPX ~TATE OF- ALA&~I<A TEXACO * THE"' CORRECT AF']:~ FOR f-tB I£' 56:'-029-2t0¢7-0t. e. THE CORRECT AF'I~ FOR 2-,5 " 'FHE CORRECT APl' FOR 3-27 ]:5' 50-029-°tiF'J9 % THE CORRECT LOIS INT. FOR 5-i2 15 8836'-9249'. $ THE CORRECT API~-' FOR t4-9B I'~J 50-'329-20.~34-02. RECEIVED OCT 0 Ai~.~k~ 011 & ~al] Cons. ARCO ALASKA, INC. F'~ O. BOX i ANCHORAGE, ALASKA 995i DA'FE ' 8-30-9 { REFERENCE' ARCO CASED HOLE FINALS 6-i =v_.. ,o_i.: ~,-.9 i F'ERF RECFiRD_ 7-3 8-i5-9t F'ERF RECORD 7-{'? 8--i2-9{ CCL (TUBING CUTTER) 7-{7 8_f-~ o ;-:,i VERTZLOG 7-i '? 8--2i --9i PFC 9-2 8--i 6-9i VERTILOG 9-4 8--i 8-9 i COL. LAR/PERF 9-5 8- i ':'}-9 i COLLAR/F'ERF ,--,:_o 8--i ,' ,- i COLLAR/PERF i ,S-i 0 8-I 4-9f COLLAR i 4-4 8'-1 i -9i CCL/PERF i4-i'3 8-2t-9i PERF RECORD i $-2~ 8- t $-9 i COLLAR/PEF.'.F i 8-i .S 8-2i -9i F'DK- i ¢,¢3/GR/CCL i 8- t 6 8-'2'2-9 i CNL RUN i RUN t RUN t RUN i RUN i RUN ~, RUN 1 RIJN t RUN i RUN t RUN t RUN { RUN { RUN i RUN i RUN t PLEA'SE SIGN AND REI'URN THE Ai'TACHED COPY AS RECEIPT OF DATA. H, AVE A NICE DAY~ SONYA WALLACE A'¥O- i 52':? AF'F'ROVED '¥'RANS:~ 9 ,,, S C H SCH ATLAS ATLAS ATLAS ATLAS A'f'I..AS ATLAS ATLAS SCH ATLAS ATLAS SCH AFLAS ATLAS SCH DISTRIBUT]:ON ~-* CE~"TRAL ,, ,r:- I LES ~ F'H IL_L.'r F'S -~: CHEVRON F'B WELL FILEY D & H R & D . ~ EXTENSION EXF'LORAi'ION ~ BPX :~ tEXXON ~ S'i'ATE OF_ALASKA HARATHON i'EXACO ~ HOB l L ARCO ALASKA, INC. P.O. BOX ANCHORAGE, ALASKA 995 DATE: 7-i 2-91 REFERENCE: ARCO CASED HOLE FINALS 1-t i 6-5-9t i-i t 6-5-9i t -2i 6-7-91 2-4 6-30-9t 4-t 6-t t-9i %4-36 6-2i-9~ F4-3Z 6-2t -9t ~1.¢~ /4-37 6-2t-9t '~ ~ ~4-37 6-24-9t ~t~ -33 7-2-9t ~I~D~ 5-35 6-38-9t * 9-6 6-t6-9t 9-8 6-5-9t 9-9 6-23-9t ** 9-1G 4-t 7-9t 9-t8 6-t 3-9t 9-33 6-t 4-9t ~ t t-3 4-1 7-9t ~ ~ -5 6-t 2-9t t 6-t 6 6-t 3-9t t7-t 6-t6-9t t 7-t t 5-8-9t PROD PROFILE/ GR-COLLAR J PROD PROFILE/ CCL-PERF/ GAS LIFT/ CBT/ CET~ F'FC-GR (PACKER SETTING CBTj CET~ F'FC-GR (PACKER SETTING~ GR-CCL--- COLLAR-F'ERFJ PRODUCTION F'ACKER-- SBL/GR/CCL- CCL-PERF--- LEAK DETECTIONs' PERFORATION BREAKDOWN~ COLLAR-PERF~ INJ PROFILEJ JEWELRY~ LEAK DETECTION-~ INJ F'ROFIL~~ DATA FRAC '[EMF'~ LEAK DETEC'FION--~ PROD PROFILE~. . PDK--t~/GR/CCL-BORAX~ LEAK DETECTION-- INJ F'ROFILE--- INJ PROFILE~ INJECTION/PRODUCTION-- PRISM-- LEAK DETECTION_.. RUN t, 5' CAMCO RUN t, 5' CAMCO RUN t, 5' CAMCO RUN ~, 5' ATLAS RUN t, 5' CAMCO RUN t, 5' $CH RUN t, 5' $CH RUN t, 5' ATLAS RUN t, 2'&5' $CH RUN t, 2'&5' $CH RUN t, 5' ATLAS RUN t, 5' ATLAS RUN t, 5" Al'LAS RUN t, 5' ATLAS RUN t, ~' ATLA~ RUN ~, 5' Al'LAS RUN t, 2'&5' CAMCO RUN t, 5' CAMCO RUN t, ~' ATLAS RUN ~, 5' CAMCO RUN t, 5' CAMCO RUN t, 2' CAMCO RUN t, 5' CAMCO RUN t, -5' CAMCO RUN t, 5' CAMCO RUN t, 5' CAMCO RUN t, 5" ATLAS RUN i, 2'&5' CAMCO RUN ~, 5' CAMCO RUN ~, 5' CAMCO RUN ~, 5' CAMCO RUN ~, 5' ATLAS RUN t, 2'&5' CAMCO PLEASE SIGN RECEIVED BY HAVE A'NICE $ONYA WALLACE AT0-t529 AND RETURN THE ATTACHED COF'Y.AS DAY! DISTRIBUTION CENTRAL FILES CHEVRON EXTENSION EXPLORATION EXXON MARATHON MOBIL RECEIPT OF DATA. ¢ P H I L L I P S '"~C,~o,~4 ~ F'B WELL F I LES ~"";~'~/0/2%/w'' BPX STATE OF ALASKA TEXACO * CORRECTED LOG INTERVAL FOR 9-6 I$ 67~0-770~ ** REFERENCE MIX UF' ON TRANSMITTAL 91159 - POSSIBLE DUPLICATE LOGS *** CORRECTED LOGGED INTERVAL FOR 9-40 I$ t395~-t425~ **** CORRECTED API~ FOR f3-I6 I£ 5~-~29-2~823 ~RMUU - ..._ - '~'-_ ' :.'RECE'r SH~-RON-.-'WIL-£ON"--"---'-' = - ::?:,~'--~.- , ...... ....... . .. - ~.~ _.. -?. -:,~. -.~. - ' 7'- ~: ~- ~-~: :' ARCO ALASKA, INC, F',O, BOX i08360 ANCHORAGE, ALASKA 995i0 DATE: 4-23-9i F<FZFEIr<ENCE: ARCO CASED HOLE FINAI_,S' "~--"~ 4- i 2- 9 i 2- t S S-25-9 3-5 4-'2-9t 4-' i ' S-'.')''~ ,_,:..-9 t 4-6 3-24-"9t 4- '24 3- '24 '"' 9 i~kO 47 -3-20-9t. t "~--o2 4-t .,¢,, a.., , · 3-98 3-'20--9 i ~{. 'i .4-i 6 3-i 8--9t i5-3 2-2'?-?i t 5-3 2-28-9t i 6'-6 4-i t-9i COLLAR/F'ERF : PRODUCI":[ON TB6 CUI'TFR F'F<OD PROFILE/PITS TEHPERAI'URF $1'ATIC I'EMF'EI;,'ATUF:E P ]; 1' S PRODUCTION PACKF:'R GAHMA/CCL COLLAR/PERF COLI_AR/F'ERF INJECT I ON INJECTION FL!Jli3 I,D, F'RO DI. JC T ]; ON I:'IT$ PERF I':',REAK DOWN COLLAR/F'EF~F RUN RUN I:,'. t.j N F:LJN R U N F: U N I:;.'. t.I N Rur.4 R U N RUN ~, R tJ N 'RUN RLJN I;: tJ N I:( LJ N RtJN R t.J N RUN I::'I...EA,.?E SIGN AND RETLIF(N THE A'f'"I"ACHEED C.IFf AS RE:CEII::'T ('JF:--DATA RECEIVli[D BY _~__~~ HAVE A NICE DAY! $1'iF:',RON I,,JILSON A'¥O'- t '529 AF'F:'I:;:~ Viii:I) ~ TRANS.- 9 i A'FLAb; CAMCO A'I'LA,? CAMCO C A H C; C) C A i't C t) C A Fi C 0 A'II_ A S I"1 R A'I'I_AS AI'I_A,S' CAHCO C', A H C 0 I..IRS C A H E; 0 I"1R I"IRS ~:' ILAS DI~'I'RIBUI'ION '"' CI.::NTRAI.. FILES .#, "" C Fl Ii:.:' V R 0 N D & H :'.':EXTENSION I:;XPLORAI'I ON EXXON "l~ f.l A F: A l' I..I 0 N ,,'" ltOBIL · " !::' I"1 'r I.. L. I F' 5' 'ii" PB W E I., L. F;' :1: I,.. E 5' R & D · '~. B P X ,.,., . · ~ ,.,lATE OF ALASI<A TIE X A C 0 · x. 1' H E. r:. 0 R IR E C 'f E D A I::' ]: -,5 f:' 0 R i 4 - i 6 I S ':~'.,.,.,n .-. ,,,~. ,n "~ m -- ~..,, o .., 8 ''~ n A n ,, ...... STATE I{ I 6 I A 0" ^"0 CO"S "V^T'O" WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL ~] GAS r'--J SUSPENDED r'-'] ABANDONED [~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 90-146 3 Address P.O. Box 100360, Anchorage, AK 99510-0360 4 Location of well at surface 1170' FSL, 113' FWL, SEC 1, T10N, R15E UM At Top Producing Interval 2607' FNL, 89' FWL, SEC 6, T10N, R16E UM At Total Depth 2584'FNL, 128'FWL, SEC 6, T10N, R16E UM 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. RKB 52' ADL 28345 12 Date Spudded 13 Date T.D. Reached 114 Date Comp,, Susp. or Abend. 12/04/90. 12/17/90. i 03/23/91' 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 10844' MD/9152' TVD 10750' MD/9073'TVD YES x[~J NO L_J 8 APl Number 50-029-22098 g Unit or Lease Name PRUDHOE BAY UNIT 10 Well Number 9-47 1 Field and Pool PRUDHOE BAY FIELD PRUDHOE BAY OIL POOL 15 Water Depth, if offshore 116 No. of Completions N/A feet MSL[ 1 20 Depth where SSSV set 21 Thickness of permafrost 2219' feet MD 1900' (approx) 22 Type Electric or Other Logs Run GR/SP/DIL/BHCS, GR/CNL/LDT, CET/CBT/GR, GYRO CASING, LINER AN~ CEMENTING RECORD CASING SIZE GRADE HOLE SIZE 20" 91.5# H-40 30" 10-3/4" 45.5# J-55 13-112' 7-5/8" 29.7# L-80 9-7/8' SETTING DEPTH MD TOP BOTTOM SURF 115' SURF 4009' SURF 10833' and Bottom and 24 Perforations open to Production (MD+'I'VD of To intervaJ, size and .number) 25 10638'-10651 'MD/8979'-8990q'VD W/4 SPF, 180° PHASING 10664'-10684'MD/9001'-9018'TVD W/4 SPF, 180° PHASING CEMENTING RECORD 40 SX AS CMT 1335 SX CS III & 320 SX CLASS G TOP JOB W/300 SX CS II AMOUNT PULLED 110 BBL MTC~ 275 SX ARC CMT & 225 SX CS I TUBING RECORD SIZE DEPTH SET (MD) 4-1/2' / 3-1/2' 10316' PACKER SET (MD) 10216' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC DEPTH II~rrERVAL (MD) N/A AMOUNT & KIND OF MATERIAL USED 27 N/A Date First Production Date of Test Hours Tested PRODUCTION TEST IMeffmd of Operation (Flowing, gas lift, etc.) PRODUCTION FOR TEST PERIOD ,,~ OIL-BBL GAS-MCF WATER-BBL Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL Press. 24-HOUR RATE ~* 28 CORE DATA CHOKE SIZE I GAS-OIL RATIO OIL GRAVITY-APl (cerr) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NONE *NOTE: DRILLED 12/20/90. TUBING RUN 3/6/91. PERFORATED WELL 3/23/91. RECEIVF:D Form 10-407 Rev. 7-1-80 ~ED ON REVERSE SID~ Submit in duplicate GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. TOP SAD LEROCH IT 10443' 8815' BASE SADLEROOHIT 10686' 9019' NONE 31. LIST OF ATTACHMENTS WELL HISTORY (DRILL AND COMPLETE), WELL HISTORY ADDENDUM (SIGNED 4/16/91), GYROSCOPIC SURVEY (2 COPIES) 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~-¢~ ',.~?'~¢'---' "7~A'~'¢'--- Title DRILLING ANALYST Date z¢' ~-.~ ~/ . INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 WELL HISTORY ADDENDUM WELL WORK LOG Well # 9-47 Date: 3/23/91 Work performed: INITIAL PERFORATIONS AFE: AS3960 ~ummary RU Halliburton. RIH w/ gun #1, shoot interval f/ 10664'-10684' w/ 4 spf, 180° phasing. POOH ASF. RIH w/gun #2, shoot interval f/10638'-10651' w/4 spf, 180° phasing. POOH ASF. RD. Perforated w/ 4 spf, 180° phasing: 10638'-10651' 10664'-10684' DRILLING SUPERINTENDENT RECEIVED APR .OJJ .& Gas Cons. Com~sslOn Anchorage ARCO 011 and Gas Comfyv'~ Well History - Initial Report - Daily Instruction.l: Prepare and the first Wednesday after a well is spudded or wort<over operations are started. Dally work prior ~JmmeHzed on the form giving inclusive dates only. ICounty. parish or borough NORTH SLOPE Ikease or Unit ADL: 28345 ITitle DRILL PRUDHOE BAY District Field Jstate AK Well no. DS 9-47 ^uth. or W.O. Operator ARCO Spudded or W.O. begun SPUD Date and depth as of 8:00 a.m. API: 50-029-22098 12/04/90 ( TD: 0'( SUPV:LP 12/05/90 ( TD: 855'( SUPV:LP 12/06/90 ( TD: 1970'( SUPV:LP 12/07/90 TD: 3322'( SUPV: LP TD: SUPV:L~.~:/~ 12/09/90 SUPV:LP ' The above is cor~'~ ~ For form I~eparatlon and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. IDate 12/04/90 IH°ur 18:00 rARCO W.I. 21.7800 Prior status if a W.O. Complete record for each day reported NABORS 28E 1) RIG MOVE. MW: 0.0 VIS: 0 0) MOVING RIG F/ 9-3 TO 9-47. 2) 855) DAILY:S14,505 CUM:$14,505 ETD:SO EFC:$2,301,405 DRILLING SURF. HOLE MW: 8.7 VIS:300 MOVE F/9-3 TO 9-47, NIPPLE UP DIVERTER, TAKE ON WATER IN PITS P/U BHA CHANGE STAB. BLADES,MIX SPUD MUD, FUNCTION TEST HYDRIL AND DIVERTER SYSTEM - DRILL F/ 110' TO 396' , SLIDE F/396' TO 456', CHANGE SWAB IN MUD PUMP # 1 , DRILL SLIDE F/ 456' TO 546'- CHANGE SWAB AND LINER IN #2 MUD PUMP, DRILL F/546' TO 8 55' DAILY:S66,848 CUM:$81,353 ETD:S50,000 EFC:$2,318,253 3) 115) DRILLING SURF.HOLE MW: 8.9 VIS:340 DRILL 855'MD - 1718' MD. PUMP SURVEY,, CIRC BTTMS UP , DROP SS ,PUMP PILL, POOH , C/O BIT #1, C/O DYNADRILL ORIENT - RIH, DRILL F/1718 - 1970'MD. DAILY:S83,581 CUM:$164,934 ETD:S150,000 EFC:$2,301,834 DRILLING. MW: 9.0 VIS:300 .:_...=52);RLG/ 1790'-2282'. CBU. POOH. L/D BHA. RIH. DRLG F/ ~:~::_$8t,792 CUM:$246,726 ETD:S250,000 EFC:$2,283,626 -~ 4~. '~' · ~:UP.::HOLE TO RUN CSG.10-3/4"@ 4009' MW: 9.4 VIS:400 ~/F/3322'MD TO 4019f MD , CIRC. BTTMS UP, PUMP PILL ~t~,SWABBING ,PULL SLOW FILL HOLE THROUGH DRILL PIPE, -:'CLEAN STABILIZERS , L/D MOTOR , BIT X/O P/U BIT SUB + #2 BIT. RIH BRIDGE AT 2950'MD. WASH AND REAM F/2950'MD TO 3041'MD RIH, WASH F/2950'MD TO 4019'MD . CIRC.BTTMS UP,DROP SURVEY + PUMP PILL, POOH TIGHT F~ 2715'MD TO 2558'MD. RIH TIGHT AGAIN @ 2500'MD , KELLY UP + REAM 8 JTS TO 2750'MD. DAILY:S60,958 CUM:$307,684 ETD:S290,000 EFC:$2,304,584 o) N/U BOPE 10-3/4"@ 4009' MW: 0.0 VIS: 0 REAM THRU TIGHT SPOT ,RIH TO BTTM., CIRC. AND CONDITION MUD, POOH , TIGHT 2800'MD TO 2600'MD , WORKED THROUGH + CLEANED HOLE. R/U TO RUN 10-3/4 CSG. CIRC.AND COND. MUD. PUMP 100 BBLS H20, DROP BTTM PLUG, TEST CMNT. LINES TO 3000 PSI. PUMP 456 BBLS(1335 SX) CS III LEAD SLURRY 12.2 PPG. PUMP 65 BBLS(320 SX) CLASS G TAIL SLURRY , DROP TOP PLUG DISPLACE W/ RIG PUMPS @ 13.5 BPM BUMP PLUG W/2000 PSI , CK FLOATS RECIPROCATg'PIPE THRU OUT CMNT. JOB CIP @ 2000 HRS. PERFORM TOP JOB W/ 300 SX CS II. DAILY:S214,257 CUM:$521,941 ETD:S700,000 EFC:$2,108,841 . AR3B~5~I-D INumberall dally well history forme consecutively no. as they' am prepared for each well. iiPage I ARCO 0,, ..nd Gas Company Daily Well History--lnterir Inatrucfionl: This form is used during drilling or workover operations. If testing, coring, or Derfora(ing. show formation name in describing ,vork oerformed. Number all drill stem testa sequentially. Attach description of all corea. Work 0erformed by Producing Section will be reported on "lnle,il~" sheels untd hnal completion. Report official or representative te~t on "Final" form. 1) Submit "lnlerim" sheets when tilled out but not less trequently than every 30 days. or (2) on Wednesday of Ihe week in which oil erring ia set. Submit weekly for workovera and following setting ot oil strinG until comolehon. District ICounty or Parish ARCO ALASKA INC. J NORTH SLOPE F;eld ~ ~Lease or Unit PRUDHOE BAY I DS 9-47 Date and depth Complete record for each day while drilling or workover m progreaa as of 8:00 a.m. NABORS 28E AK IWell no. 12/10/90 ( 7) TD: 4020' ( 1) SUPV:LP 12/11/90 ( TD: 6040'( SUPV:LP 12/12/90 ( TD: 7155'( SUPV:LP 12/13/90 ( TD: 8085'( SUPV:ZR 12/14/90 ( TD: 9100'( SUPV:ZR 12/15/90 ( TD: 9720'( SUPV:ZR 12/16/90 ( TD:10280' ( SUPV:ZR 12/17/90 ( TD:10778' ( SUPV:ZR 020) 9) 115) 0) 930) 1) 015) 2) ' 620) 3) 560) .4) 498) POOH 10-3/4"@ 4009' MW: 8.8 VIS: 32 N/U FMC WELLHEAD + BOPE, TEST BOPE,L/D 13-1/2 BHA ,P/U 9-7/8 BHA, RIH TO 1047' CUT AND SLIP 104' DRILL LINE,RIH TAG FC @ 3924' H_D , CIRC ,TEST CSG.TO 3000 PSI. DRILL F/C + HARD CEMENT TO 3999'MD , DRILL REMAINING CUNT.+ SHOE, DRILL 10' NEW HOLE TO 4029' ADT=.25 HRS. CIRC. BTTMS UP ,PERFORM LOT - EMW 12.7 PPG POOH TO L/D TELECO TOOL DUE TO FAILURE. DAILY:S99,248 CUM:$621,189 ETD:S750,000 EFC:$2,158,089 DRILLING. 10-3/4"@ 4009' MW: 9.1 VIS: 45 POOH. C/O TELECO MWD. RIH. DRLG F/ 4029'-6040' DAILY:S83,488 CUM:$704,677 ETD:S750,000 EFC:$2,241,577 DRILLING. 10-3/4"@ 4009' MW: 9.5 VIS: 46 DRLG F/ 6040'-6078' CIRC HIGH VIS SWEEP. DROP SURVEY. POOH. RIH. REAM F/ 6018'-6078' DRLG F/ 6078'-7155'. DAILY:S69,755 CUM:$774,432 ETD:S950,000 EFC:$2,111,332 P/U BHA #8. 10-3/4"@ 4009' MW: 9.6 VIS: 42 DRLG F/ 7155'-7975' CBU. SHORT TRIP TO 6630' DRLG F/ 7975'-8085' CIRC LOW/HIGH VIS SWEEP. DROP SS SURVEY. POOH. C/O BHA. DAILY:S69,394 CUM:$843,826 ETD:S1,025,000 EFC:$2,105,726 DRILLING. 10-3/4"@ 4009' MW: 9.7 VIS: 61 RIH. DRLG F/ 8085'-9100'. DAILY:S60,283 CUM:$904,109 ETD:S1,100,000 EFC:$2,091,009 DRILLING. 10-3/4"@ 4009' MW: 9.8 VIS: 45 DRLG F/ 9100'-9487'. CBU. SHORT TRIP. DRLG F/ 9487'-9692'. CBU. DROP SURVEY. POOH. M/U BHA. RIH. REAM TO BTM F/ 9610-9692' DAILY:S75,959 CUM:$980,068 ETD:S1,140,000 EFC:$2,126,968 DRILLING. DRLG F/ 9720'-10280'. 10-3/4"@ 4009' MW: 9.8 VIS: 49 DAILY:S54,730 CUM:$1,034,798 ETD:S1,160,000 EFC:$2,161,698 DRILLING. 10-3/4"@ 4009' MW: 9.8 VIS: 48 SHORT TRIP 13 STDS. DRLG F/ 10280'-10458'. CIRC SEEP. SHORT TRIP. DRLG F/ 10458'-10778'. DAILY:S61,592 CUM:$1,096,390 ETD:S1,575,000 EFC:$1,808,290 The a0oYe is corr~.~.t Sign I% ~c~ J,i,,e D,Iling Supt. see Procedurea Manual Section t0. Drilling, Pagea 86 and 87 AR38-459-2-8 NumOer all dady well h,slory ~orms consecu[,'¢ely as ~hey are prepared for each ARCO O..,nd Gas Company Daily Well History--lnterir Inllrurtiene: This form is used during drilling or workover operations. If testing, coring, or perforatrng, show formalion name ~n descrrbing ,York performed. Number ali drill stem tests sequentially. Attach descriplion of all cores. Work performed by Producing Section will be reported On "Interim" sheels unul hnal completion. Report official or reprelentative feet On "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days. or (2) on Wednesday of the week irt which oil string is set. Submil weekly for workovers and following setting of o~1 string unhl completion. Date and depth as of 8:00 a.m. District JCounty or Parish i Slate ARCO ALASKA INC. J NORTH SLOPE Field ~ ~ ILease or Unit PRUDHOE BAY I DS 9-47 Complete record for each day while drilling or workover in progress NABORS 28E 12/18/90 ( TD:10844' ( SUPV:ZR 12/19/90 ( TD:!0844' ( SUPV:ZR 12/20/90 ( TD:10844 PB: 0 SUPV:ZR 1~) 66) 1 ) 0) 7) AK LOGGING RUN #2. 10-3/4"@ 4009' MW: 9.9 VIS: 45 DRLG F/ 10788'-10844' CBU. SHORT TRIP 30 STDS. CIRC 50 BBLS SWEEP. POOH. R/U ATLAS WL. M/U LOGGING TOOLS. RUN #1 GR/SP/DIL/BHCS. RUN #2 GR/CNL/LDT. DAILY:S52,958 CUM:$1,149,348 ETD:S1,400,000 EFC:$2,036,248 RIH W/ 7-5/8" CSG. 10-3/4"@ 4009' MW: 9.9 VIS: 50 CONT'D LOG RUN#2 GR/CNL/LDT. TEST BOPE. M/U BIT & BHA. RIH. WASH 60' TO BTM. CIRC SWEEP. POOH. TEST BOPE TO 3000 PSI. RUN 7-5/8" CSG. DAILY:S45,331 CUM:$1,194,679 ETD:S1,550,000 EFC:$1,931,579 L/D DP. 7-5/8"@10833' MW: 9.3 NaC1 RIH W/ 7-5/8" CSG. PUMP 50 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER @ 10.5 PPG 127 BBLS MTC @ 12 PPB, 50 BBLS SPACER @ 13 PPB, 80 BBLS (275 SX) ARC SLURRY. BUMP PLUG W/ 2000 PSI. INSTALL FMC PACKOFF. PUMP 30 BBLS FRESH WATER DOWN ANNULUS FOR ARCTIC PACK. RETURNS IN CELLAR BOX. MIXED 10 BBLS DESCO PILL. PUMP AS TRACER W/ 180 BBLS. NO TRACER ON SURFACE. CONT'D ARCTIC PACK W/ 225 SX CSI, 95 BBLS ARCTIC PACK. L/D 5" DP. DAILY:S44,276 CUM:$1,238,955 ETD:S1,238,955 EFC:$2,286,900 Well no. The above is correct Sign~ ~~ . ~,,~,~ I~or form'"l~r~par~io~ and distribution see Procedures Manual Section 10. Drilling. Pages 86 and 87 Drilling Supt. AR3B-459-2-B Numoer all dalW ,,',,ell h,stor¥ forms consecullvely J= ~-~e *? as They are prepared for each well j ARCO O. and Gas Company Daily Well History-Final Report Inatructiona: Prepare and:~~J~e fir'at Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should b~;:'~- _ ..... '~ ~}:~re:euspended for an indefinite or appreciable length of time. On workovers when an official test Js not required upon completiO~~:.'--~lye teat data in blocks operation if space is ava[~ District ' ~'- ~-~:':' State 3rovided. The "Final Report" form may be used for reporting the entire Accounting cost center code NORTH ST.OpE AK ,~,13 T, ~ 28345 We,~,~. 9-47 Field AS3960 Auth, or W,O. no. PRUDHOE SAY County or Parish Lease or Unit ITte ARCO Operator SPOD A.R.Co. W,I, I Date NABORS ~28E Spudded or W.O. begun Date and depth as of 8:00 a'm-----21/9012/ TD:10844 PB: 0 SUPV:ZR Complete record for each day reported 18) APl: 5~-029-2209~ 21.7800 rrotal number of wells (active or inactive) on this ]cost center prior to plugging and l?/~d./(3t~ .... IabandOnment oft~w~l0,, I Hour Prior status if a W.O. RIG RELEASED 0 18~Ofl unq ~_g/o,,~n,o~ ..... ............. ',-; = 3 Naci L/D DP. FREEZE PROTECT TOP 400' W/ DIESEL. N/D BOP. N/U FMC DRY HOLE TREE. TESTED BPV. RIG RELEASED @ 18:00 HRS 12/20/90. ' DAILY:S342,546 CUM:$1,581,501 ETD:S1,581,501 EFC:$2,286,900 Old TD I New TD PB Depth Released rig I Date K nd of rig Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Off cial reservo r name(s) Potential test data Well no. Date Reservolr Producing Interval Oil or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. : Water % GOR Gravity Allowable I~ffective date , corrected The above is corre~"t~ For form preparation and distribution, see Procedures Manual, Section 10. Drilling, Pages 86 and 87. AR3B-459-3-C Number all dally well history forms consecutively as they are prepared for each well. iPage no. Dl~ldon of AtlantlcRk:MleidCompany ARCO Oi~ ~,.d Gas Company Well History - Initial Report - Dali; Instructions: Prepare and submit the "llllllat:Rellel't" on the first Wednesday after a well is spudded or workover operations are started. Daily work prior to spudding sholjJ(I be summarized on the form giving inclusive dates only· District Field ARCO ALASKA IState County, parish or borough NORTH SLOPE AK...._ · -' ILease or Unit IWell no. PRUDHOE BAY ' - I ADL: 28345 ~S 9-47 Auth. ITitle COMPI~ETE or w'°k%°3 9 6 0 APT: 50-029-22098 IARCO W,I. Operator ARCO 21.7800 Spudded or W.O. begUnAcCEPT IDate 03/03/91 IH°ur 0330 HRS IPri°rstatusifaW'O' Date and depth Complete record for each day reported as o! 8:00 a.m. NABORS 2ES 02/27/91 03/03/91 ( 19 TD: 0 PB:10750 SUPV:ZR 03/04/91 ( 20 TD: 0 PB:10750 SUPV:RWO 03/05/91 ( 21 TD: 0 PB:10750 SUPV:RWO MIRU SOS. LOG CET/CBT F/ 10650'-9430' AND 8400'-6100' RAN GR F/ PBTD-$URF CSG SHOE. RAN GYRO F/ PBTD-SURF. RD AND SECURE WELL. $44,554 COMPLETION N/U BOPE. 7-5/8"@10833' MW: 9.3 NaCl MOVE RIG F/ DS 9-40 TO DS 9-47. RIG ACCEPTED @ 03:30 HRS, 3/3/91. PULL BPV. N/D TREE. N/U BOPE. DAILY:S6,432 CUM:$1,587,933 ETD:S393,254 EFC:$3,481,579 POOH. 7-5/8"@10833' MW: 9.3 NaCl N/U BOPE. TEST BOPE. RIH W/ BHA #1. CIRC OUT DIESEL CAP. RIH. TAG FILL @ 10671'. ROTATE TO 10730'. CBU. 10 STD SHORT TRIP. REV CIRC. DISP W/ 8.6 PPG SEAWATER. POOH. DAILY:S23,370 CUM:$1,611,303 ETD:S416,624 EFC:$3,481,579 RIH W/ 3-1/2" TUBING. 7-5/8"@10833' MW: 8.6 Seawater POOH. R/U ATLAS W/L. TEST CSG. RIH W/ GR/JB/CCL. TAG @ 10746'. POOH. M/U 7-5/8" 'FB-i' PERM PKR W/ TAIL. RIH. SET @ 10216' (WLM). R/D ATLAS. RIH W/ 3-1/2" COMP. RECEIVED APR 2 9 t991 .0ii & ~as cons. commission Anchorage The above is correct For form~'preparetion and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87, iT,t,. Drilling Supt. AR3B-459-1-D Number all dally well history forms consecutively as they are prepared for each well. jPage no. ARCO O,, and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the-~'FIl~a~l~l't{~' on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "F hal Report" should be submitted .a~ ~.-:~13eraflon$ ars suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon completion, report co--and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation if space is available. ~:7-~---~.~? County or Parish NORTH SLOPE Lease or Unit ADL: 28345 T t e COMPLETE IAccounting cost center code State AK District -J~:~CO A~ASK~ INc. Field PRUDHOE BAY Well no. DS 9-47 Auth. or W.O. nD.AS3960 Operator ARCO Spudded or W.O.~pT Date and depth as of 8:00 a.m. 03/06/91 ( TD: 0 PB:10750 SUPV:RWO IA.R.Co. W.I. Date API: 50-029-22098 03/03/91 Iotal number of wells (active or inactive) on this Dst center prior to plugging and I 2 1 . 7 8 0 0 bandonment of this well [ J Prior status if a W.O, our 0330 HRS I Complet ...... d fq~].~[~a~ re~[t~d 22) RIG RELEASED @ 03:00 HRS. 7-5/8"@10833' MW: 8.6 Seawater RIH W/ 3-1/2" TBG, 4-1/2" TBG. P/U SSSV. RIH. STING INTO PKR @ 10216'. M/U FMC GEN IV HGR. PUMP 110 BBLS DIESEL DN TBG. LAND TBG HGR. TEST TBG. SET BPV. N/D BOPE. N/U TREE. INSTALL TEST PLUG. TEST TREE. SET BPV. SECURE WELL. RIG RELEASED @ 03:00 HRS, 3/6/91. CAMCO 'BAL-O' SSSV @ 2219', BAKER 7-5/8" X 3-1/2" 'FB-i' PERM PKR @ 10216', 3-1/2" TT @ 10316'. DAILY:S77,114 CUM:$1,901,941 ETD:S707,262 EFC:$3,481,579 Old TO I NewTD I PB Depth Released rig Jl Date ] Kind of rig I Classifications (oil, gas, etc.) Type completion (single, dual, etc.) Producing method Official reservo r name(s) Potential test data Well no. Date Reservoir Producing Interval Oil or gasTest time Production Oil on tesf Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective Ca=e corrected Sign' ure ', D Title -- For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. AR3B-459-3-C Number all daily well histor-/ forms consecutively Page no I aa they are prepared for each well. Dl~l~Jon of Atl~nl~l~t~l~4ny ,r TELECO] T.,~:o Oilfieid .""~"'.ice, of Alalk. Inc. 6116 Nielson V Anchorage, AK · 99502 (907) 562-2646 December 27, 1990 JOB #792 ARCO ALASKA, INC. WELL: DS-9-47 PRUDHOE BAY RIG: NABORS 28E Attached please find a copy of the computer calculated MWD directional surveys for the above mentioned well. Teleco appreciates this opportunity to provide service to ARCO Alaska Inc. Teleco is committed to providing the highest quality MWD Service and we would welcome any comments or questions concerning these surveys or any of our other services. Sincerely, Field Operations Supervisor JGM/el Enclosures RFCEIVED JAN 9 t991 Alaska 0/I & A ~41#AT COMPANY Company: Well: Location: Rig: Arco Alaska DS9-47 Prudhoe Bay Nabors 28E Inc. TELECO OILFIELD SERVICES SURVEY CALCULATIONS Date 12/19/90 TELECO Job # Grid Correction: Magnetic Declination: Total grid correction: Proposed Direction: 792tak 0.0' 30.8' 30.8' 74.0' MINIMUM CURVATURE CALCULATION Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/100° ******************************************************************************************************* TIE IN COORDINATES 0 0 0.0 0.0 0.01 0.01 0.01N 0.01E 0.01 N 45.00E 0.00 TELECO BEHIND MUD MOTOR 326 326 0.3 221.0 326.01 -0.70 0.61S 0.55W 0.82 S 42.24W 0.09 416 90 0.7 115.9 416.01 -0.48 1.02S 0.21W 1.04 S 11.59W 0.92 506 90 2.6 97.6 505.97 1.80 1.53S 2.31E 2.77 S 56.40E 2.16 688 182 6.2 93.4 687.40 14.86 2.66S 16.22E 16.43 S 80.67E 1.98 PAGE 1 Company: Arco Alaska Inc., Well: DS9-47, Location: Prudhoe Bay, ~iq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg' Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg deg/lO0° 869 181 8.8 85.3 866.84 37.66 2.1iS 39.78E 39.83 S 86.97E 1.55 1021 152 14.5 81.1 1015.65 .67.97 1.79N 70.19E 70.21 N 88.54E 3.79 1208 187 17.5 75.4 1195.40 119.33 12.50N 120.54E 121.19 N 84.0SE 1.81 1397 189 21.2 77.2 1373.69 181.88 27.24N 181.39E 183.42 N 81.46E 1.98 1585 188 23.7 77.9 1547.43 253.53 42.70N 251.49E 255.09 N 80.36E 1.34 1648 63 24.6 78.3 1604.92 279.24 48.01N 276.71E 280.84 N 80.16E 1.45 1836 188 27.9 77.6 1773.50 362.18 65.40N 358.01E 363.93 N 79.65E 1.76 2026 190 35.2 73.0 1935.33 461.45 90.98N 453.94E 462.97 N 78.67E 4.04 2212 186 39.3 73.7 2083.36 574.00 123.19N 561.79E 575.14 N 77.63E 2.22 2401 189 38.6 76.9 2230.36 692.75 153.36N 676.68E 693.84 N 77.23E 1.13 2590 189 39.9 71.2 2376.76 812.22 186.27N 791.52E 813.15 N 76.76E 2.03 2779 189 39.6 72.6 2522.08 932.99 223.82N 906.39E 933.61 N 76.13E 0.50 2968 189 38.1 73.0 2669.26 1051.51 258.87N 1019.64E 1051.99 N 75.75E 0.81 3156 188 37.4 73.3 2817.91 1166.60 292.22N 1129.80E 1166.98 N 75.50E 0.38 PAGE 2 Company; Arco Alaska ~nc,, Well: .QS9-~7, Location: Prudhoe Bay, Rig: NabQrs 28E Meas Course True. Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg 3345 189 36.6 71.6 2968.86 1280.29 326.50N 1238.24E 1280.57 N 75.23E 0.69 3533 188 37.2 73.3 3119.20 1393.11 360.53N 1345.86E 1393.31 N 75.00E 0.63 3725 192 35.3 72.6 3274.03 1506.62 393.80N 1454.40E 1506.77 N 74.85E 1.01 3914 189 34.5 71.2 3429.04 1614o67 427.38N 1557.18E 1614.77 N 74.65E 0.60 4166 252 33.7 68.8 3637.72 1755.58 475.66N 1689.93E 1755.60 N 74.28E 0.62 4354 188 33.0 70.2 3794.76 1858.62 511.87N 178.6.74E 1858.62 N 74.01E 0.55 4542 188 33.7 70.9 3951.79 1961.79 546.28N 1884.21E 1961.80 N 73.83E 0.42 4728 186 34.8 70.9 4105.53 2066.31 580.54N 1983.13E 2066.35 N 73.68E 0.59 4980 252 35.9 69.1 4311.07 2211.73 630.43N 2120.11E 2211.85 N 73.44E 0.60 5228 248 37.9 71.6 4509.40 2360.30 680.42N 2260.33E 2360.52 N 73.25E 1.01 5480 252 36.2 72.3 4710.51 2512.03 727.48N 2404.68E 2512.31 N 73.17E 0.70 5730 250 36.1 73.0 4912.38 2659.46 771.44N 2545.45E 2659.78 N 73.14E 0.17 5982 252 37.2 73.3 5114.56 2809.86 815.03N 2689.42E 2810.20 N 73.14E 0.44 PAGE 3 ..Company: ArCo Alaska In¢.,..Wel~ Dsg-~7, Location: Prudhoe Bay, Riq: Nabors 28R Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet ~eet deg deg feet feet feet feet feet deg deg/100' ******************************************************************************************************* 6233 251 '36.4 72.6 5315.54 2960.19 859.10N 2833.16E 2960.55 N 73.13E 0.36 6483 250 35.0 74.7 5518.55 3106.07 900.21N 2973.13E 3106.43 N 73.15E. 0.74 6731 248 .,35.6 74.7 5720.94 3249.38 938.03N 3111.38E 3249.70 N 73.22E 0.24 6983 252 35.5 74.7 5925.97 3395.89 976.70N 3252.70E 3396.17 N 73.29E 0.04 7226 243 33.3 75.1 6126.46 3533.15 1012.47N 3385.23E 3533.40 N 73.35E 0.91 7519 293 35.0 74.4 6368.92 3697.63 1055.76N 3543.93E 3697.84 N 73.41E 0.60 7803 284 34.8 70.5 6601.86 3860.00 1104.72N 3698.81E 3860.26 N 73.37E 0.79 8020 217 33.6 73.3 6781.34 3981.86 1142.65N 3814.70E 3982.16 N 73.32E 0.91 8245 225 33.6 72.6 6968.75 4106.35 1179.16N 3933.74E 4106.67 N 73.31E 0.17 8560 315 33.0 76.5 7232.04 4279.23 1225.26N 4100.36E 4279.51 N 73.36E 0.71 8873 313 33.1 75.4 7494.38 4449.85 1266.71N 4265.97E 4450.07 N 73.46E 0.19 9187 .314 34.0 74.6 7756.06 4623.38 1311.64N 4433.61E 4623.56 N 73.52E 0.32 9501 314 33.3 75.8 8017.43 4797.35 1356.11N 4601.84E 4797.49 N 73.58E 0.31 PAGE 4 Company: Arco Alaska Ipc.~, Well; DS9-47, Location: Prudhoe Bay, Riq: Nabors 28E Meas Course True Vertical Coordinates Closure Dog Leg Depth Length Incl Azi Vert. Dp. Section N/S E/W Distance Angle Severity feet feet deg deg feet feet feet feet feet deg ******************************************************************************************************* 9627 126 33.9 75.1 8122.38 4867.05 1373.63N 4669o33E 4867.18 N 73.61E 0.57 9933. 306 33.5 76.9 8376.96 5036..72 1414.71N 4834.05E 5036.81 N 73.69E 0.35 10218 285 33.1 80.0 8615.18 5192.68 1446.04N 4987.30E 5192.71 N 73.83E 0.62 10393 175 32.6 83.9 8762.21 5286.66 1459.34N 5081.25E 5286.66 N 73.98E 1.24 10799 406 32.9 83.9 9103.68 5503.04 1482.68N 5299o64E 5503.14 N 74.37E 0.07 PROJECTED BHL 10844 45 32.9 83.9 9141.46 5527.12 1485.28N 5323.95E 5527.25 N 74.41E 0.00 PAGE 5 TE?7. CO 0i 1 f i e }d PLAN VIEW Serv ~c,~ 12800 Arco Alaska Inc. 0S9-47 Prudhoe Bay Nabors 28E JOB# 792tak/O0 SCALE: 1 inch = 1600 feet 11200 9600 8000 6400 z o 4800 3200 1600 1600 1600 3200 4800 600 EAST (ft) 6400 8000 -~000 2000 4000 ~5000 ~8000 >lO000 12000 14000 16000 18000 TF' Eeo Oilfield Servic6 VERTICAL PROJECTION lO00 3000 5000 7000 9000 ,' 859 ' 8. lB oleg a~7' a~.a ~e; Arco Alaska Inc. oas ' 3~.2 ~eg DS9-47 ~eo ' 3e.e de~ Prudhoe Bay ~e ' ~ ~ ~e~ Nabors 28E '%- ' JOB¢ 792tak/O0 735 ' 35,3 de~ SCALE 980 ' 35,9 . ~730 ' 5~.1 deg 6E55 ' 38.4 ~eu 873~ ' 35.8 de~ 226 ' 33.3 deg 803 ' 54.8 ~580 ' 33.0 ~ deg ~9~87 ' 34,0~ deb 11000 VERTICAL SECTZON (ft) SUB - SURFA CE DIRECTIONAL SURVEY ~ UIDANCE ~-~ ONTINUOUS ~-~ OOL R~'¢EI'VI~D APR 2 9 1991 A!aska 0il & Anchorage Company ARCO ALASKA, INC. Well Name D.S. 9-47 (1170' FSL, 113' FWL, SEC 1, T10N, R15E, UM) Field/Location_PRUDHOE BAY~ NORTH SLOPE, ALASKA Job Reference No. 74403 Locjqed By- FORMICA Date 27-FEB-91 Computed By' KRUWELL SCHLUMBERGER * GCT DIRECTIONAL SURVEY CUSTOMER LISTING FOR ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA SURVEY DATE: 27-FEB-1991 ENGINEER: JEFF FORMICA METHODS OF COMPUTATION TOOL LOCATION: TANGENTIAL- Averaged deviation and azimuth INTERPOLATION: LINEAR VERTICAL SECTION: HORIZ. DIST. PROdECTED ONTO A TARGET AZIMUTH OF NORTH 74 DEG 1MIN EAST COMPUTATION DATE: 02-APR-91 PAGE 1 ARCO ALASKA INC. D.S, 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 oo 800 O0 900 O0 0 O0 lO0 O0 200 O0 300 O0 399 99 499 97 599 77 699 32 798 55 897 33 -52 O0 48 O0 148 O0 248 O0 347 99 447 97 547 77 647 32 746 55 845 33 0 0 N 0 0 E 0 4 S 10 8 W 0 11 S 20 38 W 0 34 S 57 8 E 0 35 S 67 25 E 2 9 S 76 55 E 4 39 S 85 2 E 6 17 S 88 14 E 8 0 N 87 56 E 9 58 N 84 28 E 0 O0 -0 03 -0 01 -0 28 0 52 2 19 7 84 16 69 28 62 43 83 0 O0 0 24 0 65 1 26 0 22 2 97 1 65 1 91 2 53 2 32 0 O0 N 0 05 S 0 36 S 0 72 S 1 14 S 1 75 S 2 59 S 3 12 S 3 07 S 1 99 S 0 O0 E 0 01 W 0 09 E 0 08 W 0 86 E 2 77 E 8 90 E 18 26 E 30 65 E 46 17 E 0 O0 N O 0 E 0 0 0 1 3 9 18 3O 46 05 S 13 35 W 37 S 14 15 E 72 S 6 25 W 43 S 37 4 E 28 S 57 48 E 27 S 73 47 E 52 S 80 18 E 81 S 84 17 E 21 S 87 32 E 1000 O0 1100 O0 1092 1200 O0 1188 1300 O0 1283 1400 O0 1377 1500 O0 1470 1600 O0 1562 1700 O0 1653 1800 O0 1742 1900 O0 1830 995 21 02 1040 09 1136 28 1231 47 1325 46 1418 33 1510 11 1601 65 1690 54 1778 943 21 13 24 02 15 26 09 16 57 28 18 50 47 20 28 ,46 22 34 33 23 56 11 25 40 65 27 16 54 30 1 N 82 26 E N 78 0 E N 75 32 E N 74 26 E N 76 16 E N 77 26 E N 77 16 E N 76 50 E N 76 44 E N 75 36 E 63 94 88 82 116 53 147 15 180 72 217 46 256.86 298.74 343.19 390.84 3 08 0 93 2 15 2 04 2 66 1 56 1 60 1 56 1 94 3 59 0 37 N 4 62 N 91 10 99 N 118 19 15 N 147 27 67 N 180 35 99 N 215 44 57 N 254 54 O0 N 295 64 15 N 338 75 50 N 384 66 40 E 06 E 91 07 E 118 58 E 148 06 E 182 89 E 218 42 E 258 29 E 300 62 E 344 94 E 392 66 41 N 89 41 E 18 N 87 6 E 58 N 84 41 E 82 N 82 36 E 18 N 81 16 E 87 N 80 32 E 3O N 80 4 E 18 N 79 38 E 64 N 79 16 E 27 N 78 54 E 2000 O0 1915 26 1863 26 34 0 2100 2200 2300 2400 2500 2600 2700 28OO 2900 O0 1997 O0 2077 O0 2156 O0 2236 O0 2313 O0 2389 O0 2467 O0 2544 O0 2622 36 1945 64 2025 84 2104 03 2184 22 2261 99 2337 28 2415 63 2492 69 2570 36 35 24 64 37 44 84 37 19 03 38 25 22 40 7 99 39 32 28 39 18 63 39 18 69 38 2 N 73 7 E N 71 34 E N 73 15 E N 76 37 E N 76 8 E N 71 38 E N 70 14 E N 71 2 E N 71 33 E N 71 33 E 443 91 500 97 560 54 621 57 682 746 810 873 936 999 56 12 07 42 72 16 3 32 1 44 2 89 1 26 3 18 3 49 0 99 0 42 0 67 0 92 89 74 N 436.06 E 445 20 N 78 22 E 107 125 141 155 172 194 215 235 255 30 N 490.38 E 501 59 N 547.11 E 561 29 N 606.09 E 622 35 N 665.52 E 683 74 N 726.64 E 746 17 N 787.03 E 810 15 N 846.91 E 873 46 N 906.94 E 937 24 N 966.23 E 999 98 N 77 39 E 33 N 77 4 E 35 N 76 53 E 41 N 76 52 E 89 N 76 38 E 63 N 76 8 E 81 N 75 45 E 01 N 75 27 E 38 N 75 12 E 3000 O0 2701.57 2649 57 37 56 3100 3200 3300 3400 3500 3600 3700 3800 3900 O0 2780.51 2728 O0 2860.05 2808 O0 2940.49 2888 O0 3021 03 2969 O0 3101 23 3049 O0 3180 93 3128 O0 3261 11 3209 O0 3342 81 3290 O0 3424 83 3372 51 37 41 05 36 53 49 36 14 03 36 28 23 36 56 93 37 15 11 35 49 81 34 57 83 34 33 N 72 20 E 1060.59 N 72 57 E 1121.96 N 71 44 E 1182.54 N 70 18 E 1241.86 N 71 15 E 1301.02 N 72 6 E 1360.71 N 73 13 E 1421.09 N 72 11 E 1480.83 N 72 4 E 1538.45 N 71 11 E 1595.62 0 55 0 73 1 37 0 34 0 69 0 88 0 56 2 44 0 53 2 99 274 34 N 1024 66 E 1060 75 N 75 1 E 292 310 330 349 368 386 404 422 439 57 N 1083 87 N 1141 37 N 1197 89 N 1253 64 N 1309 63 N 1367 17 N 1424 08 N 1479 77 N 1533 27 E 1122 05 E 1182 17 E 1241 12 E 1301 83 E 1360 49 E 1421 62 E 1480 42 E 1538 83 E 1595 09 N 74 53 E 64 N 74 46 E 92 N 74 34 E 05 N 74 24 E 72 N 74 17 E 10 N 74 13 E 84 N 74 10 E 45 N 74 5 E 62 N 74 0 E COMPUTATION DATE: 02-APR-91 PAGE 2 ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4000 O0 3507.86 3455 86 33 35 4100 4200 4300 4400 4500 4600 4700 480O 4900 O0 3590.96 3538 96 33 49 O0 3674.26 3622 26 33 18 O0 3758.19 3706 19 32 34 O0 3842,20 3790 20 33 14 O0 3925.49 3873 49 33 44 O0 4008.74 3956.74 33 38 O0 4091.31 4039.31 34 46 O0 4173.52 4121.52 35 1 O0 4254.64 4202.64 36 12 N 68 22 E 1651 17 N 68 55 E 1706 N 69 15 E 1761 N 69 40 E 1815 N 69 59 E 1869 N 70 24 E t925 N 70 21 E 1980 N 69 45 E 2036 N 69 27 E 2093 N 68 55 E 2151 55 67 85 96 17 47 73 51 77 0.57 0.45 0.82 0.84 0.90 0.07 1 .07 0.62 2.12 0.29 459 36 N 1585 99 E 1651 17 N 73 51 E 479 499 518 537 555 574 593 613 634 64 N 1637 35 N 1689 48 N 1740 21 N 1791 95 N 1843 53 N 1895 91 N 1948 63 N 2001 50 N 2056 79 E 1706 48 E 1761 36 E 1815 28 E 1870 35 E 1925 54 E 1980 52 E 2037 94 E 2093 56 E 2152 58 N 73 41 E 73 N 73 32 E 95 N 73 25 E 10 N 73 18 E 36 N 73 13 E 70 N 73 8 E O2 N 73 3 E 87 N 72 58 E 21 N 72 51 E 5000 O0 4335 67 4283.67 35 27 5100 5200 5300 5400 5500 5600 5700 5800 5900 oo 4417 O0 4498 O0 4578 O0 4657 O0 4738 O0 4820 O0 4901 O0 4982 O0 5062 15 4365.15 35 20 N 69 13 E 2267 32 4446.32 36 46 N 70 14 E 2326 01 4526.01 37 10 N 71 10 E 2386 98 4605.98 36 29 N 71 25 E 2446 66 4686.66 35 56 N 71 49 E 2505 01 4768,01 35 19 N 73 9 E 2563 28 4849.28 36 3 N 72 57 E 2621 03 4930.03 36 18 N 73 14 E 2680 11 5010.11 37 12 N 73 11 E 2740 N 68 59 E 2210 12 89 12 43 41 44 57 82 81 70 0 44 071 3 63 0 39 0 80 1 58 0 61 0 83 1 05 0 48 655 59 N 2111 22 E 2210 66 N 72 45 E 676 696 716 735 754 771 788 805 823 28 N 2165 59 N 2220 47 N 2277 69 N 2334 34 N 2390 80 N 2445 74 N 2501 79 N 2557 21N 2615 38 E 2268 14 E 2326 18 E 2387 06 E 2447 12 E 2506 59 E 2564 34 E 2622 81 E 2681 12 E 2741 53 N 72 39 E 85 N 72 35 E 23 N 72 32 E 26 N 72 30 E 33 N 72 29 E 49 N 72 29 E 74 N 72 30 E 73 N 72 31 E 63 N 72 32 E 6000 O0 5141 62 5089 62 37 31 6100 6200 6300 6400 6500 6600 6700 6800 6900 O0 5219 O0 5297 O0 5378 O0 5459 O0 5541 O0 5623 O0 5704 O0 5785 O0 5867 81 5167 84 5245 35 5326 58 5407 25 5489 14 5571 48 5652 98 5733 48 5815 81 39 17 84 37 30 35 35 50 58 35 32 25 34 55 14 35 22 48 35 34 98 35 17 48 35 27 N 72 36 E 2801 32 N 72 43 E 2863 N 72 21 E 2926 N 72 16 E 2985 N 72 57 E 3043 N 73 20 E 3101 N 72 40 E 3158 N 73 22 E 3216 N 73 38 E 3274 N 73 37 E 3332 64 16 43 73 43 82 98 92 86 1 55 0 30 3 94 0 68 0 64 0 70 0 98 0 58 0 70 0 65 841.13 N 2673 05 E 2802 26 N 72 32 E 859.70 N 2732 878.40 N 2792 896 62 N 2848 914 02 N 2904 93O 68 N 2959 947 48 N 3014 964 51 N 3070 98O 80 N 3125 997 35 N 3181 55 E 2864 23 E 2927 66 E 2986 33 E 3044 57 E 3102 45 E 3159 07 E 3218 68 E 3275 21 E 3333 60 N 72 32 E 13 N 72 32 E 44 N 72 32 E 76 N 72 32 E 45 N 72 33 E 85 N 72 33 E 02 N 72 34 E 95 N 72 35 E 89 N 72 36 E 7000 O0 5948.77 5896 77 35 42 7100 7200 7300 7400 7500 7600 7700 7800 7900 O0 6030.87 5978 87 33 43 O0 6114.34 6062 34 33 19 O0 6197.64 6145 64 34 2 O0 6280.14 6228 14 34 34 O0 6362.46 6310 46 34 45 O0 6444.58 6392 58 34 48 O0 6526.68 6474 68 34 52 O0 6608.74 6556.74 34 48 O0 6691.03 6639.03 34 22 N 74 42 E 3391.10 N 74 41 E 3448.18 N 74 9 E 3503.25 N 73 '29 E 3558.57 N 72 48 E 3615.08 N 73 15 E 3671.84 N 73 19 E 3728.90 N 73 0 E 3785.98 N 71 11 E 3843.10 N 71 5 E 3899.85 0 65 1 53 0 44 1 47 0 27 0 5O 0 27 0 65 0 57 0 97 1013 25 N 3237 24 E 3392.10 N 72 37 E 1028 1042 1058 1074 1091 1107 1124 1141 1160 24 N 3292 99 N 3345 37 N 3398 85 N 3452 46 N 3506 80 N 3561 34 N 3616 93 N 3670 34 N 3724 32 E 3449.15 N 72 39 E 38 E 3504.20 N 72 41 E 52 E 3559.50 N 72 42 E 58 E 3616.03 N 72 42 E 86 E 3672.79 N 72 43 E 54 E 3729.85 N 72 43 E 18 E 3786.94 N 72 44 E 56 E 3844.08 N 72 43 E 32 E 3900.89 N 72 42 E ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 02-APR-91 PAGE 3 DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN 8000 O0 6773.90 6721 90 33 48 8100 8200 8300 840O 8500 8600 8700 8800 89OO O0 6857 29 6805 O0 694O O0 7024 O0 7107 O0 7191 O0 7275 O0 7359 O0 7443 O0 7527 78 6888 15 6972 58 7055 44 7139 42 7223 47 7307 61 7391 57 7475 29 33 18 78 33 28 15 33 35 58 33 13 44 32 53 42 32 51 47 32 47 61 32 40 57 33 12 9000 O0 7610 87 7558 87 33 59 9100 9200 9300 9400 9500 9600 9700 9800 9900 O0 7693 O0 7776 O0 7859 O0 7943 O0 8026 O0 8109 O0 8192 O0 8276 O0 8360 80 7641 80 33 54 73 7724 73 33 59 76 7807 76 33 46 09 7891 09 33 20 67 7974 67 33 34 56 8057.56 33 59 87 8140.87 33 11 57 8224.57 33 15 15 8308.15 33 20 10000 O0 8443 57 8391 57 33 33 10100 10200 10300 10400 10500 10600 10700 10800 10844 O0 8526 O0 8610 O0 8694 O0 8778 O0 8863 O0 8947 O0 9031 O0 9114 O0 9151 98 8474 56 8558 6O 8642 83 8726 15 8811 25 8895 06 8979 87 9062 75 9099 98 33 29 56 33 0 6O 32 43 83 32 26 15 32 38 25 33 3 06 33 3 87 33 3 75 33 3 VERTICAL DOGLEG RECTANGULAR COORDINATES HOR}Z. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN N 71 58 E 3955 76 N 72 29 E 4010 N 72 14 E 4065 N 72 44 E 4121 N 74 54 E 4176 N 76 19 E 4230 N 75 52 E 4284 N 75 28 E 4339 N 75 22 E 4393 N 76 3 E 4447 92 94 14 26 71 96 12 15 44 0.94 0.14 0.21 0.90 1 52 0 36 0 38 0 3O 0 59 0 55 1178 19 N 3777 36 E 3956.84 N 72 41 E 1194 1211 1228 1243 1257 1270 1283 1297 1310 94 N 3829 61N 3882 34 N 3935 76 N 3987 04 N 4040 09 N 4093 51 N 4145 20 N 4198 53 N 4250 95 E 4012.03 N 72 40 E 40 E 4067,07 N 72 40 E 03 E 4122.29 N 72 40 E 95 E 4177.40 N 72 41 E 78 E 4231.80 N 72 43 E 48 E 4285.99 N 72 46 E 97 E 4340. 10 N 72 48 E 25 E 4394.09 N 72 50 E 91 E 4448.34 N 72 52 E N 76 9 E 4502 74 N 75 44 E 4558 N 75 19 E 4614 N 75 6 E 4670 N 74 42 E 4725 N 75 9 E 4780 N 76 5 E 4836 N 75 30 E 4891 N 75 49 E 4946 N 76 19 E 5001 58 45 17 44 33 24 53 23 10 0 44 0 59 0 28 0 41 0 40 1 95 1 07 0 42 0 34 0 20 1323 81 N 4304 63 E 4503 59 N 72 54 E 1337 1351 1365 1379 1394 1408 1421 1435 1448 37 N 4358 38 N 4412 58 N 4466 96 N 4520 43 N 4573 12 N 4627 73 N 4681 34 N 4734 55 N 4787 82 E 4559 38 N 72 57 E 93 E 4615 21 N 72 58 E 82 E 4670 90 N 73 0 E 20 E 4726 15 N 73 1 E 16 E 4781 02 N 73 3 E 39 E 4836.90 N 73 4 E 01 E 4892.15 N 73 6 E 01 E 4946.82 N 73 8 E 30 E 5001.65 N 73 10 E N 77 5 E 5056 18 N 78 12 E 5111 23 N 79 30 E 5165 95 N 81 31 E 5219 78 N 83 9 E 5273 12 N 84 4 E 5326 10 N 83 50 E 5379 40 N 83 50 E 5433 14 N 83 50 E 5486.89 N 83 50 E 5510.54 0 68 0 65 1 61 0 86 0 99 016 3 48 0 O0 0 O0 0 O0 1461 28 N 4840 95 E 5056 69 N 73 12 E 1473 09 N 4894 1483 82 N 4948 1492 69 N 5002 1499 92 N 5055 1505 72 N 5109 1511.46 N 5162 1517.32 N 5217 1523.19 N 5271 1525.77 N 5295 83 E 5111 67 E 5166 13 E 522O 54 E 5273 O0 E 5326 79 E 5379 02 E 5433 25 E 5486 11 E 5510 69 N 73 15 E 34 N 73 19 E 10 N 73 23 E 35 N 73 29 E 26 N 73 35 E 49 N 73 41 E 19 N 73 47 E 91 N 73 53 E 55 N 73 56 E COMPUTATION DATE: 02-APR-91 PAGE 4 ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/ O0 FEET FEET FEET DEG MIN 0 O0 1000 2000 3000 4000 5000 6000 7000 8000 9000 0 O0 O0 995 O0 1915 O0 2701 O0 3507 O0 4335 O0 5141 O0 5948 O0 6773 O0 7610 -52.00 0 0 21 943.21 13 24 26 1863.26 34 0 57 2649.57 37 56 86 3455.86 33 35 67 4283.67 35 27 62 5089.62 37 31 77 5896.77 35 42 90 6721.90 33 48 87 7558.87 33 59 N 0 0 E N 82 26 E 63 N 73 7 E 443 N 72 20 E 1060 N 68 22 E t651 N 68 59 E 2210 N 72 36 E 2801 N 74 42 E 3391 N 71 58 E 3955 N 76 9 E 4502 0 O0 94 91 59 17 12 32 10 76 74 0 O0 3 08 3 32 0 55 0 57 0 44 1 55 0 65 0 94 0 44 0 O0 N 0 89 274 459 655 841 1013 1178 1323 0 O0 E 37 N 66 74 N 436 34 N 1024 36 N 1585 59 N 2111 13 N 2673 25 N 3237 19 N 3777 81N 4304 0.00 N 0 0 E 40 E 66.41 N 89 41 E 06 E 445.20 N 78 22 E 66 E 1060 75 N 75 1 E 99 E 1651 17 N 73 51 E 22 E 2210 66 N 72 45 E 05 E 2802 26 N 72 32 E 24 E 3392 10 N 72 37 E 36 E 3956 84 N 72 41 E 63 E 4503 59 N 72 54 E 10000.00 8443.57 8391.57 33 33 N 77 5 E 5056.18 0.68 1461.28 N 4840.95 E 5056.69 N 73 12 E 10844.00 9151.75 9099.75 33 3 N 83 50 E 5510.54 0.00 1525.77 N 5295.11 E 5510.55 N 73 56 E COMPUTATION DATE: 02-APR-91 PAGE 5 ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 0 O0 52 O0 152 O0 252 O0 352 01 452 01 552 10 652.43 753.04 854.05 0.00 52.00 152.00 252.00 352.00 452.00 552.00 652.00 752.00 852.00 -52 O0 0 O0 100 O0 200 O0 300 O0 400 O0 500 O0 600 O0 700 O0 800 O0 0 0 N 0 0 E 0 4 S 13 38 E 0 17 S 28 0 E 021 S 65 6 W 0 33 S 70 3 E 1 3 S 70 48 E 3 42 S 82 7 E 5 21 S 86 40 E 7 11 N 89 55 E 8 59 N 85 55 E 0 O0 0 O0 0 O0 -0 28 0 15 1 07 4 58 12 14 22 65 36 45 0 O0 0 62 0 O0 1 03 0 38 1 72 291 1 37 1 67 1 54 0.00 N 0.01 S 0.20 S 0.53 S 0.98 S 1.39 S 2.20 S 2.92 S 3.19 S 2.64 S 0 O0 E 0 01 E 0 06 E 0 14 W 0 44 E 1 52 E 5 40 E 13 47 E 24 48 E 38 67 E 0 O0 N 0 0 E 0 0 0 1 2 5 13 24 38 01 S 29 3 E 21 S 15 52 E 54 S 15 11W 07 S 23 58 E 06 S 47 24 E 83 S 67 47 E 78 S 77 47 E 68 S 82 34 E 76 S 86 6 E 955 70 1058 1162 1267 1372 1480 1588 1698 1810 1924 952 O0 55 1052 34 1152 02 1252 86 1352 02 1452 70 1552 77 1652 54 1752 96 1852 900 O0 12 2 O0 1000 O0 1100 O0 1200 O0 1300 O0 1400 O0 1500 O0 1600 O0 1700 O0 1800 O0 14 39 O0 16 16 O0 18 6 O0 19 54 O0 22 15 O0 23 45 O0 25 39 O0 27 29 O0 30 59 N 83 9 E N 79 48 E N 76 34 E N 74 13 E N 75 38 E N 77 19 E N 77 21 E N 76 50 E N 76 39 E N 75 9 E 54 28 78 06 105 78 136 70 171 37 209 83 252 28 298 21 348 05 403 58 3 67 2 96 1 71 2 27 1 95 2 O0 1 52 1 57 2 O8 4 17 0.85 S 2.52 N 80 8.40 N 107 16.32 N 137 25.41 N 170 34.32 N 208 43.56 N 249 53.88 N 294 65.27 N 343 78.74 N 397 56 71 E 48 E 80 63 E 107 52 E 138 98 E 172 43 E 211 95 E 253 77 E 299 35 E 349 26 E 4O4 56 72 S 89 8 E 52 N 88 12 E 96 N 85 32 E 49 N 83 14 E 86 N 81 33 E 24 N 80 39 E 72 N 80 7 E 65 N 79 38 E 50 N 79 14 E 99 N 78 47 E 2044.54 1952 O0 1900 O0 34 52 2167.71 2052 2293.91 2152 2420.46 2252 2550.62 2352 2680.26 2452 2809.52 2552 2937.18 2652 3063.93 2752 3189.93 2852 O0 2OO0 O0 2100 O0 2200 O0 2300 O0 24O0 O0 2500 O0 2600 O0 2700 O0 2800 N 72 0 E O0 37 6 N 72 15 E 540 O0 37 20 N 76 31 E 617 O0 38 59 N 75 31 E 695 O0 39 52 N 70 12 E 778 O0 39 19 N 70 55 E 860 O0 39 15 N 71 35 E 942 O0 37 54 N 71 46 E 1022 O0 37 52 N 72 53 E 1099 O0 36 59 N 71 54 E 1176 469 08 93 88 34 59 93 74 01 87 49 1 58 3 28 1 40 3 62 1 07 0 38 0 79 0 54 0 64 1 24 97 28 N 460.08 E 470 25 N 78 4 E 119 140 158 183 211 237 262 286 3O8 78 N 528.37 E 541 44 N 602.50 E 618 48 N 677.91 E 696 46 N 757.35 E 779 08 N 835.09 E 861 37 N 912.66 E 943 44 N 987,94 E 1022 09 N 1062.15 E 1100 98 N 1135.30 E 1176 78 N 77 14 E 66 N 76 53 E 19 N 76 51 E 25 N 76 23 E 35 N 75 49 E 02 N 75 25 E 20 N 75 7 E 01 N 74 56 E 6O N 74 47 E 3314 28 2952 O0 2900 O0 36 16 3438 54 3052 3563 65 3152 3688 76 3252 3811 21 3352 3932 87 3452 4053.08 3552 4173.33 3652 4292.64 3752 4411.74 3852 O0 3000 O0 3100 O0 32O0 O0 3300 O0 3400 O0 3500 O0 3600 O0 3700 O0 3800 O0 36 37 O0 37 15 O0 36 4 O0 34 57 O0 33 58 O0 33 54 O0 33 28 O0 32 35 O0 33 21 N 70 25 E 1250.29 N 71 38 E 1323.94 N 72 50 E 1399.09 N 72 25 E 1474.25 N 72 9 E 1544.87 N 69 45 E 1614.09 N 68 38 E 1680.52 N 69 13 E 1747.04 N 69 38 E 1811.90 N 70 2 E 1876.40 0 54 0 65 0 84 2 84 0 47 313 0 49 0 59 081 1 02 333.19 N 1205 13 E 1250 34 N 74 33 E 357.19 N 1274 380.21 N 1346 402.16 N 1418 424.06 N 1485 445.95 N 1551 470.18 N 1613 494.15 N 1675 517.10 N 1736 539.42 N 1797 87 E 1323 45 E 1399 34 E 1474 53 E 1544 27 E 1614 42 E 1680 75 E 1747 64 E 1811 97 N 74 21 E 10 N 74 14 E 26 N 74 10 E 87 N 74 4 E O9 N 73 58 E 53 N 73 45 E 09 N 73 34 E 99 N 73 25 E 35 E 1876.55 N 73 18 E ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA COMPUTATION DATE: 02-APR-91 PAGE 6 DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMZCA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTZCAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANG[JLAR COORDINATES HORIZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 4531 87 3952 O0 3900 O0 33 42 4652 4773 4896 5020 5142 5267 5392 5516 5639 23 4052 79 4152 74 4252 04 4352 75 4452 35 4552 55 4652 44 4752 26 4852 O0 4000 O0 4100 O0 4200 O0 4300 O0 4400 O0 4500 O0 4600 O0 4700 O0 4800 O0 34 27 O0 34 42 O0 36 12 O0 35 27 O0 35 27 O0 37 13 O0 36 34 O0 35 47 O0 35 31 N 70 24 E 1942 83 N 69 49 E 2009 N 69 42 E 2078 N 68 55 E 2149 N 69 3 E 2221 N 69 33 E 2292 N 70 58 E 2366 N 71 24 E 2441 N 72 4 E 2515 N 73 12 E 2586 66 59 85 71 56 72 96 O4 32 0 22 1 60 0 87 0 35 0 42 1 15 0 45 0 87 1 30 0 88 561 89 N 1860 02 E 1943 03 N 73 11 E 584 608 633 6,59 685 710 734 757 778 52 N 1923 41N 1987 81 N 2054 75 N 2122 O0 N 2188 07 N 2258 27 N 2329 30 N 2399 38 N 2467 05 E 2009 91 E 2078 76 E 2150 07 E 2222 55 E 2293 51 E 2367 84 E 2442 27 E 2515 37 E 2587 92 N 73 6 E 93 N 72 59 E 29 N 72 51 E 27 N 72 44 E 24 N 72 37 E 50 N 72 33 E 81 N 72 30 E 95 N 72 29 E 24 N 72 29 E 5762 78 4952 O0 4900 O0 36 8 5887 6013 6141 6267 6390 6513 6635 6758 6880 33 5O52 O0 5O0O 12 5152 O0 5100 53 5252 O0 5200 47 5352 O0 5300 69 5452 O0 5400 10 5552 O0 5500 45 5652 O0 5600 35 5752.00 5700 99 5852.00 5800 O0 37 7 O0 37 48 O0 39 4 O0 36 0 O0 35 35 O0 34 51 O0 35 36 O0 35 23 O0 35 28 N 73 20 E 2658.82 N 73 10 E 2733.05 N 72 37 E 2809.35 N 72 40 E 2889.88 N 72 1 E 2966.36 N 72 54 E 3038.32 N 73 18 E 3108.93 N 72 51 E 3179.39 N 73 48 E 3250.83 N 73 26 E 3321.83 0 19 0 57 2 3O 1 25 0 7O 0 59 0 56 0 67 0 5O 0 83 799 47 N 2536.75 E 2659 74 N 72 30 E 820 843 867 890 912 932 953 974 994 99 N 2607.80 E 2733 53 N 2680.71 E 2810 51 N 2757 61 E 2890 76 N 2830 50 E 2967 43 N 2899 15 E 3039 83 N 2966 75 E 3109 59 N 3034 10 E 3180 07 N 3102 56 E 3251 21N 3170 98 N 72 31 E 29 N 72 32 E 85 N 72 32 E 35 N 72 32 E 34 N 72 32 E 95 N 72 33 E 43 N 72 33 E 87 N 72 34 E 64 E 3322.86 N 72 35 E 7003 97 5952.00 5900 O0 35 41 7125 7245 7365 7487 7609 7730 7852 7973 8093 37 6052.00 6000 10 6152.00 6100 83 6252.00 6200 27 6352.00 6300 03 6452.00 6400 86 6552,00 6500 64 6652.00 6600 63 6752.00 6700 67 6852.00 6800 O0 33 28 O0 33 28 O0 34 34 O0 34 41 O0 34 47 O0 34 53 O0 34 39 O0 33 55 O0 33 17 N 74 44 E 3393 41 N 74 38 E 3462 N 73 54 E 3528 N 72 52 E 3595 N 73 11 E 3664 N 73 16 E 3734 N 72 31 E 3803 N 71 5 E 3873 N 71 36 E 3941 N 72 29 E 4007 21 O6 7O 59 O5 62 O5 O8 45 0 64 0 73 0 64 0 38 0 75 0 26 1 36 0 18 0 84 0 07 1013 86 N 3239 47 E 3394 42 N 72 37 E 1031 1C49 1C69 1C89 1109 1129 1151 1173 1193 96 N 33O5 81N 3369 13 N 3434 37 N 3499 28 N 3566 57 N 3633 64 N 3698 60 N 3763 89 N 3826 85 E 3463 24 E 3529 06 E 3596 92 E 3665 47 E 3735 03 E 3804 93 E 3874 41 E 3942 63 E 4008 18 N 72 40 E O0 N 72 42 E 64 N 72 42 E 54 N 72 43 E O0 N 72 43 E 58 N 72 44 E 07 N 72 42 E 15 N 72 41 E 55 N 72 40 E 8213 45 6952 O0 6900 O0 33 28 8333 8453 8572 8691 8809 8929 9049 9170 9290 43 7052 02 7152 12 7252 11 7352 96 7452 23 7552 62 7652 18 7752 67 7852 O0 7000 O0 7100 O0 7200 O0 7300 O0 7400 O0 7500 O0 7600 O0 7700 O0 7800 O0 33 33 O0 32 58 O0 32 53 O0 32 48 O0 32 40 O0 33 25 O0 34 0 O0 34 1 O0 33 48 N 72 14 E 4073 36 N 73 22 E 4139 N 76 13 E 4205 N 76 0 E 4269 N 75 30 E 4334 N 75 26 E 4398 N 76 4 E 4463 N 75 57 E 4530 N 75 21 E 4597 N 75 7 E 4664 62 20 84 30 52 48 47 78 98 0 18 1 32 1 O0 0 42 0 26 0 77 0 83 0 53 0 22 0 36 1213 87 N 3889 47 E 4074 49 N 72 40 E 1233 73 N 3952 1251 O0 N 4015 1266 41N 4078 1282 30 N 4141 1298 56 N 4203 1314.40 N 4266 1330.49 N 4331 1347.16 N 4396 1364.25 N 4461 71 E 4140 98 E 4206 8O E 4270 31 E 4335 45 E 4399 49 E 4464 56 E 4531 80 E 4598 81E 4665 77 N 72 40 E 32 N 72 42 E 88 N 72 45 E 29 N 72 48 E 46 N 72 50 E 37 N 72 53 E 30 N 72 56 E 55 N 72 58 E 72 N 73 0 E COMPUTATZON.DATE: 02-APR-91 PAGE 7 ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA COURSE MEASURED VERTICAL VERTICAL DEVIATION AZIMUTH DEPTH DEPTH DEPTH DEG MIN DEG MIN VERTICAL DOGLEG RECTANGULAR COORDINATES HORZZ. DEPARTURE SECTION SEVERITY NORTH/SOUTH EAST/WEST DIST. AZIMUTH FEET DEG/IO0 FEET FEET FEET DEG MIN 9410 66 7952 O0 7900 O0 33 18 953O 9651 9770 989O 10010 10129 10249 10368 1O486 48 8052 05 8152 64 8252 25 8352 11 8452 98 8552 35 8652 18 8752 76 8852 O0 8000 O0 8100 O0 8200 O0 8300 O0 8400 O0 8500 O0 8600 O0 8700 O0 8800 O0 34 1 O0 33 35 O0 33 11 O0 33 19 O0 33 31 O0 33 25 O0 32 47 O0 32 35 O0 32 38 N 74 39 E 4731.29 N 75 42 E 4797 29 N 75 45 E 4864 60 N 75 40 E 4930 15 N 76 16 E 4995 74 N 77 11 E 5061 76 N 78 28 E 5127 71 N 80 39 E 5192 59 N 82 35 E 5256.22 N 84 6 E 5319.07 0 34 1 62 1 02 0 40 0 10 0 73 0 56 I 05 1 15 0 07 1381 50 N 4525 85 E 4732 O0 N 73 2 E 1398 1415 1431 1447 1462 1476 1488 1497 1504 69 N 4589 04 N 4654 37 N 4718 28 N 4782 52 N 4846 43 N 4911 44 N 4975 80 N 5038 98 N 5101 57 E 4797 97 N 73 3 E 91 E 4865 24 N 73 5 E 42 E 4930 75 N 73 7 E 09 E 4996 30 N 73 10 E 39 E 5062 26 N 73 12 E 02 E 5128 15 N 73 16 E 06 E 5192 95 N 73 21 E 58 E 5256.49 N 73 27 E 89 E 5319.24 N 73 34 E 10605.67 8952.00 8900.00 33 3 10724.99 9052.00 9000.00 33 3 10844.00 9151.75 9099.75 33 3 N 83 50 E 5382.44 N 83 50 E 5446.57 N 83 50 E 5510.54 0.00 0.00 0.00 1511.79 N 5165.86 E 5382.53 N 73 41 E 1518.79 N 5230.57 E 5446.61 N 73 49 E 1525.77 N 5295.11 E 5510.55 N 73 56 E COMPUTATION DATE: 02-APR-91 PAGE 8 ARCO ALASKA INC. D.S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER 10.75" CASING TOP SAD ZONE 2 LAST READING GCT ZONE lB BASE SAD PBTD 7.625" CASING TD DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA INTERPOLATED VALUES FOR CHOSEN HORIZONS SURFACE LOCATION = 1170' FSL & 113' FWL, SEC1 TION R15E,UM MEASURED DEPTH BELOW KB TVD FROM KB SUB-SEA RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 4009.00 10443.00 10443.00 10600.30 10613.00 10686.O0 ~0750.00 10833.00 10844.00 3515.35 8815.12 8815.12 8947.50 8958.14 9019.32 9072.96 9142.53 9151.75 3463 35 8763 12 8763 12 8895 50 8906 14 8967 32 9020 96 9090 53 9099 75 461.20 N 1502.51N 1502.51 N 1511.48 N 1512.22 N 1516.50 N 1520.25 N 1525.12 N 1525.77 N 1590 62 E 5078 47 E 5078 47 E 5162 95 E 5169 83 E 5209 42 E 5244 13 E 5289 14 E 5295 11 E ARCO ALASKA INC. D. S. 9-47 PRUDHOE BAY NORTH SLOPE, ALASKA MARKER 10.75" CASING TOP SAD ZONE 2 LAST READING GCT ZONE lB BASE SAD PBTD 7.625" CASING TD COMPUTATION DATE: 02-APR-91 PAGE 9 DATE OF SURVEY: 27-FEB-1991 KELLY BUSHING ELEVATION: 52.00 FT ENGINEER: JEFF FORMICA ************ STRATIGRAPHIC SUMMARY ******~**~** , SURFACE LOCATION = 1170' FSL & 113' FWL, SEC1 TION R15E,UM MEASURED DEPTH TVD BELOW KB FROM KB SUB-SEA 4009.00 10443 O0 10443 O0 106O0 3O 10613 O0 10686 O0 10750 O0 10833 O0 10844 O0 3515 35 8815 12 8815 12 8947 50 8958 14 9019 32 9072 96 9142 53 9151 75 3463.35 8763 12 8763 12 8895 5O 8906 14 8967 32 9020 96 9090 53 9099 75 RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST 461 20 N 1502 51N 1502 51N 1511 48 N 1512 22 N 1516 50 N 1520 25 N 1525 12 N 1525 77 N 1590 62 E 5078 47 E 5078 47 E 5162 95 E 5169 83 E 5209 42 E 5244 13 E 5289 14 E 5295 11 E FINAL WELL LOCATION AT TD: TRUE SUB-SEA MEASURED VERTICAL VERTICAL DEPTH DEPTH DEPTH HORIZONTAL DEPARTURE DISTANCE AZIMUTH FEET DEG MIN 10844.00 9151.75 9099.75 5510.55 N 73 56 E SCHLUMBEROER D I RECT I ONAL SURVEY COMPANY ARCO ALASKA INC. NELL O.S. 9-47 FIELO PRUOHOE BAY COUNTRY USA RUN ONE DATE LOOOEO 27 - FEB - REFERENCE 74403 ~VELL: D.S. 9-47 .. (1170' FSL, 113' FWL, SEC 1, T10N, R15E, UM) IORIZONTAL PROJECTION NORTH S000 4OOO 3OOO 2000 1000 -]000 -2000 ~XJTH -9000 REF ?4409 SCALE = 1/lO00 IN/FT -~.--~.~..~- -~..;..4..~4-~..~.~.-~.-.-~-~ t ~ ~ .~-4-.~- L4..-;-~.-;-~-.~. ~...~-.;...~...;.--~...~..4...~..,...L..;...'~.. ;..L .i ........ ~..~..~.-~-~..~ -~..4.-~.+~-~.. -~-~.-~-, -4..4~...&- ;.~.4..~-.~..~.-~..~..~ ...... ,..., ..... L. ;...;...;.. ~..; ...... L..;...~...-..,..L..~ .~_.~ ~ i i ; ~ · - ~ : ; ~ ~ : ~ ~ ~ ! ~ ; ~ ; : : ~ : ~ ~ : ; ~ ~ ; : : : , - : ~ : ~ ; ~ · . - .... ~ , . · ~.-~-~..~.~-4.+- -~-,-.~.~. ~-~ ~.~...~....~--~-.~.~.....~..,....---~ .... ~..-~ ....... .....--~...,-~-.~.~-.~ ......... ;...~...;.~...?....~ .... ; ....... 4 ........... ...4 ................... ... ~ ~...~... -&~+.~-; ....... M.--;.-~-&.&--T~.J..4..-..-4~-&..;-~...L4...L...4...L ;...L..L~.4..Z...L.....4...;-.;..L..;.. &. 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'":"'~ '~'"~" ?: .......... ~ ....... ~'"J'"7':"':'"? i'"-~"!"'!'+'J-i'"!'"i'"i ....... :r~-':"?'?-' H?-i"?";."-l-?'h'h'? "'h'!"";'"?",'"f-f'.:'"h'~ '"?'h~'"!'"!'":'"t'"t ..... .':-~"T"~'"??'~'''?'~' !"':'"~ ......... :'": :": ..... ~":'"1"~":"~':"7' 7OO0 74, PROJECTION ON VERTICIqL PLANE 74. - 2S4. SCALED IN VERTICAL D~PTH~ HORIZ SCALE = 1/I000 IN/FT AOGCC GEOLOGICAL N~ATE.~.iALS iNYENTORY LiST PERMIT # (::JO - I L~ WELL NANiE ~j~)~), COMPLETION DATE ~) } ~ ] c~l CO, CONTACT check off or list data as it is rcceivedTlist received date for 407. if not reo, uired list as NR 407 1 * q--z~--~/I I drillina history' I v'~ su~e¥1 v"t ,~ell tests i O ~ core descriptio~ cored intewals j core analysis !~ dw ditch intcwals . ,,~ digital data i ! I I i ,, 'I i , .'N~ 'l'~rlc i ri, lit, i ,klTcr.,~,,i .~ SCALE Lg~l I I FL. ! riLg114 ! Irkl I LrlLIliI,II~L~-ll I NO.j [to thc nearest foot] [inchl!00'J ii i i i ! , \ 1 o ~--t o15":) i j \ to~$- 1~?15 i I ,.i tO ~D - ARCO ALASKA, INC, ANCHORAGE, ALASKA 995~ D A ]" E ' 3 ..... i,...")- c.,,. t A R C 0 C A ;S: E D H 0 I_ E F" I N A I....? ~" i - i ii': '2 .... 2. Il.'.< -9 i P I) K - t 0 0 / C- R / C C I... x,5 .... i B ',2 -',2 '5 .... 9 t )} I F F:' Ii'.". R E N T I A L T E H F:' E R A "l' U F;:. E .-4 .... i B .,-..°-'":":':,:..., .... c:'i,- PDI<--t P'O/i'"IF:'F',,, , ,. f".'ORF;: .... ji.'Ii';MA '" 3 -" 5 :3 '- S "- 9 t C 0 L I.. A R --4-t 2..,-.')-"') 4~.. _.o,. t CCL '-? .... :$ S .... 5"" 9 t C 0 I_ !_ A R / F:' r-z I:;: I:: " "';' i (3 C L "%; ..... 40 ,:.~ .... i .... : 4{¢ '-9-47 2-27-9t C..,R/COL. I_ AI-R ca '-,.?.-47 ',.:..-':!?..-,? ',.4;..,> _. 4 '72 - 2 '7 "- 9 t C Ii'7. T '--9~,'a 7 3-'4-9t PFi:ODUCT ION F:'ACK ER '~9.-48 '2-28-9t [.;BT --,41; ..... 4. F.::._ .,-.."~ ... ,:..":' o...... .... .:>, 1 C E T "~,::;., ..... :.'t. :ii!: .... 5::' .... ,;..":' :.:° ... 9 i [.; R / C f'i... I... I... A F:.'. "' i 3 .... 5;' n 2 "" ',2 '.5 - 9 t C N !_ - -I" H E F:.'. ?"i A I.. ~i S .... '::""" "': '"': '"' ....... , .::, ,:_' '- ,,:...;-"' ',', t r': i'~ .... IT F:' I 'f' I..I lei F;: N A !... "% 3 -" o.,, !ii .,'""- .... - ..... 2 ";', o,. i f). ...... ! I A t._ I N D I J C l" I 0 N '".M /' -'- ':'- '::, .... 9 ';', .... o i C i'i I.. I... A I:;, · "y ,...~ .-... .,... -.... .." ..... ~ -. "~ 4 '.}" -Z .... · ',"-.-,.-: i -,. , i I),S' N 4i- ,~ -~ ,Z) ")' ~::' -. .::.- ,-, ,:., .... ..; .... 9 i {:; C L & F:' 0 I:;,' 0 """" A 'l' L.. A ,S' RUN i , .,. F;:UN t , :5'" A'I'I_A,5; ~<" A T I... A ,S' RLJN t,., 5 A'T L (.:, RtJN i, " RLJN i, .5" ATI...AS I;,'UNi, .'5" A'f'I..AS Fi:UN i , 5" AI'L.A.S' I;:tJNt, 2'&LS" SCH F;..'LJi'.J i , ") "' ~:'" ' ..... . ,... ~:,.; ,.,.. C.. I..I RtJN t, 2"&.5" .SCH RUN t ~ 5" ~'I'L.~,S' · 'o'" &'5" ..~CIq RLJN {, .. RLJN t, 2"&.5" ,S'CH "'"" 'i,r I:;" I! , , RUN t, ,: ...... - SC~"~ I:i'{ ..... IN 3 55, '::'~" ,.,s' C H I;,'UN3"5, '5" SCH R { ! N ."~':< 5" .S' C !'.t IRtJN i, 5" ATI_A::.;' RLJN 1, 5' Ht...,S' ':~" ATI_A£' RUN t, .., i::'i. IE A ,? E S I (.'.; N A N I) ,-:. I::. 'i" lJ R iq T H E A T T A C I-.I E D C 0 I::' Y A S R Iii: C Iii; I F' T 0 I-:' I;, A 'T' ¢.;~ HA",/E A NICE DAY! D I ,'.:.-.' l' Fi.' I B U 3' I ii) N '"' C ['!:N'¥RAL.. FIL. E$ '11' C I..I Iii; ",/' R 0 N D & ?.i "" '" 0 Fi.' A l' I 0 N · ,,-E X T E N,:, I N Ii:.. X F:'L. £) · ~ E X X 0 iq bi A Fi: A 1" H 0 N :~ H 0 B I i_ ':":' 'r t"t IE A F:' I ~ F' 0 R t6-'8 I,.5/ 50-029-.20549, ~: F:' H I I.. L. I F'S F'B WEL. L F:ILE.,S' R & I) :~: B P X · ,- STA'FE OF ALASKA I'EXACO RECEIVED I AR I 8 1991 Alaska 011 Ii GaS Cons. Commission Anchorage APPLICATION FOR SUNDRY APPROVAL 1. Type of Request: Abandon _ Suspend _ Operation Shutdown ~ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Perforate _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB) Development X ARCO Alaska. Inc. Exploratory _ RKB 52' feet ,3. Address Stratigraphic _ 7. Unit or Property name P. O. Box 100360, Anchorage, AK 99510 Service _ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 1170' FSL, 113' FWL, Sec. 1, T10N, R15E, UM ~)-47 At top of productive interval 9. Permit number 2600' FNL, 4917' FEL, Sec. 6, T10N, R16E, UM (APPROX) 90-146 At effective depth 10. APl number 2629' FNL, 156' FWL, Sec. 6, T10N, R16E, UM (APPROX) 50-029-22098 At total depth 11. Field/Pool Prudhoe Bay Field 2629' FNL, 156' FWL, Sec. 6, T10N, R16E, UM (APPROX) Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 10844' feet Plugs (measured) None true vertical 91 41 ' feet Effective depth: measured 10844' feet Junk (measured) None true vertical 91 41 ' feet Casing Length Size Cemented Measured depth True vertical depth Conductor 8 0' 2 0" '40 sx AS cmt 1 1 5' 11 3' Surface 3976' 1 0-3/4" 1335 sx CS III & 4009' 3527' 320 sx Class G - Top job w/300 sx CS II Production 1 0800' 7-5/8" 275 sx ARC & 1 0833' 91 32' 225 sx CS I Perforation depth' measured None RE(~EiVEp true vertical N o n e FEB 1 ¢ t991 Tubing (size, grade, and measured depth None Alaska Oil & Gas Cons. Commission Packers and SSSV (type and measured depth) Anchorage None 13. Attachments Description summary of proposal _ Detailed operation program __ BOP sketch_ Well Histor~ 14. Estimated date for commencing operation 15. Status of well classification as: 2/25/91 Oil X Gas __ Suspended _ 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed (,~ ~ ~~u.~ _, Title Drillincj Analyst Date (', FOR COMMISSION USE ONLY IApproval No. Conditions of approval: Notify Commission so representative may witness Plug integrity _ BOP Test_ Location clearance__ ~40~ , Mechanical Integrity Test _ Subsequent form require 10- Approved by the order of the Commission ORIGINAL SIGNED BY : Commissioner Date J-'2 (~ -- ~'// i~1 I Form 10-403 Rev 06/15/88 LONNIE~ u. ~m!"l'H SUBMIT IN TRIPLICATE Inillal Report- D~iI: m~ t~ ~ gMng In~ls~v~ d~t~ only. District ARCO ALASKA ~leld PRUDHOE BAY Ol~rator ARCO Spudded or W.O. begun NORTH SLOPE [ Lom~Unlt ADL: 28345 ~' DRILL API: 50-029-22098 SPUD al Of 8;00 I.m. 12/04/90 ( TD: 0'( SUPV:LP AK JARCO W.I. Prior status if a W.O. 12/04/90 Comgl~ meer~ for east day _ml~_ ft~l NABORS 28~ 9-47 18:00 12/05/90 ( TD: 855'( SUPV:LP 12/06/90 ( TD: 1970'( SUPV:LP 12/07/90 ( TD: 3322'( SUPV:LP 1) RIG MOVE. MW: 0.0 ViS: 0 0) MOVING RIG F/ 9-3 TO 9-47. 2) 855) DAILY:S14,505 CUM:$14,505 ETD:SO EFC:$2,301,4~5 DRILLING SURF. HOLE MW: 8.7 VIS:300 ' MOVE F/9-3 TO 9-47, NIPPLE UP DIVERTER, TAKE ON WATER IN PITS P/U BHA CHANGE STAB. BLADES,MIX SPUD MUD, FUNCTION TEST HYDRIL AND DIVERTER SYSTEM - DRILL F/ 110' TO 396' , SLIDE F/396' TO 456', CHANGE SWAB IN MUD PUqdP 9 1 , DRILL SLIDE F/ 456' TO 546'- CHANGE SWAB AND LINER IN #2 MUD PUMP, DRILL F/546' TO 8 55' DAILY:S66,848 CUM:$81,353 ETD:S50,000 EFC:$2,318,253 DRILLING SURF.HOLE MW: 8.9 VIS:340 DRILL 855'MD - 1718' MD. PUMP SURVEY,, CIRC BTTMS UP , DROP SS ,PUMP PILL, POOH , C/O BIT #1, C/O DYNADRILL ORIENT - RIH, DRILL F/1718 - 1970'MD. DAILY:S83,581 CUM:$164,934 ETD:S150,000 EFC:$2,301,834 3) 115) 21.7800 · MW: 9.0 VIS:300 F/ 1790'-2282'. CBU. POOH. L/D B~A. RIH. DRLG F/ 1322' ~81,792 CUM:$246,726 ETD:$250,000 EFC:$2,283,626 12/08/90 TD: 4019' SUPV:LP 12/09/90 ( TD: 4019'( SUPV:L~ 1 4 Alaska Oil & G~s Cons. Co~ssi°~ 'Anchomge O) HOLE TO RUN CSG.10-3/4"@ 4009' MW: 9.4 VIS:400 F/3322'MD TO 4019' MD , CIRC. BTTMS UP, PUMP PILL POO~ ,SWABBING ,PULL SLOW FILL HOLE THROUGH DRILL PIPE, CLF,%N STABILIZERS , L/D MOTOR , BIT X/O P/U BIT SUB + 92 BIT. RIH BRIDGE AT 2950'MD. WASH AND REAM F/2950'MD TO 3041'MD RIH, WASH F/2950'MD TO 4019'MD . CIRC.BTTMS UP,DROP SURV~ + PUMP PILL, POOH TIGHT F/ 2715'MD TO 2558'MD. TIGHT AGAIN @ 2500'MD , KELLY UP + ~ 8 JTS TO 2750'MD. DAILY:S60,958 CUM:$307,684 ~TD:$290,000 ~FC:$2,304,584 N/U ROPE 10-3/4"@ 4009' MW: 0.0 VIS: 0 RF. JtM THRU TIGHT SPOT ,RIH TO BTTM., CIRC. AND CONDITION MUD, POOH , TIGHT 2800'MD TO 2600'MD , WORKKD THROUGH + CLEANED HOLE. R/U TO RUN 10-3/4 CSG. CIRC.AND COND. MUD. PUMP 100 BBLS ~20, DROP BTTM PLUG, TEST CMNT. LINES TO 3000 PSI. PUMP 456 BBI,S(1335 SX) CS III LEAD SLURRY 12.2 PPG. PUMP 65 BBL,(320 SH) CLASS G TAIL SLURRY , DROP TOP .. PLUG DISPLACE W/ RIG PUMPS @ 13.5 BPM BUMP PLUG W/2000 PSI , CK FLOATS RECIPROCATE PIPE THRU OUT CMNT. JOB CIP @ 2000 HRS. PERFORM TOP JOB W/ 300 SX CS II. DAILY:S214,257 CUM:~521,941 ETD:S700,000 EFC:$2,108,841 Fer form i)ml:mrmlo~ ~ dl~'lbmlon, ~ laro~ldurl~ MI,lUll, ~,1~]~ 10, Drilling, P~ ~ Im:l ~7. JNuml~m' MI ~ ~ ~ ~ ~v~ly ARCO Oil and Gas Company Daily Well History--Inter If~itn~ti~l~: This lorm is u~ld dutil~ d~lllng or wescor o~rltJo~. If lesti~g, corl~, or Dedora(lflg. show ~ormaho~ ni~e m ~escr~bin~ work Oe~lOrmed. NumDer Ill ~rill slim tlltl ~U~II~Iy. A~ dl~rlplion el Ill corel. Work DlrfOrmld Dy Producing Section will ~l rlpOqld On "ln~rl~" S~eels unuI f,nal comolltto~. RO~ offici~ or ~p~ t~ Off "F~II" fO~. 1) Submit "lflll/i~" S~eet9 w~en filled out but not less frequently t~an every 30 days. o~ ,2) O~ Wedne~ay Ot the w~k in wRich otl IH~ il HI. Submit w~kiy for workovl~ eno following setting of oil 5{r,nG untd cOmDlltlOn. Di~ltric! ICoumy or PeriSh i Slale ARCO ALASKA INC. I NORTH SLOPE PRUDHOE BAY ~ DS 9-47 ComDIIII reCord for each day w~ill drilling or workov/r m progrl~ NABORS ! Dale and ClelOtrl al of 8;00 a.m. 12/10/90 ( TD: 4020'( SUPV:LP 12/11/90 ( TD: 6040'( SUPV:LP 12/12/90 ( TD: 7155'( SUPV:LP RECEIV ,D 12/13/90 ( TD: 8085'( SUPV:ZR 12/14/90 ( TD: 9100'( SUPV:ZR 1) ) 020) 9) 115) 0) 930) 1) 015) 2) 620) 3) 560) 12/15/90 ( TD: 9720'( SUPV:ZR 12/16/90 ( TD:10280' ( SUPV:ZR FEB 4 i99' 2/17/9o ( Alaska..0il & Gas Cons. Com~tS~to~ solveD: zo**0,: ZR ( For IO~l?t Pre~anltion and diltril3ulion sit ~rOCldur~l Mlnull Slclior! 10, Drilling, Plgll ~ Ifil ~? .4) 498) AK POOH 10-3/4"@ 4009' MW: 8.8 VIS: 32. N/U FMC WELLHEAD + BOPE, TEST BOPE, L/D 13-1/2 BHA ,P/U 9-7/8 BHA, RIH TO 1047' CUT AND SLIP 104' DRILL LINE, RIH TAG FC @ 3924' MD , CIRC ,TEST CSG.TO 3000 PSI. DRILL F/C + HARD CEMENT TO 3999'MD , DRILL RF_24AINING CMNT.+ SHOE, DRILL 10' NEW HOLE TO 4029' ADT-.25 HRS. CIRC. BTTMS UP ,PERFORM LOT - F,24W 12.7 PPG POOH TO L/D T£LECO TOOL DUE TO FAILURE. DAILY:S99,248 CUM:$621,189 ETD:S750,000 EFC:$2,158,089 DRILLING. 10-3/4"@ 4009' H'W: 9.1 vis: 45 POOH. C/O TELECO MWD. RIH. DRLG F/ 4029'-6040' DAILY:S83,488 CUM:$704,677 ETD:S750,000 EFC:$2,241,577 DRILLING. 10-3/4"@ 4009' MW: 9.5 ViS: 46 DRLG F/ 6040'-6078'. CIRC HIGH VIS SWEEP. DROP SURVEY. POOH. RIH. REAM F~ 6018'-6078' DRLG F/ 6078'-7155'. DAILY:S69,755 CUM:$774,432 ETD:S950,000 EFC:$2,111,332 P/U BHA #8. 10-3/4"@ 4009' MW: 9.6 VIS: 42 DRLG F/ 7155'-7975' CBU. SHORT TRIP TO 6630' DRLG F/ 7975'-8085' CIRC LOW/HIGH VIS SWEEP. DROP SS SURVEY. POOH. C/O BHA. DAILY:S69,394 CUM:$843,826 ETD:S1,025,000 EFC:$2,105,726 DRILLING. 10-3/4"@ 4009' MW: 9.7 VIS: 61 RIH. DRLG F/ 8085'-9100'. DAILY:S60,283 CUM:$904,109 ETD:S1,100,000 EFC:$2,09'1,009 DRILLING. 10-3/4"@ 4009' MW: 9.8 VIS: 45 DRLG F/ 9100'-9487'. CBU. SHORT TRIP. DRLG F/ 9457'-9692'. CBU. DROP SURVEY. POOH. M/U BHA. RIH. RF~ TO BTM F/ 9610-9692'. DAILY:S75,959 CUM:$980,068 ETD:S1,140,000 EFC:$2,126,968 10-3/4"@ 4009' MW: 9.8 VIS: 49 DRILLING. DRLG F/ 9720'-10280'. DAILY:S54,730 CUM:$1,034,798 ETD:S1,160,000 EFC:$2,161,698 DRILLING. 10-3/4"@ 4009' MW: 9.8 VIS: 48 SHORT TRIP 13 STDS. DRLG F/ 10280'-10458' CIRC SEEP. SHORT TRIP. DRLG F/ 10458'-10778'. DAILY:S61,592 CUM:$1,096,390 ETD:S1,575,000 EFC:$1,808,290 Iwe]l nO AR3B-459-2-B INumOe7 all -'la,iv well hlSlOry ~OrmS consecdl,~ely i:' -'-- ": as they are predated for each *ell i ARCO 01, and Ga. Company 0 Daily Wall History--Inter II~ll~getl 1'~il formal il ~111~1 ~l~/J~l drllll~ or ~r ~ltiOnl. ~f tithing, coring, or peHOr/llng, show formilion nl~e ~n deKr~bing work performed. NUmar ~l ~dl[ It~ t; ~- ~ ~fl~lOfl Ol Ill CO~I. WO~ ~rfO~ ~y Producing ~tion will Be ~ld On "lnlHm" ,h~ll unlll ~inal comDlltfOn. RI~ offi¢l~ or ~~ ~ ~ "~" ~o~. 1) Su~m~t "1~1~" s~Hll w~l~ fillea out ~ut nol Itll Ir~u~lly th~ eve~ ~ ~lyl, o; {2) on WldnlHly Of the wNk i~ wh~ ~1 ~ ii ~. ~mit wHkly for worko~ ~o following ~lt~ng 01 0~1 sirenG until complel~on. OillrJct Fie~d ! I County or Parilh ARCO ALASKA INC. J NORTH SLOPE I Lia, or unit I DS 9-47 AK al of 8:(X~ a.m. PRUDHOE BAY Coml~lll[O record i'or eacI1 cls~¥ while drilling or workover ~n progr~u NABORS 28E 12/18/90 ( TD:10844' ( SUPV:ZR 12/19/90 ( TD:10844' ( SUPV:ZR 12/20/90 ( TD:10844 PB: 0 SUPV:ZR JWell nO 1 ) 66) 1, ) O) LOGGING RUN #2. 10-3/4"@ 4009' MW: 9.9 VIS: 45 DRLG F~ 10788'-10844' CBU. S~OR~ TRIP 30 STDS. CIRC 50 BBLS SWEEP. POOH. R/U ATLAS WL. M/U LOGGING TOOLS. RUN #1 GR/SP/DIL/BHCS. RUN #2 GR/CNL/LDT. DAILY:S52,958 CUM:$1,149,348 ETD:S1,400,000 EFC:$2,036,248 RIH W/ 7-5/8" CSG. 10-3/4"@ 4009' MW: 9.9 VIS: 50 CONT'D LOG RUN#2 GR/CNL/LDT. TEST BOPE. M/U BIT & BHA. RIH. WASH 60' TO BTM. CIRC SWEEP. POOH. TEST BOPE TO 3000 PSI. RUN 7-5/8" CSG. DAILY:S45,331 CUM:$1,194,679 ETD:S1,550,000 EFC:$1,931,579 L/D DP. 7-5/8"@10833' MW: 9.3 NaCl RIH W/ 7-5/8" CSG. PUMP 50 BBLS ARCO PREFLUSH, 50 BBLS ARCO SPACER @ 10.5 PPG 127 BBLS MTC @ 12 PPB, 50 BBLS SPACER @ 13 PPB, 80 BBLS (275 SX) ARC SLURRY. BUMP PLUG W/ 2000 PSI. INSTALL FMC PACKOFF. PUMP 30 BBLS FRESH WATER DOWN ANNULUS FOR ARCTIC PACK. RETURNS IN CELLAR BOX. MIXED 10 BBLS DESCO PILL. PUMP AS TRACER W/ 180 BBLS. NO TRACER ON SURFACE. CONT'D ARCTIC PACK W/ 225 SX CSI, 95 BBLS ARCTIC PACK. L/D 5" DP. DAILY:S44,276 CUM:$1,238,955 ETD:S1,238,955 EFC:$2,286,900 RE .EIVED Alaska Oil & Gas Cons. Commiss/o[t Ai~cl~orage ThO Ill. vi il corrlct For form ~l~-plrl~lo~t' ina dilt,bu[ion ~ PrOC~u~ M~U~ ~tJon 10, Ddlling Supt. AR3B-459-2-8 NumOer all ..1ally well nl$1oty torres al Inly are orepared for each well ARCO Operator Spudded or W.O. begun .. . lC;ounty or Parilh Lelt~ or Unit Title . - hie ~ ~ Of WI Il M~ ~M ~ ~ld. ~l~le I~ ~ ll~. ~ ~ ~ ~ ~1~ t~ 11 not ~. ~ "~ ~' fo~ m~ ~ ~ ~ ~1~ ~ ~tlm A~ountlng colt center code .... State AK ~TtT, , , . , Date ~d deptll 21_ 7.q n _n I A.fi. Co. W.I. I ~ Il'la I~n Dill ,.minoRs Coml~et. record for ea~ da~ repor~l ~'~,~ · , 18) RIG ~~ ~ ]~nn ~m~ ~-=/a.a,.. ..... . . "' K DRY HOL~ T~;. TEST~ BPV. RIG 12/20/90. r%.~_ DAILY:S342,546 C~:$1,581,501 ETD:$~,581,501 EFC:$2~286~00 otal nurnl~er of welll (ICtlVl Or inactive) on this~ Olt cente~ prior to plugging and / bindonml~t of tl¥lltW~l. IHOUr -u; vv IPrler ltatul If a W.O. F'E/~ 1 4 ~99~ Ala$~ .Oil.& Gas Cons. Commissi0~ Anchorage- Old TO j New 'rD { PB 0ti)th I Relelled rig I Date I Kind of I Cla~iflcetlonl (o11, gll, etC.) Ty~ completion (llngle, dull, itc,) Producing method OfflclII m#rvoir Potlfltlat tilt dill Date .... ~r ' ' Produ(~ing Interval 011 or galTe~ tiTM Production , 011 on tilt Gal ]' ~1~ co--ted ~ ..... . . AR3B-459-3-C Humber Itl dilly alii hi#cpi fOnT~ cona~'utlv~ly il t~ Ire p/~ for el(at well, RECEIVED JAN 9 1991 Alaska Oil & Gas Cons, Commission Anchorage ARCO AI...ASKA, INC,. F',. O,. .BOX t O.?)T~60 A N C H (] R A (; E, A L A,'~Z K A ).') F:',, ]" E · i 2'. .... 2 E:-. 9 .... .-5 ':2 ? 5;: .... ..':i. 7 ( I:;t A t..,J ) ( F:' (] i';..' t-.i ) r::'~ i !... ,,'::'~ ,':-:.' r:;'~ "i 1._ A ,'? ...... i':'.'l i I... is:~ ,':':.' i,-'; i I._ I'.:i ..I A i" i... A ,ti.: F':'~ 'i i... A ;5' A T'i... A A 'f'i... r:~ ;ii: (':'l 'i' i... A ,~i.' .%.' .h 4. RECEIVED ,JAN ~, tOqi Alaska 0il a Gas Cons. Anchorage ARCC~ ALASKA: INC~ P~O~ BOX ~00¥60 A N C H 0 R A (; E, ~. L A,:, K A .[:: i[ ,5' .... F;.i ;ii E: i...i "i' ]; [) ,jAN ~ 1991 Alaska Oil & GaS Cons. Anchorage 41® ~2e $~ · 2~e ~e ~2 LEGEND · EXISTING ~ELLS · CONOUCTOR AS-BUILT THIS SURVEY WELL A.S.P. PLANT CEOOETIC CELLAR LOCATION BOX IN SECTION NO. COORDS. COORDS. POSITION ELEV. 47 5.942,641.0,3 N 1379.70 148'14'05.436" "1170' FSL 19.67 718.499.15 E 1653.1,5 70'14'45.107" 113' FWL LOCATED WITHIN PROTRACTED SECTION 1. TION. R15E. UMIAT MERIDIAN, ALASKA. i/ ®10 e12 el? eli e21 e22 VICINITY MAP NOTES 1. BASIS OF LOCATION PER LO~JNSBURY AND ASS(XL ORIGINAL AS-BUILT OF WELL ~13 AND 11114 DATED FEB. 1977. 2. COORDINATES SHOWN ARE ALASKA STATE PLANE ZONE 4.. 3. ELEVATIONS SHOWN AEE: ARCO DA'nJM (M.L. LW.), 4. REFERENCE FIELD BOOK: PB 90-4,5 (P. 50-5.3) DATE OF SUI~VEY: 11/6/90 SURVEYOR'S CERTIFICATE · I HEREBY CERTIFY THAT [ AM PRO- PERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION AND THAT ALL DIMEN- SIONS AND OTHER DETAILS ARE CORRECT AS 1990. F. ROBERT BELL SC ASSOC. ARCO Alaska Inc. DRILL SITE 9 CONDUCTOR AS-BUILT WELL # DS9- 4-7 J J. FENTIE J BARNHART ' TB '~'~'~N.T.S. AS-BUILT @ NORTH SLOPE IJMFJ REVISIONS ! DRAWNI CHECK INSDP! ooooJCEA-2721-004 · R. BELL PA2011AA 12°~ "' ~1 o TO: THRU: ? Commissioner ! ' State of Alaska GAS CONSERVATION COF/~ISSION DATE: December 20, 1990 FILE NO: JT. I4H. 12 2 0.6 TELEPHONE NO: SUBJECT: BOP test AAI PBU 9-47 Pea-mit No. 90-46 Prudhoe Oil Pool FROM: Harold R. Hawkins Petroleum Inspector Sunda~/_December 9, 1990: I witnessed the BOP test on AAI PBU 9-47. There were two failure%-. I filled out an AOGCC iield report which is attached. in summary: The two failures were worked on and put back in service and tested o.k. The BOP test, when completed, was tested satisfactorily by Nabors 28E crew for AAI PBU at DS 9-47. Attachment. 02-001A (Rev. 6/89) 20/11LVIEMO1.PM3 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Inspection Report TEST: Initial ~// Weekl y.~ Other Representative ~ ~'~ Y/~Z~ f~ y~ ~ Casing set ~ U~ ~ OPERATION: Drig~ ~// Wkvr~ ,4 hl Well ~)jF Location: Sec ~tm T Drlg contrct~ ~/~y~ Location (general) Housekeeping (general) Reserve pit~. Well s i gn~t// Ri g m/rMF MUD SYSTEMS: Visual Trip tank ~/ Pit gauge · ., ,~ Flow monitor ~/ Gas detectors /// Audio ACCUMULATOR SYSTEM: ft Full charge pressure ,,,,,?(__b~ L~ psig Press after closure //J~r~ psig Pump incr clos press 200 psig ~ min /J see Full charge press attained / min ~/J> sec Controls: Master o t~j7 Remote ,. O~j7 B1 ind switch cover ~Jy/~y KELLY AND FLOOR SAFETY VALVES: ~ Upper Kelly BOPE STACK: Test Pressure Lower Kelly Annular preventer ~ ~T> Ball type Pipe rams ,~-~P Inside BOP Blind rams .~-~ ~ Choke manifold Choke line valves ~9~'~ Number valves HCR valve ~-'~ Number flanges Kill line valves ~--~ ~F Adjustable chokes Check valve //~//~ Hydraulically operated choke Test pressure ..:.~'j ~'~ Test pressure Test pressure ... J~'~ Test pressure Test pressure TEST RESULTS: Failures ~. Test time X hfs ~ ~Iw'>~ '. Repair or replacement of failed equipment to be made within ~ 'days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Distribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 05/10/90) WITNESS Telecopy No. (907) 276-7542 October 31, 1990 J D Giltespie Regional Drilling Engr ARCO Alaska, ~nc P 0 Box 100360 Anchorage, A2K 99510-0360 Re ~ Prudhoe Bay Unit DS 9-47 ~2iCO Alaska, inc Permit # 90-146 Surf Loc l170'FSL, li3'~L, Sec 1, T10N, RlSE, UM Btmho!e Loc 2577'FNL, 193'FWL, Sec 6, T10N, R16E, UM Dear Mr Gillespie: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you irom obtaining additional permits required by law from other gover~nnental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The Commission will advise you of those BOPE tests that it wishes to witness. Sincerely, · · David W Joh~ston Commissioner BY O~ER OF .THE COI~MiSSION enci C: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl - STATE OF ALASKA "- 0/~/~,~//~4 ALASKA ~,L AND GAS CONSERVATION CL..,,IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill ~ Redrill lb. Type of well. Exploratory ~ Stratigraphic Test ~ Development Oil Re-Entry - Deepen Service - DevelopementGas ,- Single Zone ~ Multiple Zone 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface ll70'FSL, ll3'FWL, Sec. 1, T10N, R15E, UM At top of productive interval 2600'FNL, 4917'FEL, Sec. 6, T10N, R16E, UM At total depth 2577'FNL, 193'FWL, Sec. 6, TiON, R16E, UM 12. Distance to nearest property line 193' feet 13. Distance to nearest well D~9~-al~ 600' TVD/MDfoet 16. To be completed for deviated wells 35°15, Kickoff depth 50o ' feet Maximum hole angle 30" 13-1/2 ,,. 9-7/8 ~on~in 18. Casing program size Hole Casing 20" " 10-3/4' "7-518" D- l/' ~-" cency 9-7/8 7-5/8" 19. Specifications WeightI Grade I CouplingI Length I I 2~.7~ I ~-sol e~c ¢08o8' 5. Datum Elevation (DF or KB) RKB 52 ' feet 6. Pr(~{,et(t..y 9~j%it~nation ADL: 28345 7. Unit or property Name Prudhoe Bay Unit 8. Well number PBU DS 9-47 9. Approximate spud date 11/07/90 14. Number of acres in property 2560 10. Field and Pool Prudhoe Bay Field Prudhoe Bay Oil Pool 11. ~pe Bond(see20AAC25.025) Statewide Number No. U-630610 Amount $200,000 15. Proposed depth (MD and TVD) i~{~:~D feet 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Maximum surface 2 8 0 0 psig At total depth R'VD) 3 7 0 0 r psig Setting Depth Top Bottom MD ] TVD ] MD ! TVD 35'I 35'I 115! 115' 33,/ 33,! 3963[ 3500' 31'/ Quantity of cement (include stage data) 280 sx CS II 1311 sx CS III/317 sx 280 sx E1 'G 700 sx ~± u 240 sx C1 G I 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 Length Size Cemented Measured depth True Vertical depth Casing Structural Conductor Surface RECEIVED Intermediate Production OCT2. ¢, 1990 Liner Perforation depth: measured ~sk~ 0il & Gas Cons. true vertical ,,,.,.~1_~_ 0[~..~-:,=.:: _.:. 20. Attachments Filing fee ~ Property plat [] BOP Sketch I~ Diverter Sketch :B Drilling program ,~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis [] Seabed report ,% 20 AAC 25.050 requirements 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed,~.L' ' /I'~,,,,~_~.C,~2./¢~ Title Regional Drilling Engineer //// ,~¢;/ Commission Use Only ~Z~/,~(MRC ) PD4/011 Permit Nu~'i:)er ! APl rfumber J Approval date I See cover letter ?0-/?'¢3" 50--o2_?- 2 2-,:, ¢ F 10/31/90 for other requirements Conditions of approval Samples required F-l,, Yes ~ No Mud log required ~ Yes ~ No .m, No Hydrogen sulfide.measures lq Yes ,,l~'No Directional.survey required ,~ Yes Required working pressure for BOPE FI2M; [] 3M; ,~ 5M; [] 10M; [] 15M Other: Approve Commissioner Form 10-401 Rev. 12-1-8~ by order of the commission I Date Submit in triplicate J CL G o Antcipated BHP: 3700 psi (8.0 ppg EMW) @ 8800' TVD o Maximum Anticipated Surface Pressure: 2800 psi o Planned Completion Fluid: 8.6 ppg Seawater PBU DS 9-47 OPERATIONS SUMMARY 1. MIRU drilling rig. NU diverter and function test same. 2. Drill 10-3/4" hole to 500' TVD/MD. 3. Kick off and build angle at 2.5 degrees/100 ft. to 35 deg 15' in the N 74 deg 1' E direction. End of build is at 1822' TVD / 1910' MD. Drill to 3963' MD / 3500' TVD. 4. Set 10-3/4" casing and cement same. Nipple up BOPE and test to 5000 psi. 5. Pick up 9-7/8" BHA and RIH. Test casing to 3000 psi for 30 minutes. Drill 10' of new hole and perform leakoff test. 6. Drill 9-7/8" hole to 8797' TVD, 10450'MD,( 10 "TVD above Sadlerochit top). 7. Set 7-5/8" casing and cement same. 8. Pick up 6-3/4" BHA ,GIH. Test casing to 3000 psi. 9. Drill 10' of new hole and perform EMW test. 10. Drill 6-3/4" hole to TD @ 9114' TVD,10839'MD, condition hole to run OH logs 11. Run wireline logs as programmed. 12. Set 5-1/2" liner and cement same. 13. Clean out the liner and test liner to 3000 psi for 30 minutes. Circulate well to brine. 14. Run cased hole logs. 15. Run 4-1/2 tubing and packer assembly with GLMs, treater string and SSSV. Test tubing and casing to 3000 psi. Freeze protect with diesel. 16. N/U tree and test to 5000 psi. Release drilling dg. 17. Rig up wireline unit and perforate. NOTE: In the event that the mud weight requirement is less than or equal to 10 ppg at the intermediate csg. point( 8797' TV D/10450' M D) the option to drill the 9-7/8" hole to TD (9114TVD ,10839'MD will be evaluated. DS 9-41,DS9-42& DS9-43 required a 9.8 PlXJ mud weight to drill the K5 shale interval. NOTE; a. PBU DS 9-47 OPERATIONS SUMMARY CONT. Excess non-hazardous fluids developed from the well operations and as necessary to control the reserve pit fluid level will be pumped down the 9-5/8" x 13-3/8" annulus. The annulus will be left with a non-freezing fluid during any extended period. The annulus will be sealed with 300 sx of cement followed by Arctic Pack. b. Minimum distances of wells within 200 ft. of the proposed well are: o DS 9-13: 59.00' @ 0' MD / 0q'VD o DS 9-10: 59.00' @ 600' MD / 600' TVD o DS 9-12: 179' @ 0'MD / 0' TVD o DS 9-11 : 176' @ 800'MD / 799' TVD c. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.033. d. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). e. Based on previous logs on DS 9, no potential productive zones are antidpated above 3500' TVD. f. No potential hazardous levels of H2S are anticipated in this well. DS 9-47 MUD PROGRAM DEPTH DENSITY VIS YP INT 10MIN FL OIL SOLIDS MUD (TVD) (PPG) GELS GELS CC/30MIN (%) (%) TYPE SPUD 8.8 300 70 30+ 50+ 25 0 2 GEL-BENEX to to to to to SPUD MUD 13-3/8" 9.2 100 40 6 csg pt. SET 10-3/4" CASING DEPTH DENSITY PV YP INT 10 min FL OIL SOLIDS MUD (TVD) (PPG) (CP) (#/ft GEL GEL cc/30min (%) (%) TYPE 13-3/8" 8.7 10 6 2 4 25 0 2 LIGHTLY to to to to to to to to TREATED 5000 9.0 15 16 4 10 10 9 POLYMER 5000 9.0 15 16 4 10 10 0 9 LIGHTLY to to to to to to to to TREATED 9-5/8" 10.0 20 25 6 12 6 11 POLYMER csg pt. SET 7-5/8" CASING DEPTH DENSITY PV YP INT 10min FL OIL SOLIDS MUD (TVD) (PG) (CP) (#/ft) GEL GEL cc/30min (%) (%) TYPE 9-5/8" 8.7 10 6 2 1 8 0 4 LIGHTLY to to to to to to to to TREATED TD 9,2 15 10 4 10 6 6 POLYMER SET5-1/2" LINER THIS MUD PROGRAM IS ONLY A GUIDELINE. ACTUAL HOLE CONDITIONS WILL DICTATE THE ACTUAL MUD PROPERTIES. NABORS 28E MUD SYSTEM PIT #1 130 BBLS PIT #2 81 BBLS PIT #5 117 BBLS PI?.?. PIT 20 BBLS PIT #6 135 BBLS TRIP TANK 170 BBLS PIT #3 137 BBLS PIT $4 179 BBLS EQUIPS~m~f - DRILLING FLUID SYSTEM (3) DERRICK FLO-LINE C?,~.ANER (1) DERRICK MUD C?.~.ANER (1) B~ANDT CF-2 CENTR~~ (1) PIONEER MARK I CENTRIFUGE (1) RIG BUILT GAS BUSTER (1) DRILCO DEGASSER (1) PVT SENSOR PER PIT w/ visual and audio warning devices (1) AGITATOR PER PIT (1) DRI?.?.ING FLOW SHOW SENSOR W/ readout convenient to the driller's console 13-5/8" 5000 psi BOP STACK DIAGRAM I PIPE RAM BLIND RAIVIS i~ I DRILLING PIPE RAMS CASING SPOOL ACCUMULATOR CAPACITY TEST 1. CHECK AND FILL ACCUMULATOR RESERVIOR TO THE PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURE THAT THE ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH THE CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRES- SURE. 13-5/8" STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH A NON-FREEZING FLUID. 2. CHECK THAT ALL HOLD DOWN SCREWS ARE FULLY RETRACTED. MARK THE RUNNING JOINT WITH PREDETERMINED PLUG SEATING DEPTH. RUN THE TEST PLUG ON DRILL PIPE AND SEAT IN WELL- HEAD. 3. CLOSE ANNULAR PREVENTER AND UPSTREAM VALVES . 4. FUNCTION TEST CHOKES. 5. IN EACH TEST, FIRST HOLD 250 PSI FOR 3 MINUTES PRIOR TO THE HIGH PPRERSSURE TEST. 6. INCREASE PRESSURE ON ANNULAR TO 3000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 7. OPEN ANNULAR PREVENTER AND CLOSE TOP PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 8. CLOSE VALVES DIRECTLY UPSTREAM OF THE CHOKES AND OPEN CHOKES. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 9. OPEN TOP SET OF PIPE RAMS. CLOSE BOTTOM PIPE RAMS. INCREASE PRESSURE TO 5000 PSI AND HOLD FOR 3 MINUTES. BLEED PRESSURE TO ZERO. 10. TEST REMAINING MANIFOLD VALVES (IF ANY) WITH 5000 PSI UPSTREAM OF THE VALVE AND ZERO PRESSURE DOWNSTREAM. 11. BLEED PRESSURE TO ZERO. OPEN BOTTOM PIPE RAMS. 12. BACK OFF RUNNING JOINT AND POH. CLOSE BLIND RAMS AND TEST TO 5000 PSI FOR 3 MINUTES. 13. BLEED OFF ALL PRESSURE. OPEN BLIND RAMS. FILL MANIFOLD AND LINES WITH NON-FREEZING FLUID. SET ALL VALVES IN THE DRILLING POSITION. 14. TEST STANDPIPE VALVES TO 5000 PSI. 15. CHECK DEGASSER OPERATION. 16. RECORD BOP TEST INFORMATION ON THE BOP TEST FORM SIGN AND SEND TO DRILLING SUPERVISOR. 17. PERFORM COMPLETE BOP TEST WEEKLY AND FUNCTION TEST DAILY. NABORS 28E DIVERTER SYSTEM ARCO ALASKA, INC. FILL-UP UNE RISER FLOWUNE I 20" :2O(X) PSI DIVERTER I 1(7' BALL VALVE I I I 1(7' BALL VALVE I I I CONDUCTOR I NOTE: ONLY ONE VALVE OPENS AUTOMATICALLY WHEN THE DIVERTER CLOSES. THE SECOND VALVE WILL REMAIN CLOSED UNLESS CONDITIONS REQUIRE THE USE OF THE SECOND VENT LINE. THE SECOND VENT LINE VALVE CAN BE OPENED USING CONTROLS LOCATED AT THE ACCUMULATOR. THIS IS THIS IS A VARIANCE FROM 20AAC25.035. RESERVE PIT 10" VENT LINE 10" VENT UNE DIVERTER LINES DISCHARGE 100 FT. FROM RIG IGNITION SOURCE. ALL TURNS ARE TARGETED TEE& 0 1000 204Yd 3~ ~ ~ ~ ~ ~ T I I I T I I I I T I T ~ r T I T ~ T T r I I I r I I I T T I I T r ( I r I I I ~ I r I ~ ; ., 0 RI(~ I~/PiVATION 52' "~-~. ~" C~g ~112 ~112 ~0 AR{ O DS9-.47SL [HOLE ] LI~ ~AT ~. 1~ 1~ 15.0 ~7.~ SHL: U 1 gN 15E 1 1170' FSI, 113' ~L THL: U I~N 16E 6 26~' ~ 4917' FEL BHL: U 10N 16E 6 2577' ~ 193' ~L ~o N 74 1' E '~1822 ~1910 D~20 ). ~4~ C~g ~=35~ ~3~3 D~=l~5 ~-i ~5¢ ~=5188 D~=2311 K-15 T~5107 T~=5931 I~E~2740 K-10 ~D=7~7 ~9323 D ~-5 ~8~2 ~9782 D~963 7-5/8 C~g ~87~ ~1~50 D~=5~8 L~ ~=8805 ~=1~62 DE~53~;5 BASE i~L~O~ ~ ~2 T~=1~89 D~ =5486 T~G~ ~ ~2 T~1~89 DEP::~86 ~ ~= }114 ~=10839 DEI'=5573 · I .............................................................. _ 1000 2000- 3000 4000 5000' 6OOO 7000 8000 9OO0 10000- 6~ VERTICAL SECTION 7000 (8) ------' (9 :~== (.1. o and. (14 =hr= Z2) ---- (22 :ac= 28)- _ (29 :hr~ 31) rev: 01/30/89 6.0IL · Company_ //~%. ,, i · YES NO 1. Is the permit fee at:ached ~ ........................................ ~'. ~ II ' Z. Is well to' be locauad in a defined pool ............................. 3. Is well located proper distance from properly line .................. 4. Is well located proper distauce from other wells ........ ~ ........... 5. is sufficient undedicated acreage available iQ this pool ............ 6. Is well :o be deviated and is we!lbore pla: included ................ 7. Is operator :he only affected parly ......... i ....................... 8. Can permi: be approved before fifteen-day wait ...................... 9. Does operator have a bond im force .................................. 10. is a conser~ra:ion order needed ...................................... I!. Is admin~s:ra=ive approva~ needed ................................... lZ.' Is :he lease number appropriate ..................................... 13. Does the wall have a un/qua marne a~d n~mber ..................... ' .... 14. IS c6nduc~or'string provided ........................................ 15. Will surface casing protect ~ zones reasonably ~xpected serve as an u=derground source of drinking wa=er ..................... 16. Is enough cemen: used ~:o circulate on conduc:or and suvaco ......... I7. W~i!l cement uie in surface and intarmediaue or production 18. Wi3_! camamg cover ~ kmo~ produc=ive horizons ..................... !9. Wi3.1 al! casing give adequate safety in colla=se, :e~sion and burst.. 20. Is this well :o be kicked off from an e~Lsting ~e!lbore ............. 21. Is old weL!bore abamdommen: procedure included on 10-403 ............ 22. Is adequate weilbore separation proposed ..................... .' ...... 23. Is a ~iver:ar system required ....................................... 24. Is :he dri!3.ing fluid program schematic amd !is: of eq~ipmen: adequate 25. Are necessaz7 ~iagr~-~ and descriptions of diver=ar and BOPE 26. Does BOPE have sufficient pressure rating - Test to ~'oo~ 17. Does =he choke manifold comply =/A~Z 33-53 (~ay 84) .................. 28. Is =he presence of E25 gas probable ............................. ~... For e~--p, loratory amd S=ra:igrap. hic yeller 29. Are data presen=ed on potamtia! overpress~re zones? ................. 30. Are seismic a~a,~ysis data presem=ed on sha3_lo~ gas zones .............. 31. If am offshore loc., are ~r~ey res~s of seabed condO:ions prese-~:ed 3Z. Addi:iom~l req~.iremm~:s ............................................. iiiii ii i i Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information-of this nature is accumulated at the end of the file under APPENDIX. .. No special 'effort has been made to chronologically organize this category of information. PkOGRAM: LISCAN REVISION: 5.2 Start of execution: Fri 21 DEC 90 8:03a **** REEL HEADER **** LIS 90/12/21 AWS 01 PART NUMBER: W5790-MICRO **** TAPE HEADER **** LIS 90/12/21 01 FILE LIS **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 9 - 47 : PRUDHOE BAY : N. SLOPE : ALASKA * COMMENT RECORD * API NO. 50-029-22098-00. LOGGED ON 18 DEC,1990. TD NOT LOGGED DUE TO HOLE PROBLEM. FILE 1 : MAIN PASS DIFL - AC. FILE 2 : MAIN PASS ZDL - CN - GR. FILE 3 : REPEAT SECTION DIFL - AC. FILE 4 : REPEAT SECTION ZDL - CN - GR. * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 11 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 AC 68 1 US/F 4 RECEIVED JAN 1,99! Alaska Oil & 8as Cons. Commission Anchorage 2 CHT 3. CILD 4 GR 5 RFOC 6 RILD 7 RILM 8 SP 9 SPD 10 TEMP 11 TTEN 68 68 68 68 68 68 68 68 68 68 1 1- 1 1 1 1 1 1 1 1 LBF 4 MMHO 4 API 4 OHlV~ 4 OHMM 4 OHM~ 4 MV 4 F/MN 4 DEGF 4 LBF 4 * DATA RECORD DEPTH RFOC TEMP 10780.000 -999.2500 -999.2500 10730.000 4.635892 162.7685 10680.000 9.107214 163.4434 10630.000 15.36908 163.7656 10580.000 9.318754 163.3341 10530.000 12.77836 162.7296 10480.000 7.222782 162.0670 10430.000 6.751933 161.0540 10380.000 4.273598 159.8584 10330.000 6.381219 158.5598 10280.000 0.2000000 0.0000000E+00- (TYPE# AC RILD TTEN -999.2500 -999.2500 -999.2500 86.90886 3.974608 6744.492 80.13747 5.851732 6633.148 $6~68924 14.52459 6796.578 76.39941 9.237888 6697.039 84.10100 13.00488 6712.754 85.27248 4.015009 6666.707 103.5598 4.712218 6585.695 102.1390 2.403936 6565.977 99.71007 3.793924 6479.035 104.9368 0.2000000 5000.000 o) 1014 BYTES * CHT RILM -999.2500 -999.2500 1063.515 4.014894 978.0376 6.863348 1073.950 13.00702 1081.940 10.61032 1065.892 15.87619 1033.350 4.114045 989.5386 4.918670 982.5725 2.599506 927.4302 3.947619 500.0000 0.2000000 CILD SP -999.2500 -999.2500 251.5971 -999.2500 170.8896 19.10443 68.84874 -24.71344 108.2498 3.103592 76.89424 -16.53740 249.0655 -51.62590 212.2143 1. 030029 415.9844 4.136292 263.57'93 8.851364 0.0000000E+00 11.36047 GR SPD -999.2500 -999.2500 0.0000000E+00 23.03931 96.43158 23.40390 49.40189 22.99770 80.72446 22.99770 69.94539 23.03340 32.96707 22.99770 159.4319 22.99770 229.8889 22.99770 260.0242 23.99760 343.1848 0.0000000E+00 ~OTAL DATA RECORDS : 52 STARTING TAPE DEPTH = 10780.00 ENDING TAPE DEPTH = 10240.00 **** FILE TRAILER **** **** REEL HEADER **** LIS 90/12/21 AWS 01 **** TAPE HEADER **** LIS 90/12/21 01 FILE ~ 2 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA INCORPORATED : D.S. 9 - 47 : : : * FOR/V~AT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 20 CURVES : NAME CODE SAMPLE~ UNIT 1 CAL 68 1 IN 2 CHT 68 1 LBF 3 CN 68 1 % 4 CNC 68 1 % 5 DEV 68 1 DEG 6 GR 68 1 API 7 HRD1 68 1 CPS 8 HRD2 68 1 CPS 9 LSN 68 1 CPS 10 PE 68 1 BARN 11 PORZ 68 1 % 12 RB 68 1 DEG 13 SFT2 68 1 DIM BYTES 4 4 4 4 4 4 4 4 4 4 4 4 4 14 SHR 151 SPD 16 SSD 17 SSN 18 TTEN 19 ZCOR 20 ZDEN 68 68 68 68 68 68 68 1 1 1 1 1 1 1 DIM 4 F/MN 4 CPS 4 CPS 4 LBF 4 G/C3 4 G/C3 4 DATA RECORD DEPTH DEV PE SPD ZDEN 10700.000 -999.2500 -999.2500 -999.2500 -999.2500 10650.000 368.3347 2.351535 17.99820 2.211636 10600.000 368.3347 2.962300 24.02150 2.228169 10550.000 368.3347 3.285254 24.99750 2.452626 10500.000 367.5339 2.710869 24.99750 2.180226 10450.000 365.2732 3.610870 24.99750 2.575809 10400.000 363.4070 4.027214 24.99750 2.389771 10350.000 361.9255 2.905579 24.99750 2.301190 (TYPE~ CAL GR PORZ SSD -999.2500 -999.2500 -999.2500 -999.2500 9.090139 44.93999 26.56752 10929.70 8.711700 .45°42551 25.56548 11419.09 8.799780 94.27060 11.96203 11110.48 9.153358 39.65298 28.47112 10727.66 9.407660 97.73009 4.496373 9335.773 9.657801 241.6643 15.77147 10504.18 10.32168 205.6423 21.13997 11075.55 0) 1014 BYTES * CHT HRD1 RB SSN -999.2500 -999.2500 -999.2500 -999.2500 1308.702 2124.980 -1.841253 190.8309 1471.000 2199.392 -1.841253 .180.8056 1441.970 1569.825 0.4946752 148.4728 1443.885 2198.589 2.681581 197.5723 1387.269 1061.187 4.217371 160.3349 1296.807 1519.942 5.215652 128.3973 1331.125 1895.283 5.809328 135.0546 CN HRD2 SFT2 TTEN -999.2500 -999.2500 -999.2500 -999.2500 21.17281 2583.639 1869.972 6463.074 25.54094 2688.258 1867.802 6878.273 28.32529 1938.016 1321.400 6783.258 21.39684 2592.264 1901.146 7013.910 26.83165 1299.481 854.1172 6884.988 54.71849 2020.524 1274. 173 6713.445 43.50218 2370.248 1558.067 6848.973 CNC' LSN SHR ZCOR -999.2500 -999.2500 -999.2500 -999.2500 26.25719 101.0516 0.6875081 0.7648885E-01 30.56734 86.10381 0.6173611 0.1094964 33.31531 67.30769 0.5857871 0.1830472 26.47836 102.4371 0.6444310 0.5265365E-01 31.84149 75.88660 0.5571229 0.1278697 58.70895 44.53381 0.5244391 0.1240608 48.01691 50.66461 0.6232660 0.1203964 10300.0.00 360.7568 5.978733 24.99750 2. 658012 10.35892 1241.831 46.96658 51.31947 188.6082 748.3247 1039.178 52.48610 -0.4856225 6.230224 545.4543 0.4132170 8229.703 141.5779 6740.477 0.8527970E-01 10250.000 10.28707 1221.627 45.19904 49.63440 359.8201 228.5565 1459.181 1927.598 52.07339 -3.973277 14.49279 6.480661 1166.690 0.5284460 24.99750 10374.18 138.0360 6768.730 0.1250378 2.410869 10200.000 10.82587 1205.376 45.52470 49.94510 359.0986 251.0062 1537.372 2019.438 48.35780 3.756925 18.12485 6.590167 1237.337 0.5451840 25.00340 10140.84 136.5746 6652.746 0.8732051E-01 2.350940 TOTAL DATA RECORDS : STARTING TAPE DEPTH = **** FILE TRAILER **** 91 10700.00 ENDING TAPE DEPTH = 10160.00 **** REEL HEADER **** LIS 90/12/21 AWS 01 **** TAPE HEADER **** LIS 90/12/21 01 FILE # 3 LIS .001 **** FILE HEADER **** 1024 CN WN FN COUN STAT ARCO ALASKA INCORPORATED D.S. 9 - 47 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 11 5 6 7 8 9 10 11 CURVES : NAME CODE SAMPLE# UNIT 1 AC 68 1 US/F 2 CHT 68 1 LBF 3 CILD 68 1 MMHO 4 GR 68 1 API RFOC 68 1 OHMM RILD 68 1 OPIMM RILM 68 1 OHMM SP 68 1 MV SPD 68 1 F/MN TEMP 68 1 DEGF TTEN 68 1 LBF BYTES 4 4 4 4 4 4 4 4 4 4 4 * DATA RECORD (TYPE# 0) DEPTH AC RFOC RILD TEMP TTEN 10810.000 0.2000000 0.0000000E+00 10760.000 5.849332 162.6190 10710.000 5.565187 162.7186 10660.000 10.69946 162.9281 10610.000 9.320955 162.9338 10560.000 15.33510 162.5806 10510.000 8.532295 162.0327 10460.000 15.89981 161.4381 10410.000 9.165148 160.5890 50.00000 0.2000000 5000.000 83.28035 4.072331 8621.496 81.98679 4.705156 6501.199 88.84506 5.533715 6785.555 88.12486 4.636501 6798.078 93.36296 11.19344 6720.453 75.88771 7.569603 6598.184 77.93509 15.68819 6620.883 100.1570 6.101438 6537.766 1014 BYTES * CHT RILM 500.0000 0.2000000 1125.529 3.634753 1043.591 4.892544 1162.901 5.901121 1172.775 5.583715 1024.529 11.33006 1032.400 7.691590 1015.080 16.40442 975.3083 6.151359 CILD SP 0.0000000E+00 -80.00000 245.5596 20.06465 212.5328 -52.68474 180.7104 56.48798 215.6798 21.54956 89.33801 20.81386 132.1073 33.47174 63.74220 41.26233 163.8958 8.687454 GR SPD 0.0000000E+00 0.0000000E+00 0.0000000E+00 24.99750 100.8148 24.99750 55.25981 24.99161 44.99864 24.99750 34.70360 24.99750 86.04858 24.99750 65.77390 24.59131 251.6433 24.99750 10360.000 100.5576 944.9856 323.6367 204.4413 '4.268547 159.5706 ; 10310.000 6. 029664 158.5643 10260.000 0.2000000 0.0000000E+00 3.089884 6471.559 101.8402 2.902966 6429.797 50.00000 0.2000000 5000.000 3.161155 17.38358 24.99750 937.1321 3.067738 500.0000 0.2000000 344.4753 -10.28999 0.0000000E+00 -80.00000 178.2434 24.99750 255.7464 0.0000000E+00 TOTAL DATA'~RECORDS : STARTING TAPE DEPTH = FILE TRAILER **** 55 10810.00 ENDING TAPE DEPTH = 10240.00 **** REEL HEADER **** LIS 90/12/21 AWS 01 **** TAPE HEADER **** LIS 90/12/21 01 FILE ~ 4 LIS .001 **** FILE HEADER **** 1024 CN : WN : FN : COUN : STAT : ARCO ALASKA INCORPORATED D.S. 9 - 47 FORMAT RECORD (TYPE~ 64) ONE DEPTH PER FRAME TAPE DEPTH UNIT : F 20 CURVES : NAME CODE SAMPLE# UNIT BYTES 1 CAL 68 1 2 ,. CHT 68 1- 3 CN 68 1 4 ~ CNC 68 1 5 DEV 68 1 6 GR 68 1 7 HRD 1 68 1 8 HRD2 68 1 9 LSN 68 1 10 PE 68 1 11 PORZ 68 1 12 RB 68 1 13 SFT~ 68 1 14 SHR 68 1 15 SPD 68 1 16 SSD 68 1 17 SSN 68 1 18 TTEN 68 1 19 ZCOR 68 1 20 ZDEN 68 1 IN 4 LBF 4 % 4 % 4 DEG 4 API 4 CPS 4 CPS 4 CPS 4 BARN 4 % 4 DEG 4 DIM 4 DIM 4 F/MN 4 CPS 4 CPS 4 LBF 4 G/C3 4 G/C3 4 * DATA RECORD DEPTH DEV PE SPD ZDEN 10700.000 -999.2500 -999,2500 -999.2500 -999.2500 10650.000 368.3347 2.569616 22.99770 2.160632 10600.000 368.3347 2.960118 22.99770 2.159743 10550.000 368.3347 3.518673 22.99770 2.355935 10500.000 368.3347 2.895475 22.99770 2.131829 10450.000 366.2041 3.231492 22.99770 (TYPE# CAL GR PORZ SSD -999.~n~00 -999.2500 -999.2500 -999.2500 8.333260 45.20720 29.65865 12011.73 8.049431 42.10510 29.71251 12311.61 8.112305 93.50375 .17.82210 12713.72 8.325558 40.11052 31.40427 11731.79 8.617088 96.44473 12.85958 10391.18 0) 1014 BYTES * CHT HRD1 RB SSN -999.2500 -999.2500 -999.2500 -999.2500 1352.941 2593.561 -1.841253 189.4004 1520.996 2635.183 -1.841253 182.0316 1544.237 2117.175 -1.841253 144.4167 1475.217 2592.499 0.8401999 196.6807 1477.377 1499.764 3.264614 154.0587 CN HRD2 SFT2 TTEN -999.2500 -999.2500 -999.2500 -999.2500 21.03816 3107.980 2211.336 6524.285 24.93797 3266.125 2191.445 6845.984 27.73433 2652.175 1698.080 6909.680 22.40874 3150.354 2201.782 6779.777 27.23329 1772.538 1238.524 6855.652 CNC LSN SHR ZCOR -999.2500 -999.2500 -999.2500 -999.2500 26.12413 100.8081 0.6607080 0.1129045 29.97275 87.22200 0.6175860 0.1274288 32.73241 66.36580 0.5649420 0.2255490 27.47673 98.53639 0.6243299 0.8712757E-01 32.23708 71.16631 0.5908132 0.1368337 ~.437817 10400.000 9.184748 1433.103 55.54053 59.49242 364.0918 237.7058 1667.926 2121.244 41.94420 3.551525 17.69408 4.732932 1339.184 0.5621300 22.99770 10712.26 130.2432 6740.727 0.1231305 2.358047 TOTAL DATA RECORDS : 57 STARTING TAPE DEPTH = 10700.00 ENDING TAPE DEPTH = 10360.00 **** FILE TRAI~ER **** **** TAPE TRAILER **** LIS 90/12/21 01 TOTAL RECORDS IN THIS LOGICAL TAPE : 283 **** REEL TRAILER **** LIS 90/12/21 AWS 01 TOTAL RECORDS IN THIS LOGICAL REEL : TOTAL RECORDS IN THIS PHYSICAL REEL: End of execution: Fri 21 DEC 90 8:03a Elapsed execUtion time = 37.95 seconds. SYSTEM RETURN CODE = 0 284 284
