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182-104
RECEIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION DEC 11 2014 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,CC la. Well Status: ❑Oil El Gas 0 SPLUG ❑Other ®Abandoned ❑Suspended lb. Well Class 20AAC 25105 20AAC 25 110 0 Exploratory 0 Stratigraphic ❑GINJ 0 WINJ ®WAG 0 WDSPL 0 Other No. of Completions Zero ❑ Development ® Service • 2. Operator Name: 5. Date Comp., Susp.,or Aband.:. 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/16/2014 • 182-104 ' 314-403 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 07/05/1982 50-029-20771-00-00 ' 4a. Location of Well(Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 07/19/1982 PBU S-09 1642' FNL, 1635' FWL, Sec. 35,T12N, R12E, UM 8. KB(ft above MSL): 66.98' 15. Field/Pool(s) Top of Productive Horizon: Prudhoe Bay/Aurora 3745'FNL, 265' FWL, Sec. 35,T12N, R12E, UM GL(ft above MSL): 37.66' Prudhoe Bay/Kuparuk River Pool Total Depth: 9. Plug Back Depth(MD+TVD) Prudhoe Bay /Prudhoe Bay 4950' FNL,679' FEL, Sec. 34,T12N, R12E, UM 2726' • 2726' • 4b. Location of Well(State Base Plane Coordinates, NAD. 10.Total Depth(MD+TVD) 16. Property Designation: • Surface: x- 619797 ' y- 5979855 • Zone- ASP4 •10480' ' 9218' • ADL 028257&028258 TPI: x- 618463 y- 5977730 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 617541 y- 5976511 Zone- ASP4 None 18. Directional Survey: CI 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 1870' (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: DIL/FDC/CNL/SP/GR/CAL, DIL/BHCS/GR/SP, CBL/VDL/GR/CCL, USIT 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"x 30" Insulated Conductor 30' 110' 30' 110' 36" 8 cu yds Concrete 13-3/8" 72# L-80 30' 2678' 30' 2678' 17-1/2" 3720 cu ft Arcticset II 9-5/8" 47# L-80 28' 10480' 28' 9218' 12-1/4" 2058 Cu ft Class'G',700 cu ft Class'G',130 cu ft Arcticset I 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#x 5-1/2", 17#, L-80 9806'; 7312'/6562',9499'/8328';9702'/ 8508' • A 4-1/2", 12.6#L-80 10250'- 10261' 10250'/9006' j/' 26. ACID, FRACTURE,CEMENT SQUEEZE,ETC. f i11iiy WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No SCANNED FEB 2 0 2015 Lir i DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Injection N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period 4 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ® No Sidewall Core(s)Acquired? El 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 Form 10-407 Revised 10/2012 CONTINUED ON REVERSEubmit Original Only V RSC _ , ,\ MP JAN '- a LU`l'& 29 GEOLOGIC MARKERS(List all formations an iters encounter 30. FORMATION TESTS NAME ,,j ND Well Tested? ,J Yes 0 No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Schrader Bluff NA 5307' 4981' None Base Schrader Bluff 5863' 5411' Kuparuk C 7570' 6764' Kuparuk D 7570' 6764' Kuparuk B 7605' 6791' Kuparuk A 7626' 6807' Miluveach 7715' 6876' Sag River 9931' 8715' Shublik 9975' 8755' Ivishak 10062' 8835' 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: Takahiro Kosaka,564-5994 Email. Takahiro.Kosaka@bp.com Printed Name: Joe Lastufk Title: Drilling Technologist Signature: Phone 564-4091Date: 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 WELL NAME: S-09 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9693' 64 Bbls Class 'G' 7520' Set CIBP 7259' - 7263' Tubing Punch 6960' 26 Bbls Class 'G' 2934' Cut & Pull Tubing 2747' Set EZSV 2726' Set Whipstock S-09, Well History (Pre-Rig Sidetrack) Date Summary 08/15/14 CTU#9 1.75"QT-1000(CV=31.1)Job Objective: Plug and Abandon. MIRU/Weekly BOP test RIH w/2" BDN, Displaced well 1.5 times with 1% kcl, established baseline WHP. 430 psi and 1120 psi at 1 bpm, tagged TD at 10193'. Batched cement time of 22:34, pumped 64 bbls 15.8#Class G cement. 08/16/14 CTU#9 1.75"QT-1000(CV=31.1)Job Objective: Plug and Abandon. Obtained 700 psi bump with Cement top calculated 9338'with 29 bbls behind pipe, POOH with FP to 3000'. RIH w/PDS GR/CCL logging tools&3.65" nz,tag cement top at 9693'corrected depth to log, log up with flags at 7450'and 7200'. Performed Passing MIT-T to 2562 psi., downloaded good data with-11'correction. 08/17/14 CTU#9 1.75"QT-1000(CV=31.1)Job Objective: Plug and Abandon. RIH with WFD 4 1/2"CIBP, OAL 14.87'. Set CIBP 7520',tagged after setting. RIH w/1.56"x 10'Tubing punch stop at flag @ 7200' correct to 7192.8 top shot. Stop at 7258'top shot bottom shot 7263'. Circulated 700 bls 1% kcl T to IA and 155 bbls diesel do IA, RIH with 2" BDN, coil wts are not correct and POOH to inspect. 08/18/14 CTU#9 1.75"QT-1000(CV=31.1)Job Objective: Plug and Abandon. POOH to inspect load cell as downhole weight reading incorrect. Replaced wiring and RBIH with 2" BDN. Batch up cement start time on cement 07:17 AM/Laid in 26 bbls of of 15.8#cement pushed 13 bbls into IA and cleaned out to 7060'est cement top.Freeze protected well w/38 bbls of diesel. RDMO. 8/22/14 TLH Update: "Plug& Abandon"work descr requires"Depth Set/Tag/Pulled (Final)"depth to be entered. 08/18/14 DRIFT TO&TAG TOC w/3.70"CENT, 3.00"SAMPLE BAILER @ 6,960'SLM.(no issues, sample of cement recovered). 08/19/14 T/I/O=vac/vac/vac Temp=Sl CMIT TxIA 3500 psi PASSED(Pre Rig) Pumped 8.7 bbls of 40*diesel down IA and TBG @ the same time to reach 3500 psi for CMIT Tx IA 1st test 1st 15 min TxIA lost 33/48 psi 2nd 15 min lost 25/18 psi for a total of 58/66 psi in 30 min Re-psi w/.1 bbl 2nd test 1st 15 min lost 17/13 2nd 15 min lost 18/13 for a total of 35/26 psi in 30 min Re-psi w/.1 bbl 3rd test 1st 15 min lost 14/15 2nd 15 min 13/09 for a total of 27/24psi in 30 min Bleed TxIAP down bleed back aprox 8 bbls AFE sign hung and tags hung on wing and IA casing valve Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp"s=98/98/vac. 08/19/14 INITIAL T/I/O=0/180/0. CURRENTLY RIGGING UP ELINE UNIT TO PERFORM TBG CUT. 08/20/14 RIH WITH 4.5"TBG JET CUTTER. JET CUT TBG @ 2934'[CCL TO CUTTER= 14.1', CCL STOP DEPTH =2919.9']. TUBING SUCCESSFULLY CUT. RDMO. FINAL T/I/O =50/50/0. 08/20/14 T/I/0=49/69/0,Temp=S/I, CMIT-TxIA PASSED to 3500 psi (Pre Rig) Pressured up tubing and IA with 7 bbls diesel to reach 3521/3500 psi. CMIT-TxIA lost 56/57 psi in 1st 15 minutes and 18/17 psi in 2nd 15 minutes for a total loss of 74/74 psi in a 30 minute test. Bled down pressure. Hung caution tags and sign on wing and IA casing. FWHP's=250/250/0. 08/27/14 T/I/O=SI/180/20. Conducted PJSM. Barrier= I/A gate valve, verified by performing LTT(Pass). Remove 2-1/16"tapped blind on I/A(working side). N/U temp valve#4(piggyback).Torqued to API spec.,226 ft- Ins; L7M non-coated. PT'd thru needle valve on 1502 cap, 300/low&3500/high (Pass). Charted&saved in TRP folder. RDMO. FWHP's=SI/180/20. Page 1 of 2 S-09, Well History (Pre-Rig Sidetrack) Date Summary 08/27/14 T/1/O=SI/0/0.Verified VR plug was present in companion OA.Torqued and PT'd blind flange. (PASSED). Installed OA Piggyback Temp#59.Torqued and PT'd (PASSED). RDMO. Final WHP's S1/0/0. 09/05/14 T/I/O=0/200/0 Pump tubing pressure up to 250 PSI through IA set TWC#427 Nipple down upper tree and install temp SV#21 RDMO Bleed IA to 0 PSI. Final T/1/O=TWC/0/0. Page 2 of 2 North America-ALASKA-BP Page 1 ot$8 Operation Summary Report Common Wet Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/11/2014 09:30 - 15:00 5.50 RIGD P PRE RIG DOWN 'BEGIN RON EVENT AT 09:30 ON 11/11/14 WITH PARKER 273 RIG. -DISCONNECT MUD AND CEMENT LINES -EMPTY DRAINS ON RIG FLOOR LOAD 5"DP IN PIPE SHED -CLEAN FLOW BOX -DISCONNECT MUD INTERCONNECTS CLEAN PITS IN PREPARATION FOR MOVE -PIN FORUM CRANE -R/D BX ELEVATORS -PREP RIG FOR MODULE SEPARATION -REMOVE BLOCKS FROM TOP DRIVE -HOOK UP BRIDAL LINES -PREP RIG FLOOR TO L/D DERRICK -SECURE FORUM CRANE -SECURE PIPE SHED '-DISCONNECT INTERCONNECTS BETWEEN MODULES *PARKER TESTED RIG ESD SYSTEM, SYSTEM WORKING CORRECTLY AND SHUT DOWN GENERATORS 15:00 - 16:00 1.00 RIGD P PRE SKID FLOOR -PJSM -REMOVE ROOFTOP WALKWAYS -RIG DOWN MANRIDERS AND PREPARE RIG FLOOR -PERFORM DERRICK INSPECTION -SKID RIG FLOOR INTO RIG MOVE POSITION. 16:00 - 17:00 1.00 RIGD P PRE LOWER MAST -PJSM AND LOWER DERRICK CHECKLISTS -LOWER DERRICK 17:00 19:00 2.00 MOB P PRE PREPARE TO SEPARATE MODULES -DISCONNECT INTERCONNECTS BETWEEN MODULES -PREPARE MODULES FOR SEPARATION -DISCONNECT AND MOVE CUTTING BOX 19:00 - 22:00 3.00 MOB P PRE STAGE MODULES OFF WELL S-13A -SEPERATE MUD AND UTILITY MODULES FROM DRILL MODULE -MOVE DRILL MODULE OFF WELL S-13A -CLEAN AND CLEAR WELL HOUSE PREP WELL S-09A FOR WELL HOUSE 22:00 - 23:00 1.00 MOB P PRE SPOT WELL HOUSE OVER S-09A -MOVE WELL HOUSE FROM S-13AAND SPOT OVER S-09A -IA=0 PSI,OA=0 PSI,T=0 PSI 23:00 - 00:00 1.00 MOB P PRE SPOT DRILL MODULE OVER WELL S-09A -MOVE RIG MATS AND STAGE UTILITY MODULE -TREE AND WELLHEAD VALVES ALL CONFIRMED CLOSED FOR SPOTTING RIG -SPOT DRILL MODULE OVER WELL S-09A -INITIAL T/I/O=TWC/0/0 PSI -DOUBLE ANNULUS VALVES INSTALLED ON WORKING SIDES OF IAAND OA. RIG TESTED E-STOP PRIOR TO MOVING OVER S-09A WELL Printed 12/1/2014 11:31:18AM North America-ALASKA-BP Page 2 e@....3„, Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/12/2014 00:00 - 02:30 2.50 MOB P PRE SPOT DRILL MODULE OVER WELL S-09A -MOVE RIG MATS AND STAGE UTILITY MODULE -TREE AND WELLHEAD VALVES ALL CONFIRMED CLOSED FOR SPOTTING RIG -RIG TESTED E-STOP PRIOR TO MOVING OVER S-09A WELL -SPOT DRILL MODULE OVER WELL S-09A -INITIAL T/I/O=TWC/0/0 PSI -CENTER WITH PLUMB BOB. LEVEL MODULE. '-DOUBLE ANNULUS VALVES INSTALLED ON WORKING SIDES OF IA AND OA. -MOVE UTILITY MODULE INTO PLACE AND MATE UP TO DRILL MODULE •-ELECTRICIAN AND RIG CREW WORKING ON RIGGING UP UM-DM INTERCONNECT -RAISE DRIVING CABS. 02:30 - 06:30 4.00 MOB P PRE MOVE MUD MODULE AND MATE UP TO DRILL MODULE -ELECTRICIAN AND RIG CREW WORKING ON RIGGING UP UM-DM INTERCONNECT -RAISE DRIVING CABS. LEVEL MUD MODULE -INSTALL ROOF AND FLOOR CAPS -INSTALL PIPESHED RAILS -CONNECT ELECTRICAL SERVICE TO MUD MODULE 06:30 - 07:30 1.00 RIGU P PRE RAISE MAST -PJSM -PERFORM DERRICK RAISING CHECKLIST -RAISE MAST:518KLBS TO LIFT MAST OFF RACK 07.30 - 08:00 0.50 RIGU P PRE SKID RIG FLOOR -SKID RIG FLOOR TO DRILLING POSITION -RAISE PIPE CAT -SKID CATTLE CHUTE 08:00 - 15:00 7.00 RIGU P PRE RIG UP OPERATIONS -BRIDLE DOWN AND RIG UP TOP DRIVE TO BLOCKS -INSTALL TORQUE TUBE PIN -R/U HIGH PRESSURE STANDPIPE -RIG UP RIG FLOOR EQUIPMENT AND MANRIDERS -VISUAL LEAK TIGHT PRESSURE TEST MUD LINE TO 4000 PSI -LOAD SEAWATER TO PITS -CALIBRATE PVTS WITH QUADCO *ACCEPT PARKER 273 RIG AT 13:00HRS ON 11/12/2014 Printed 12/1/2014 11:31:18AM North America-ALASKA-BP Page 343. Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UW:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 17:30 2.50 DHB P PRE PRESSURE TEST TWC -R/U TO TEST TWC -TEST TWC ABOVE 250 PSI LOW AND 4000 PSI HIGH FOR FIVE MIN EACH TEST.GOOD TEST -TEST TWC BELOW 250 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH TEST.GOOD TEST -BLOW DOWN AND RIG DOWN LINES -PUMP OUT TREE SIMOPS -RIG UP HARD LINE TO TIGER TANK -PT HARD LINE 250 PSI LOW AND 4000 PSI HIGH,GOOD TEST 17:30 - 19:30 2.00 PULL P PRE PJSM NIPPLE DOWN TREE AND ADAPTER FLANGE -N/D 4 1/8"DOUBLE MASTER VALVE DRYHOLE TREE -N/D 13 5/8"X 4 1/8"5K CAMERON ADAPTER. 4.5"TCII TUBING HANGER THREADS GALLED UPON INSPECTION AS EXPECTED CHECK AND TIGHTEN CONTROL LINE NPT PLUGS -CAMERON REP FUNCTION LOCK DOWN SCREWS 19:30 - 20:00 0.50 BOPSUR P PRE RIG SERVICE -SERVICE TOP DRIVE -LUBRICATE RIG 20:00 - 23:15 3.25 BOPSUR P PRE NIPPLE UP 13-5/8"5 M BOP -N/U SPACER SPOOL -N/U HIGH PRESSURE RISER -N/U BOP SIMOPS:C/O 4"XT-39 SAVER SUB TO 4 1/2"IF 23:15 - 23:30 0.25 BOPSUR P PRE H2S RIG EVACUATION DRILL -HELD RIG EVACUATION DRILL WITH GRADY'S CREW -AAR:ALL PARTIES ACCOUNTED FOR AND GO BOX UP TO DATE BY SCS 23:30 - 00:00 0.50 BOPSUR P PRE PRE-SPUD -HELD S-09A PRE-SPUD SLIDE PACKAGE WITH BOTH GRADY'S AND HUNDLEY'S CREW -DISCUSSED OVERALL SCOPE OF WORK, WELL CONTROL HAZARDS AND OBJECTIVES FOR THE WELL 11/13/2014 00:00 - 04:00 4.00 BOPSUR P PRE NIPPLE UP 13-5/8"5 M BOP -TORQUE UP HIGH PRESSURE RISER -TORQUE UP BOP -INFLATE AIR BOOTS FOR BELL NIPPLE AND FLOW LINE -INSTALL HOLE FILL&R/U BELL NIPPLE '-INSTALL MOUSE HOLE SIMOPS:C/O 4"XT-39 SAVER SUB TO 4 1/2"IF 04:00 - 04:30 0.50 BOPSUR P PRE RIG EVACUATION DRILL -RIG EVACUATION DRILL WITH HUNDLEY'S CREW -HELD AAR:ALL PARTIES ACCOUNTED FOR -ADVISED CREW TO WEAR SPIKEYS FOR DRILL Printed 12/1/2014 11:31:18AM North America-ALASKA-BP Page 4 ee,33 Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:30 2.00 BOPSUR P PRE RIG UP TO TEST BOPE -RIG UP BOP TEST EQUIPMENT -M/U TEST ASSEMBLIES -RUN TEST JOINT IN HOLE -FILL SYSTEM WITH FRESH WATER. 06:30 - 14:30 8.00 BOPSUR C PRE CHAMBER TESTING PORTION OF BOP TEST -UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -NOV TECH ON SITE TO TEST HYDRAULIC CHAMBERS AND RAM LOCKS PER API STANDARD 53 -TEST WITNESS WAIVED BY AOGCC REP JOHNNIE HILL 'ESTIMATED TIME BREAKDOWN -CHAMBER TEST,BOTH VBRS,ANNULAR, BLINDS,HCR KILL,HCR CHOKE= 8 HRS 14:30 - 00:00 9.50 BOPSUR P PRE BOP TEST -UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -TEST ANNULAR WITH 4.5"DO-NUT TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINS CHARTED -TEST REST OF BOPE RAMS TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH -TEST VBRS WITH 4 1/2"AND 5" DO-NUT TEST JOINTS -NOV TECH ON SITE TO TEST HYDRAULIC CHAMBERS AND RAM LOCKS PER API STANDARD 53 -TEST 2 7/8"X 5 1/2"VBR RAM LOCKS WITH 2 7/8"AND 5 1/2"TEST JOINT -PERFORM ACCUMULATOR DRAWDOWN TEST -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESS WAIVED BY AOGCC REP JOHNNIE HILL *ESTIMATED TIME BREAKDOWN -TEST BOPS WITH 4 1/2"AND 5"DO-NUT TEST JOINTS=10 HRS -TEST BLIND RAM AND VBRS RAM LOCKS=3 HRS Printed 12/1/2014 11:31:18AM North America-ALASKA-BP Page 590i.3- Operation Summary Report Common Well Name:S.-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/14/2014 00:00 - 04:00 4.00 BOPSUR P DECOMP BOP TEST -UTILIZE PRESSURE CROSSCHECK LIST PRIOR TO TESTING -TEST BOP ACCORDING TO AOGCC,BP REGULATIONS AND PARKER PROCEDURES -TEST ANNULAR WITH 4.5"DO-NUT TEST JOINT TO 250 PSI LOW,3500 PSI HIGH,5 MINS CHARTED -TEST REST OF BOPE RAMS TO 250 PSI LOW,4000 PSI HIGH FOR 5 MINUTES EACH -TEST VBRS WITH 4 1/2"AND 5" DO-NUT TEST JOINTS -NOV TECH ON SITE TO TEST HYDRAULIC CHAMBERS AND RAM LOCKS PER API STANDARD 53 TEST 2 7/8"X 5 1/2"VBR RAM LOCKS WITH 2 7/8"AND 5 1/2"TEST JOINT PERFORM ACCUMULATOR DRAWDOWN TEST -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESS WAIVED BY AOGCC REP JOHNNIE HILL *ESTIMATED TIME BREAKDOWN -TEST BOPS WITH 4 1/2"AND 5"DO-NUT TEST JOINTS=10 HRS -TEST BLIND RAM AND VBRS RAM LOCKS=3 HRS 04:00 - 05:00 1.00 BOPSUR P DECOMP RIG DOWN TEST EQUIPMENT -DRAIN BOP STACK -BLOW DOWN AND RIG DOWN TEST LINES 05:00 - 07:00 2.00 DHB P DECOMP RIG UP DUTCH RISER AND LUBRICATOR PJSM,REVIEW REVISED DUTCH RISER WSP WITH CREW -RIG MANAGER AND DRILLER VERIFY DUTCH RISER SCREWS ENGAGED CORRECTLY -RIG UP DUTCH RISER AND LUBRICATOR TO PULL TWC -TEST LUBRICATOR 250 PSI LOW,4000 PSI HIGH -PULL TWO WAY CHECK -RIG DOWN LUBRICATOR AND DUTCH RISER 07:00 - 10:00 3.00 PULL P DECOMP CIRCULATE OUT FREEZE PROTECT -PJSM,VERIFY LINE UP -PUMP 15BBLS SEAWATER DOWN IA, RETURNS UP TUBING TO FLOW BACK TANK @ 8 BPM, 915 PSI -PUMP 309 BBLS SEAWATER DOWN TUBING, RETURNS UP IA TO FLOW BACK TANK @ 8 BPM,900 PSI -BLOW DOWN/RIG DOWN SURFACE LINES WELL DISPLACED TO 8.5 PPG SEAWATER -MONTIOR WELL 10 MINS,CONFIRM WELL IS STATIC *START TIMING AND MONITORING WELL FLUID LEVEL FOR TUBING SPOOL SWAP AT 10:00 10:00 - 11:00 1.00 PULL P DECOMP RIG UP DOYON CASING -R/U CASING TONGS AND EQUIPMENT Printed 12/1/2014 11:31:18AM North America-ALASKA-BP Page 6 ot<48 Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 12:00 1.00 PULL P DECOMP LIFTING EQUIPMENT OD/ID TRAINING -PERFORM TUBULAR OD/ID AND ELEVATOR CALIPER TRAINING WITH HUNDLEYS CREWS AS DEFINED IN THE PARKER BACK TO WORK PLAN 12:00 - 15:30 3.50 PULL P DECOMP PULL 13"X 4.5"TCII TUBING HANGER -MAKE UP SPEAR AS PER BAKER FISHING HAND -DRAIN STACK -RUN IN HOLE AND ENGAGE SPEAR IN TUBING HANGER -BACK OUT LOCK DOWN SCREWS AS PER CAMERON -PULL TUBING HANGER OFF SEAT AT 68K •LBS -PULL TUBING HANGER TO RIG FLOOR -MONITOR WELL FOR 10 MINUTES AFTER PULLING HANGER TO RIG FLOOR,WELL STATIC L/D HANGER AND SPEAR ASSEMBLY 15:30 - 16:30 1.00 PULL P DECOMP CIRCULATE BOTTOMS-UP 1.5 TIMES 210 GPM,400 PSI -MONITOR WELL FOR 10 MIN:STATIC CHANGE OUT 5"ELEVATORS TO 4 1/2"YC ELEVATORS -DRILLER AND RIG MANAGER VERIFY ELEVATORS PROPER SIZE FOR 4.5"TUBING 16:30 - 20:00 3.50 PULL P DECOMP POOH WITH 4-1/2"12.6# L80 TUBING -LAY DOWN 1 X 1 IN PIPE SHED -UP WEIGHT 68K -POOH FROM 2,934'MD TO SURFACE -MONITOR TRIP VIA TRIP TANK-PROPER DISPLACEMENT -69 FULL JOINTS RECOVERED -4 PUP JOINTS RECOVERED -1 X NIPPLE RECOVERED -CUT JOINT=2.29 FT,4.75"FLARE TUBING IN GOOD CONDITION 20:00 - 21:00 1.00 PULL P DECOMP R/D CASING EQUIPMENT -R/D TONGS -CHANGE OUT YC ELEVATORS FOR BX ELEVATORS -DRILLER AND RIG MANAGER VERIFY ELEVATORS PROPER SIZE FOR DRILL PIPE -CLEAN AND CLEAR RIG FLOOR 21:00 - 21:30 0.50 STCTPL P DECOMP RIG SERVICE -LUBRICATE RIG GREASE BLOCKS,TOP DRIVE,IDM 21:30 - 00:00 2.50 STCTPL P DECOMP PJSM RIG UP HES E-LINE -PJSM -RIG UP E-LINE SHEAVES AND BRING TOOLS TO RIG FLOOR -MAKE UP TOOLS PER HES -RIH WITH GR/CCUJB/GR GUAGE RING 8.3"OD(EZSV 7.75"OD) Printed 12/1/2014 11:31:18AM North America-ALASKA-BP Page 7 ofg2' Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/15/2014 00:00 - 01:30 1.50 STCTPL P DECOMP RUN IN HOLE WITH HES E-LINE GAUGE RING RUN -GAUGE RING 8.3"OD -RIH WITH GR/CCL/JB/GR TOOL TO 2850' ELMD -LOG UP TO 2650'ELMD -CONFIRM 9 5/8"COLLAR AT 2752'ELMD -CONFIRM FORMATION OUTSIDE PROPOSED WINDOW SV4 SHALE -POOH AND LAY DOWN GR/CCUJB/GR TOOL *SIMOPS BUILD 5"DP STANDS OFFLINE 01:30 - 04:30 3.00 STCTPL P DECOMP RIH AND SET HES 9 5/8"EZSV(7.75"OD) -MAKE UP EZSV TO GR/CCL TOOL PER HALLI B U RTO N -SET HES TIMER SETTING TOOL TO SET IN 95 MIN AT 01:59 -RIH WITH EZSV/GR/CCL ON E-LINE Fl SURFACE TO 2850'ELMD -LOG F/2850'T/2650' -RIH TO 2800'ELMD AND PUT EZSV TOP ON DEPTH AT 2744'ELMD 8'ABOVE COLLAR -AT 03:47 E-LINE WEIGHT INDICATOR DROPPED FROM 915 LBS TO 706 LBS INDICATING PAKER SET AND RELEASED. -SET TOP OF EZSV AT 2744'ELMD,8'ABOVE CASING COLLAR -BOTTOM OF EZSV AT 2747'ELMD -PULL OUT OF HOLE AND R/D E-LINE *SIMOPS BUILD 5"DP STANDS OFFLINE 04:30 - 07:00 2.50 WHSUR P DECOMP NIPPLE DOWN BOP AND REPLACE TUBING SPOOL -DRAIN STACK LAY DOWN MOUSE HOLE AND REMOVE PS-21 SLIPS N/D BELL NIPPLE -SET BACK RISER AND BOP STACK -N/D TUBING SPOOL **BARRIERS FOR BREAKING CONTAINMENT** -PRESSURE TESTED CEMENT PLUG IN TUBING AND IA-TESTED ON 11-12-14.TOC IA AND TUBING-6960'MD. -KILL WEIGHT FLUID-8.5-PPG SEAWATER -MONITORED WELL FLUID LEVEL FROM 10:00-HRS.ON 11-14-14. FLUID LEVEL STABLE AT SURFACE FOR 20-HRS.BEFORE BREAKING CONTAINMENT. *SIMOPS BUILD 5"DP STANDS OFFLINE Printed 12/1/2014 11:31:18AM .e North America-ALASKA-BP Page 8 efaa Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:OOAM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:00 - 13:30 6.50 WHSUR P DECOMP NIPPLE UP NEW TUBING SPOOL&BOP -CAMERON INSPECT 9 5/8"ROUGH CASING CUT -CAMERON FILE CASING CUT BURS -NIPPLE UP NEW MCEVOY SSH TUBING SPOOL -INSTALL SECOND ANNULUS VALVE ON TUBING SPOOL -NIPPLE UP BOP MAKE UP MOUSEHOLE CAMERON TEST 9 5/8"PACKOFF TO 250 PSI LOW FOR 5 MIN AND 3500 PSI HIGH FOR 30 MIN AS PER PPPOT 13:30 - 16:30 3.00 BOPSUR P DECOMP PRESSURE TEST BOP SERVICE BREAK AND TUBING SPOOL -R/U TEST PLUG,ENSURE PROPER SIZE SINGLE JOINT ELEVATORS FOR 5"TEST JOINT FILL STACK AND REMOVE AIR FROM LINES -TEST BOP BREAK,TUBING SPOOL AND SECONDARY ANNULUS VALVE PT 250 PSI LOW AND 4000 PSI HIGH FOR 5 CHARTED MINUTES -PASSING TEST 16:30 - 17:00 0.50 STWHIP P DECOMP RIG SERVICE -PERFORM DERRICK INSPECTION -GREASE BLOCKS,CROWN AND IDM 17:00 - 19:30 2.50 STWHIP P DECOMP RIG DOWN TEST EQUIPMENT -R/D TEST PLUG AND EQUIPMENT -INSTALL 9 1/8"WEAR RING -M/U SAFETY JOINT -CIO 4 1/2"PS-21 INSERTS TO PS-21 BOWL INSERTS -C/O BX 4"INSERTS TO 5"DP INSERTS -RIG MANAGER AND DRILLER CALIPER AND VERIFY INSERTS ARE FOR 5"DP 19:30 - 00:00 4.50 STWHIP P WEXIT MAKE UP BAKER WHIPSTOCK ASSEMBLY -MAKEUP 9-5/8"GEN II 3-STRING MILL AND LEAD MILL ASSEMBLY -CONFIRM ANCHOR SET FOR 18 KLBS SHEAR AND REMOVAL OF SHIPPING PIN -BOT REP AND SLB DD ON RIG FLOOR -ORIENT UBHO WITH WHIPSTOCK HIGHSIDE AND CONFIRM GYRO DATA TOOL PROPERLY ORIENTED -M/U 9 X 6 1/2"DRILL COLLARS -M/U 5 STANDS OF 5"HWDP -OVERALL BHA LENGTH=829.03'MD 11/16/2014 00:00 - 01:30 1.50 STWHIP P WEXIT RUN IN HOLE WITH 9-5/8"WHIPSTOCK/MILL ASSEMBLY -RIH FROM 829'MD TO 2,726'MD -PU 130 K,SO 126 KAT 2,726'MD -RIH ON 5"DP FROM DERRICK AT—70 FT/ MIN -FILL PIPE EVERY 20 STANDS -MONITOR TRIP VIA TRIP TANK-PROPER DISPLACEMENT Printed 12/1/2014 11:31:18AM • North America-ALASKA-BP Page 9.ai23' Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay I Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM I Rig Release: Rig Contractor:PARKER DRILLING CO. I UWI:500292077100 Active datum:S-09A Actual @84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 01:30 - 05:00 3.50 STWHIP P WEXIT ORIENT AND SET WHIPSTOCK -RIG UP WIRELINE AND GYRO -ORIENT WHIPSTOCK TO 5.9 DEGREES -POOH WITH GYRO AND SURVEY EVERY 100' MD RIG DOWN HES WIRELINE 05:00 - 05:30 0.50 WHIP P WEXIT SET WHIPSTOCK -RIH TO 2,747'MD AND TAG EZSV -PU 130K,SO 126 K -SET WHIPSTOCK PER BAKER REP -S/O 17K TO SET ANCHOR -P/U 15K OVER STRING WEIGHT TO CONFIRM ANCHOR SET -S/O 42K AND SHEAR WINDOW MILL OFF OF SLIDE PROJECTED WINDOW:TOW 2,726',BOW 2,743'MD 05:30 - 06:00 0.50 STWHIP P WEXIT DISPLACE WELL FROM 8.5 PPG SEAWATER TO 8.8 PPG LSND -OBTAIN SPRS WITH SEA WATER -DISPLACE WELL TO 8.8 PPG LSND -470 GPM,500 PSI -RECORD SLOW PUMP RATES WITH NEW BHA AND NEW MUD 06:00 - 15:30 9.50 STWHIP P WEXIT KICKOFF S-09A SIDETRACK AND MILL 61./ (.C WINDOW -MILL WINDOW IN 9-5/8"CASING WITH 8-1/2" 'A MILLING ASSEMBLY S_ O�1�1- -MILL FROM 2,726'MD TO 2,754'MD -470 GPM,502 PSI,100 RPM,2-4 KFT-LBS TORQUE ON BOTTOM, 1 KFT-LBS TORQUE OFF,2-5 KLBS WOB,123K ROT WT -MONITOR DITCH MAGNETS -PUMP 50 BBL HIGH VIS SWEEP TOP OF WINDOW=2,726'MD,2,726'TVD MIDDLE WINDOW=2,734'MD, 2,734'TVD BOTTOM WINDOW=2,743'MD, 2,743'TVD 15:30 - 16:30 1.00 CONDHL P WEXIT CIRCULATE HOLE CLEAN -CIRCULATE 1 BOTTOMS UP. -470 GPM,502 PSI -SPOT 15 BBL DRILL AHEAD PILL -PULL INTO WINDOW AND FLOWCHECK WELL PRIOR TO LOT(STATIC). 16:30 - 17:30 1.00 EVAL P WEXIT PERFORM LEAK-OFF TEST -MUD WEIGHT:8.8 PPG,2,734'TVD -PUMP 3.8 BBLS AT 0.5 BPM AND PRESSURE BREAKS OVER AT 698 PSI -EMW 13.7 PPG -DISCUSS LOT WITH ODE. -LOT RESULTS IN ACCEPTABLE RANGE TO FOLLOW PRE-APPROVED RISK ASSESSMENT SEE ATTACHED DOCUMENTATION SIMOPS THRU TOUR: BUILD STANDS OF 5" DP Printed 12/1/2014 11:31:18AM • r ' North America-ALASKA-BP Page 10 of€3. Operation Summary Report Common Well Name:S-09 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/12/2014 End Date: X3-015N5-C:(16,029,904.98) Project:Prudhoe Bay Site:PB S Pad Rig Name/No.:PARKER 273 Spud Date/Time:7/5/1982 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292077100 Active datum:S-09A Actual©84.75usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 19:30 2.00 DRILL P WEXIT MILL 8.5"INTERMEDIATE HOLE FROM 2754' MD TO 2766'MD -470 GPM, 510 PSI ON,500 PSI OFF -120 RPM,2-3K TORQUE ON,1K TORQUE OFF '-PU 126K,SO 119K,ROT 123K -MILL ADDITIONAL 12'AFTER LOT TO ENSURE TOP WATERMELON MILL PASS THROUGH WINDOW WORK MILLS THROUGH WINDOW MULTIPLE TIMES TO ENSURE SMOOTH WINDOW MAX DRAG/OVERPULL=2K 19:30 - 20:30 1.00 CONDHL P WEXIT CIRCULATE -CIRCULATE 1 BOTTOMS UP. PUMP 30 BBL SUPER SWEEP 470 GPM,502 PSI -MW IN&OUT=8.8 PPG -SHUT DOWN PUMPS AND MONTIOR WELL- WELL IS STATIC 20:30 - 22:30 2.00 STMILL P WEXIT PULL OUT OF THE HOLE WITH 8 1/2"MILLING ASSEMBLY -POOH ON ELEVATORS FROM 2,766'MD TO 367'MD POOH STANDING BACK 5"DP IN DERRICK -MONITOR TRIP VIA TRIP TANK:PROPER DISPLACEMENT -FLOW CHECK WELL PRIOR TO PULLING BHA INTO STACK,WELL IS STATIC 22:30 - 23:00 0.50 STMILL P WEXIT LIFTING EQUIPMENT OD/ID TRAINING -PERFORM TUBULAR OD/ID AND ELEVATOR CALIPER TRAINING WITH LYLE BUCKLERS CREWS -DEFINED IN THE PARKER BACK TO WORK PLAN 23:00 - 00:00 1.00 STMILL P WEXIT LAY DOWN 8-1/2"MILLING BHA -CLOSE ANNULAR PREVENTER -CHANGE OUT SLIP SEGMENTS -OPEN ANNULAR PREVENTER LAY DOWN 6-1/4"DRILL COLLARS 11/17/2014 00:00 - 01:30 1.50 STMILL P WEXIT LAY DOWN 8-1/2"MILLING BHA -LAY DOWN 6-1/4"DRILL COLLARS -LAY DOWN BOT MILLING ASSEMBLY -CLEAN AND CLEAR RIG FLOOR OF BAKER MILLS AND HANDLING TOOLS MILL GAUGE WEAR: WINDOW MILL-1/4"UNDER LOWER STRING MILL-1/8 UNDER GAUGE UPPER MILL 1-IN GAUGE UPPER MILL 2-IN GAUGE 01:30 - 02:30 1.00 DRILL P INTI FLUSH AND FUNCTION BOPS -PJSM -M/U BOP CLEANING TOOL TO A STAND OF 5"DP -WASH AND JET BOPS DOWN PAST WELLHEAD -FUNCTION TEST ALL BOP COMPONENTS Printed 12/1/2014 11:31:18AM TREE=v CNV WEI_LJ-EAD= tot La/OY S-O 9 St f NOTES:R2S AVERAGE 125 ppm WF .ON MI WELL REQUIRES A SSSV WHEN ON 'ACTUATOR= BAKER C MI DFB. = 6T d: BF.ELEV EV== 38.50 ® 9-5/8'DV PKR KOP= 3200' 20'CONDUCTOR - ? Max Angle= 40" 5500' -# 2726' —VVI- `'TOCK(11/16/14) Datum MD= 10098' Datum TVD= 8800'SS D=-" 274T H9-5/8"EZSV(11/16/14) 13-3/8"CSG,72#,L-80 BUTT,D=12.347" H 2678' 11, ♦w `-, 11,. 7240' -14-i/2"FSS X tom,D=3.813" 4-1/2"TBG CUT(08/19/14) -I 2934" I��� 4 lid"KAI 1 fitL‘117:4! -i 7312 19-5/8"X 4-1/2"FES TNT PKR D=3.903 TtBNG PUNCH(08/18/14) 7259'-7263' 7473' --4-1/2"FES XD SLD SLV,0=3.813" Kvi 6.4-1/2"C8P(08/17/14) - 7620' .9i 4 CLOS®(08/12/14) 7790' -19-5/8'DV PKR Minimum ID =3.725" @ 10258' 4-112" OTIS XN NIPPLE ��► c �' --19-5/8"X 4-1/2 FES TNT PKR,D=3.903' elm-1 9571' -4-1/2"FES X NP,D=3.813' 41/2"TBG,12.6#,L-80 TCI .0152 bpf,D=3.958" H 9649' I- 4,0040400, A%lAbibl 5-1/2'TBG STUB(10/09/11) H 9653' 01I�4,I r 9665' H9-5/8"X 4-1/2"Lt'IQtE OVERSHOT d04,/#40'4" S, % 141 •,•,•! 9700' -{FBR TBG SEAL ASSY +I•I• 5-1/2"TBG,17#,L-80 TC4S,.0232 bpf,D=4.892" H 9702' %% le 9702' -9-5/8"X 5-1/2'"Thy HFBP PKR ASSY,0=4.00" NN :4,0‘1.14 9706' --16" V LLOUT EXTENSION,0=4.50" � V'Nj 9711' 1-6"x 4-1/2'XO,ID=3.958" okslo 9741' H4-1/2"PA RKER X NP,ID=3.813" 40,0404 9773' -14-1/2"PARKER X NP,0=3.813' I 4-1/2'TBG,12.6#,L-80 TC4S,.0152 bpf,D=3.958' H 9806' :`d;I� 9806' 41/2"WLEG,ID=3.958" 4,,,,I �� 9788• H atiD Tr LOG ON flP?1a? PERFORATION SUMMARY /41400'4"4•400' REF REF Loc:BHCS On 07/18/82 ANGLE AT TOP PERF:39°@ 7570' 1411414 II' 40 Note:Refer to Ftoduction DB for tIstorical pert data _'*►i► SIZE SPF INTERVAL Opn/Sqz DATE SOZ 111 ��I 10175' -+9-5/8"MARKERJOINT 7" 14 7570-7610 S 10/11/11 18-Aug % f 400400, 7" 14 7635-7663 S 10011/11 41869 4;0 4P4 3-3/8" 6 9931-9976 S 02/18/89 41869 ' 2-7/8' 4 10066-10137 S 01/19/84 41869 2-7/8" 1 10138-10250 0 07/04/84 X- 10250• H9-5/8"X 4-1/2"OTIS WE)PKR,D=4.00" 3-1/8" 1 10264-10289 0 10/12185 ' ' 10254" 1-14-112"OTIS X NP,D=3.813" ' ' . 10258' -141/2'011S XN NP,ID=3.725' 4-1/2'TBG,12.6#,L-80,0.0152 bpf,D=3.958' H 10261' -----....../ ‘--1 10261' -14-1/2"OTIS TBG TAL,D=3.980' PBTD --1 10439' El 9-5/8"CSG,47#,L-80 BUTT,.0733 bpf, El=8.681" -1 10480' X44.4.4.144.4.444.4.1. DATE REV BY OOMuENTS DATE REV BY COM,6'TTS PRIDHOE BAY UNIT 07/25/82 122E ORIGANAL COMPLETION 08/12/14 LEC/PJC CLOSE SLD SLV ' .L: S-09 08/14/88 NIE5 MO 08/25/14 JCMJM7 TBG CUT(08/19/14) PERMT No:'1821040 10/21111 D-16 RWO 08/25/14 TAR/PJC P&A(08/18/14) AR No: 50-029-20771-00 01/18/12 TMJ/JMD ADDED H2S SAFE!Y NOTE SEC 35,T12N,T12E,1642'FNL&1634'FML 04/01/12'GJF/PJC OPEN SLD SLV!SET PX PLUG 01/22/13 T.N-VJMD PILLED P9(PLUG(01/08/13) BP Exploration(Alaska) Ima~ Project Well History File Cover ~ge XHVZE This page identifies those items that were not scanned during the initial prodUction scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. [ ~;~ _~- ~ 0 ~_~ Well History File Identifier RESCAN DIGITAL DATA OVERSIZED (Scannable) E Color items: [] Diskettes, No. [3 Maps: D Grayscale items: [] Other, NofType ..,. · [] Other items scannable by large scanner [3 Poor Quality Originals: OVERSIZED (Non-Scannable) [] Other: NOTES: [3 Logs of various kinds [] Other BY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: .IS/ Project Proofing BY: BEVERLY .BREN VINCENT SHERYL MARIA LOWELL DATE: /SI Scanning Preparation ' ~'- x 30 = i(;~,O + I~¢,¢~ = TOTALPA(~ES Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: I PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: YES Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO NO (SCANNING IS COMPLETE AT THIS PONT UNLESS SPECIAl. ATTENTION IS REQUIRED ON AN INDMOUAI. PAGE BASIS DUE TO QUALITY, GRAY~,,ALE OR COI. ON IMAGES) RESCANNEDBY: BEVERLY BREN VINCENT SHERYL MARIA LOWELL DATE: ~SI General Notes or Comments about this file: Quality Checked (done) . ED STATE OF ALASKA AOKA OIL AND GAS CONSERVATION COMMON AUG 2 3 2012 REPORT OF SUNDRY WELL OPERATIONS Aiaska Oil & Gas Cons. Commission 1. Operations Abandon Li Repair Well [J Plug Perforations LJ ' Perforate ❑ otherU A 1®t era Injection Performed: Alter Casing ❑ Pull Tubing0 Stimulate - Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown❑ Stimulate - Other ❑ Re -enter Suspended Weil 2. Operator 4. Well Class Before Work: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc Development Exploratory ❑ 182 -104 -0 3. Address: P.O. Box 196612 StratigraphiC Service el 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20771 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: ADL0028258 r S -09 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): None PRUDHOE BAY, PRUDHOE OIL if l l u Q (J� 11. Present Well Condition Summary: .> Total Depth measured 10480 feet Plugs measured 9754 feet true vertical 9218.25 feet Junk measured None feet Effective Depth measured 9577 feet Packer measured See Attachment feet true vertical 8397.07 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 82 20" 91.5# H -40 28 - 110 28 - 110 1490 470 Surface 2650 13 -3/8" 72# L -80 28 - 2678 28 - 2677.91 4930 2670 Intermediate None None None None None None Production 10455 9 -5/8" 47# L -80 25 - 10480 25 - 9218.25 6870 4760 Liner 11 4 -1/2" 12.6# L -80 10250 - 10261 9006.31 - 9016.42 8430 7500 Perforation depth Measured depth 7570 - 7610 feet 7635 - 7683 feet 9931 - 9976 feet 10067 - 10138 feet 10138 - 10250 feet 10265 - 10290 feet True Vertical depth 6764.08 - 6794.99 feet 6814.25 - 6851.11 feet 8715.48 - 8756.34 feet 8839.08 - 8903.78 feet 8903.78 - 9006.31 feet 9020.09 - 9043.08 feet Tubing (size, grade, measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): MAR �� �In�'? SCANNED M 2 J Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 744 0 444 Subsequent to operation: 0 0 215 0 2078 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service © Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: . Oil ❑ Gas ❑ WDSPI{J GSTOR ❑ WINJ ❑ WAG El GINJ ❑ SUSP ❑ SPLUCE] 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: N/A Contact Garry Catron Prepared by Garry Catron 564 -4424 Printed Name Garry Catron Title PDC PE Signature � � 0 / 1 ------ � -- Phone 564 -4424 Date 8/22/2012 t 4 kJ IMS AUG 24 7 01 2 / V�4� � N A L q 4 alp OBI �l Form 10 -404 Revised 10/2010 Submit Original Only • • Packers and SSV's Attachment ADL0028258 SW Name Type MD TVD Depscription S -09 PACKER 2614 2546.91 9 -5/8" DV Packer S -09 PACKER 7312 6495.49 4 -1/2" HES TNT Perm Packer S -09 PACKER 7790 6866.21 9 -5/8" DV Packer S -09 PACKER 9499 8261.39 4 -1/2" HES TNT Perm Packer S -09 PACKER 9702 8441.48 5 -1/2" TIW HBBP Packer S -09 PACKER 10250 8939.31 4 -1/2" Otis WD Packer I Perforation Attachment ADL0028258 SW Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base TVD Depth Top TVD Depth Base S -09 4/1/2012 STO 7570 7610 6764.08 6794.99 S -09 4/1/2012 STO 7635 7683 6814.25 6851.11 8-09 4/1/2012 BPS 9931 9976 8715.48 8756.34 S -09 4/1/2012 BPS 10067 10138 8839.08 8903.78 S -09 4/1/2012 BPS 10138 10250 8903.78 9006.31 S -09 4/1/2012 BPS 10265 10290 9020.09 9043.08 • AB ABANDONED MIR MECHANICAL ISOLATED REMOVED APF ADD PERF MIS MECHANICAL ISOLATED BPP BRIDGE PLUG PULLED MLK MECHANICAL LEAK BPS BRIDGE PLUG SET OH OPEN HOLE FCO FILL CLEAN OUT STC STRADDLE PACK, CLOSED FIL FILL STO STRADDLE PACK, OPEN SQF SQUEEZE FAILED SPS SAND PLUG SET SQZ SQUEEZE SL SLOTTED LINER PER PERF SPR SAND PLUG REMOVED RPF REPERF • Casing / Tubing Attachment ADLOO28258 Casing Length Size MD TVD Burst Collapse CONDUCTOR 82 20" 91.5# H-40 28 - 110 28 - 110 1490 470 LINER 11 4 -1/2" 12.6# L -80 10250 - 10261 9006.31 - 9016.42 8430 7500 PRODUCTION 10455 9 -5/8" 47# L -80 25 - 10480 25 - 9218.25 6870 4760 SURFACE 2650 13 -3/8" 72# L -80 28 - 2678 28 - 2677.91 4930 2670 TUBING 9643 4 -1/2" 12.6# L -80 22 - 9665 22 - 8475.38 8430 7500 TUBING 56 5 -1/2" 17# L -80 9655 - 9711 8466.45 - 8516.55 7740 6280 TUBING 95 4 -1/2" 12.6# L -80 9711 - 9806 8516.55 - 8602.18 8430 7500 • • • • Daily Report of Well Operations ADL0028258 ***WELL INJECTING • 1 ' ' V • , set ttp, sbhps) R/U SLICKLINE EQUIPMENT 3/31/2012 * ** CONT WSR ON 4 -1 -12 * ** T /1 /0= 980/630/50 Temp =Hot Assist Slickline with B &F and Freeze Protect 3/31/2012 (Profile modification) LRS RU and PT. ** *WSR Continued * ** ***CONT'D FROM 3 -31 -12 * ** (b &f, set ttp,sbhps) RAN 4.5" BLB & 3.80" GAUGE RING WORK SSD @ 7473' MD AND X- NIPPLE @ 9577' MD. SAW NO RESTRICTIONS. SET 3.8T3" PX PLUG @ 9577' MD. RAN 4.5" 42B0 SHIFTING TOOL /D @ 7454' SLM.MADE SEVERAL PASSES. 4/1/2012 ** CONTINUE ON 4 -2 -12 * ** ** *WSR Continued * ** Assist slickline with 13 &I- and Freeze Protect (Profile • Modification) Freeze Protect Flowline with 5 bbls of meth and tubing with 28 bbls of meth. Pumped 150 bbls of 180* F diesel down tubing while SSL brushed. SSL set plug. Pressure test plug to 2500 psi for 5 minutes. Slickline adjust sliding sleeve. Pumped 5 bbls down Tbg to test if Tbg pressuring up as per PE. ** *WSR 4/1/2012 Continued * ** ** *WSR Continued * ** Assist Sic (Profile Modification) ' Rig down equipment. 4/2/2012 Slickline in control of well upon departure. FWHP's= 980/140/5 * ** CONT'D FROM 4 -1 -12 * ** (sbhps) RAN 2,78" CENT W/ S.S & DUAL SLB GAUGES AS PER PROCEDURE (seel log for depths) .RECOVERED GOOD DATA. HELD MAN DOWN & FIRE SAFETY DRILLS. 4/2/2012 * ** WELL LEFT S/I ON DEPARTURE * ** T /l /0= 500/6/ -3 Temp =Sl Injectivity test (perf breakdown) Pumped 30 bbls MEOH for initial injectivity test then pumped 277 bbls 100* 2% KCL for perf breakdown (See log) & capped with 40 bbls MEOH for TBG FP. DSO to put on INJ ASAP. SD pump @ 5/30/2012 18:04 , FWHP's = 1500/14/3 DSO notified SWV,WV =S /I IAV,OAV =OTG T/1/01880/50/20. Temp = SI. WHPs (UIC Compliance). Shut In. 6/10/2012 SV, WV = C. SSV, MV = OTG. IA, OA = OTG. 20:40. T /I /0 = 1900/50/20. Temp = 110 °. Increase IAP to 500 psi (UIC). WAG. IA FL @ surface. Increased IAP w/ AL from S -38 from 50 psi to 500 psi in 5 min. During pressure increase OAP increased 10 psi. Changed out IA quarter turn valve, was leaking in the open position when pressure increased, notified DSO. Job complete. Final WHPs = 1900/500/30. 6/12/2012 SV = C. WV, SSV, MV = O. IA, OA = OTG. NOVP. 11:00 hrs. T /1 /0 = 1835/440/20. Temp =114 °. WHPs (UTC Post Increase). Well is on PWI. 6/15/2012 SV= Closed. WV,SSV,MV =Open. IA,OA =OTG. NOVP. (2030 hrs) T /l /0= 1140/410/20 H.O.T. diesel flush (Operator call in) Pumped 100 bbls 180 *F 6/21/2012 diesel down Tbg from flowline to clean out meter and choke. ** *WSR Continued * ** ** *WSR Continued * ** H.O.T. diesel flush (Operator call in) Rid down. SV, WV= 6/22/2012 C SSV, MV= 0 IA, OA= OTG FWHP's= 1420/480/20 ~TREE _ GW WELLHEAD = McEVOY II S� NOTES: H2S READINGS AVERAGE 125 ppm ACTUATOR = BAKER C S -0 9 WHEN ON M I """ WELL REQUIRES A SSSV WHEN ON KB. ELEV = 66.98' I � MI. BF. ELEV = 38.50' 2089' —I4-1/2" HES X NIP, ID = 3.813" KOP = 3200' Ma x Angle = 40° @ 5500' Daturn MD = 10098' —I 2614' H9 -5/8" DV PKR I Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" IH 2678' 7240' — 14 - 1/2" HES X NIP, ID = 3,813" I �/ 7312' 9-5/8" X 4 -1/2" HES TNT PKR, ID = 3.903" ►11 ■ 10258' 7473' 4 -1/2"" HES XD SLD SLV , ID= 3.813" Minimum ID = 3.725" Ir. OPENED (04I01112) . 4 -1/2" OTIS XN NIPPLE II - 7790' — 9- 5h" =, =' 9499' H9 -5/8" X 4-1/2" HES TNT PKR, ID = 3,903" 9577' 4-1/2" HES X NIP, ID = 3.813" 14 -1 /2" TBG, 12.6#, L -80 TCII, .0152 bpf, ID = 3.958" H 9649' - 11111111 9577' — 4 -1/2" PX PLUG T (04/01 /12) 15 -1/2" TBG STUB (10/09/11) I—•I 9653' 9665' 9 -5/8" X4 -1/2" UNIQUE OVERSHOT 9700' — PER TBG SEAL ASSY 1 15 -1 /2" TBG, 17 #, L -80 TC4S, .0232 bpf, ID = 4.892" —I 9702' . 9702' — 9 -5/8" X 5-1/2" TAN HPBP PKR ASSY ID = 4,00" • 9706' — 16" MILLOUT EXTENSION, ID = 4.50" I 9711' --I6" x 4-1/2" XO, ID = 3.958" I 9741' — 14 - 1/2" PARKER X NIP, ID = 3.813" 9773' I- - 14 -1/2" PARKER X NIP, !D - 3.813'° 4 -1/2" TBG, 12.6#, L -80, .0152 bpf, ID = 3.958" H 9806' 1 — 9806' — 14 -1/2" VI/LEG, ID= 3.958" 1 9788' - ELMD TT LOG ON ? ? / ? ?/?? 1 PERFORATION SUMMARY REF LOG: 131-CS On 07/18/82 ANGLE AT TOP PERF: 39° @ 7570' I Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE T'SIZE 14 7570 - 7610 0 10/11 / 10175' — 9 -5/8" MARKER JOINT 7 14 7635 - 7663 0 10/11/11 ' 3 -3/8" 6 9931 - 9976 0 02/18/89 I 2 -7/8" 4 10066 - 10137 0 01 /19/84 2-7/8" 1 10138 - 10250 0 07/04/84 10250' H9.518" X 4-1/2" OTIS WD PKR, ID = 4.00" 1 3 -1/8" 1 10264 - 10289 0 10/12/85 07-4 ' 10254' I-14 -1 /2 "' OTIS X NIP, ID = 3.813" ' 10258' H4 -1/2" OTIS XN NIP, ID= 3,725" 1 4-1/2" TBG, 12.6 #, L -80, 0.0152 bpf, ID = 3.958" I--1 10261' 1 10261' H 4 -112" OTIS TBG TAIL, ID = 3.980" I I 1 PBTD — 10439' 000001 9 -5/8" CSG, 47 #, L -80 BUTT, .0733 bpf, ID = 8.681" H 10480' � • � • 1A . 1 . � . 1 . 1 . 1 . 1 .1. DATE REV BY COMMENTS . DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/25182 N22E ORIGINAL COMPLETION 09/20/11 TM/ PJC SET CBP / JET CUT (9/14 - 15/11) WELL. S -09 08/14188 N1 ES RWO 11/11/11 SM/JMD DRLG DRAFT CORRECTIONS PERMIT No: 1 821040 10/21/11 D RlNO 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE AR No: 50 -029- 20771 -00 02/15/11 M8 /JMD ADDED SSSV SAFETY NOTE 04/01/12 GJF/ PJC OPEN SLD SLV/ SET PX PLUG SEC 35, T12N, T12E, 1642' FNL & 1634' FWL 06/26/11 TI-V PJC DRAWING CORRECTIONS BP Exploration (Alas ka) • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg r 1 'VIII DATE: Friday, December 16, 2011 P.I. Supervisor t a t SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S -09 FROM: Lou Grimaldi PRUDHOE BAY UNIT S -09 Petroleum Inspector Src: Inspector Reviewed By P.I. Supry C 1 NON - CONFIDENTIAL Comm Well Name: PRUDHOE BAY UNIT S - 09 API Well Number: 50 029 - 20771 - 00 - 00 Inspector Name: Lou Grimaldi Insp Num: mitLG111204193133 Permit Number: 182 - 104 - Inspection Date: 12/1/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well S-09 Type Inj. W TVD 6563 , IA 0 2000 ' 1935 1920 P.T.D 1821040' TypeTest SPT Test psi 1641 , OA 22 27 27 28 Interval INIITAL - p/F P Tubing 200 203 200 200 Notes: 3.9 Bbl's pumped and 2.7 bbl's returned with 500 psi above as found pressure. Good test. - S FEE 1 6 2( 1 C Friday, December 16, 2011 Page 1 of 1 3Q2011 Not Operable Injector Report • • Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWeIllntegrityCoordinator @bp.com] Sent: Thursday, November 24, 2011 9:59 PM To: AK, D &C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA) Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O &M TL; AK, RES END Production Optimization Engineer; Kruger, Dale 0 Subject: 3Q2011 Not Operable Injector Report Attachments: Not Operable Injector Report 3Q2011.zip r. 3, Tom, Jim, Phoebe and Guy, Attached is the 3Q 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors classified as Not Operable. «Not Operable Injector Report 3Q2011.zip» Notes on wells: Removed from Quarterly Injection Report: MPF -74 (PTD #1961080): Long term shut in that was returned to service. Passed MIT -IA on 09/11/11. Added to Quarterly Injection Report: 09 -36C (PTD #1951140): Leak found in tubing patch 13 -17 (PTD #1820260): Well reclassified while flowline repair is being performed END 3- 43/P -36 (PTD #1931700): Surface casing leak discovered post Brinker treatment MPC -08 (PTD #1850140): Long term shut in requiring MITIA to be compliant MPF -89 (PTD #2050900): Surface casing leak MPF -99 (PTD #2061560): Long term shut in requiring MITIA to be compliant NGI -10 (PTD #1760690): TxIA communication when on gas injection, AA for IAxOA communication. R -02 (PTD #1781000): Identified TxIA communication with leak detect log S -09 (PTD #1821040))Shut in for rig workover to replace tubing U -04A (PTD #1920270): Starting head leak with a Furmanite repair failure Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/28/2011 I • 1 RN) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Nov 2 nil � pia. LommissIQO WELL COMPLETION OR RECOMPLETION RE' .1'i- tl nmmiceinn la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ❑ Suspended 1b. Wel 2OAAC 25 105 20AAC 25.110 ❑ flt ❑ Exploratory ❑ GINJ ❑ WINJ ® WAG ❑ WDSPL ❑ Other No. of Completions One IN Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: , BP Exploration (Alaska) Inc. 10/16/2011 182 - 104 311 - 203 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 07/05/1982 50 029 - 20771 - 00 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 07/19/1982 PBU S -09 1642' FNL, 1635' FWL, SEC. 35, T12N, R12E, UM 8. KB (ft above MSL): 67 15. Field / Pool(s): Top of Productive Horizon: 3745' FNL, 265' FWL, SEC. 35, T12N, R12E, UM GL (ft above MSL): 37.66' Prudhoe Bay Field / Kuparuk River Total Depth: 9. Plug Back Depth (MD +TVD): Pool & Prudhoe Bay Field / 4950' FNL, 679' FEL, SEC. 34, T12N, R12E, UM 10434' 9176' Prudhoe Bay Oil Pool 1 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x - 619797 y - 5979855 Zone ASP4 10480' 9218' ADL 028257 & 028258 TPI: x 618463 y 5977730 Zone ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x - 617541 y 5976511 Zone ASP4 None 18. Directional Survey: ❑Yes 181 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 1870' (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: DIL / FDC / CNL / SP / GR / CAL, DIL / BHCS / GR / SP, CBL / VDL / GR / CCL, USIT N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM To BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 2678' Surface 2678' 17 -1/2" 3720 cu ft Arcticset 11 9 -5/8" 47# L -80 Surface 10480' Surface 9218' 12 -1/4" 2058 cu ft Class 'G'. 700 cu ft Class 'G'. & 130 cu ft Arcticset I 24. Open to production or injection? ® Yes ❑ No 25. TUBING RECORD If Yes, list each interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD / TVD) 7" Gun Diameter. 14 sof 2 - 7/8" Gun Diameter. 4 sof 4 - 1/2 ", 12.6#, L - 80 9665' 7312' / 6562 & 9499' / 8328' MD TVD MD TVD 5 -1/2 ", 17# x 4 -1/2 ", 12.6#, L -80 9653' - 9806' 9702' / 8508' 7570' - 7610' 6764' - 6795' 10066' - 10137' 8838' - 8903' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 7635' - 7663' 6814' - 6836' 2 - 7/8" Gun Diameter. 1 sof DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 3 -3/8" Gun Diameter. 6 sof 10138' - 10250' 8904' - 9006' 10250' - 10261' 4 -1/2 ", 12.6 #, L -80, 11' of Add'tl Tubing 9931' - 9976' 8715' 8756' 7473' - 7477' ,/ Tubing Sliding Sleeve for access to Ku 3-1/8" Gun Diameter. 1 sof g g Kuparuk Perfs ' p 10264' - 10289' 9019' - 9042' 3200' Freeze Protected w/ 170 Bbls of Diesel 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): November 13, 2011 Water Injection 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 9 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 wW.)kr hZUi Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE /L •/ ( /� %// Submit Original Only /r l 400 s , � C.� 20. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATIOOESTS NAME MD TVD Well Tested? ❑ Yes ® No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test Permafrost Base results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Schrader Bluff NA 5307' 4981' None Base Schrader Bluff 5863' 5411' Kuparuk C 7570' 6764' Kuparuk D 7570' 6764' Kuparuk B 7605' 6791' Kuparuk A 7626' 6807' Miluveach 7715' 6876' Sag River 9931' 8715' Shublik 9975' 8755' Ivishak 10062' 8835' Formation at Total Depth (Name): Ivishak 10062' 8835' 31. List of Attachments: Summary of Pre -Rig Work and Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoin is true and correct to the best of my knowledge. Signed: Terrie Hubbl 1 f 11' �' Title: Drilling Technologist Date: 051! PBU S - 182 - 104 311 - 203 Prepared By Name/Number Terrie Hubble, 564 -4628 Well Number Permit No. / Approval No. Drilling Engineer: Rusty Knels, 564 -4676 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, or Other (explain). Item 28: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10 -407 Revised 12/2009 Submit Original Only • S -09, Well History (Pre Rig Workover) Date Summary 06/17/11 T /I /O = 250/620/10. Temp = 112 °. Bleed IA/OA to -- 0 psi (pre - PPPOT- T/T -IC). On inj. IA FL close to surface. OA FL @ surface. Bled IAP to slop trailer from 620 psi to 0+ psi in 45 min (gas). Bled OAP to slop trailer from 10 psi to 0 psi in <5 min (fluid/-5 gal). Monitor 30 min. IAP & OAP unchanged. Final WHPs = 250/0 + /0 +. 06/18/11 T /1 /O= 230/15/5. Temp= 120 °. Assist Cameron w/ PPPOT (pre -RWO). IA & OA FL near surface. Maintained open bleed on IA & OAP together while Cameron Tech performed PPPOT -IC- PASSED. Monitored for 30 minutes, IA & OAP increased 0+ psi. Final WHPs= 230/0 +10 +. Job completed. 06/18/11 T /1 /O= 250/0/0 Temp =hot PPPOT -IC (PASS) (Eval comm) DHD bled IA & OA to 0 psi and maintained open bled. PPPOT -IC : Opened SBS void bled to 0 psi. Removed 1" NPT and installed Alemite on IC, RU 1 HP BT and flushed void until clean returns achieved, attempted to pressure to 3500 psi for 30 min test would not go above 1300 psi. RU elephant gun onto ICPV and energized secondary seal with plastic, flushed plastic until air free plastic achieved, 2nd test 3500 psi for 30 min. RD test equipment removed internal check re installed Alemite and tested to 3500 psi for 5 min with no pressure Toss. * ** Internal check removed from IC * ** 07/11/11 T /I /0= 500/80/140 MIT -IA to 2500 psi. MIT -OA to 2000 psi. Load fluids for job and arrive location. 07/12/11 T /I /0= 500/80/140 MIT IA to 2500 psi. (PASSED) MIT OA to 2000 psi. (PASSED) Pumped 5.1 bbls 60/40 4- methanol down IA to bring pressure up to 2500 psi. Lost 61 psi in 1st 15 minutes. Lost 12 psi in 2nd 15 minutes. Bleed pressure down to 500 psi. Pumped 1.7 bbls 60/40 methanol down OA to bring pressure up to 2000 psi. Lost 51 psi in 1st 15 minutes. Lost 21 psi in 2nd 15 minutes. Bleed OA pressure down to 0 psi. FWHP= 400/500/0 08/14/11 WELL S/I ON ARRIVAL. RUN 4.60 CENT, 4 1/2" EQ. PRONG TO 1963' SLM. PULL MCX FROM1961' SLM 1984' MD. DRIFT W/3.70 CENT, TEL, 1.5 SAMPLE BAILER, LOC TT @ 9776' SLM 9788' ELMD +12' COR. TAGGED SOFT BOTTOM © 10170' SLM +12' = 10182' elm = 107' OF FILL. DRIFT W/4.50 CENT. SD © 9671' SLM 9700' MD. 08/15/11 WELL S/I ON ARRIVAL. RUN 3.5 CENT W/ SLB MEMORY GAUGES MAKE ALL STOPS AS PER PROGRAM. RUN 3.5 CENT W/ PDS40 ARM CALIPER AS PER PROGRAM. WELL LEFT S/I ON DEPARTURE PAD OPP NOTIFIED. 08/28/11 T /I /0= 100/0 + /0 +, Temp =Sl. PPPOT-T (PASS), Pre RWO. PPPOT -T: Opened SBS to bleed test void to 0 psi. Installed external check over internal check. Functioned LDS, all moved freely (2 "). Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. ** *Unable to remove internal check. * ** PPPOT -IC: Complete 6- 18 -11. 09/12/11 T /I /0 =40/10 /Vac. Temp =Sl. TBG FL (Pre E- Line). TBG FL C© 1000' (44 bbls). Well has been safed out, cycled master valve open and closed to obtain TBG FL. 09/14/11 T /I /O= 21/20/0 Temp =Sl Assist E -line with MIT T PASSED to 1000 psi. Pumped 3 bbls neat and 24 bbls of 60 °F diesel to reach test pressure. Tubing lost 32 psi. in the first 15 min. and 15 psi. in the 2nd 15 min. for a total loss of 47 psi. in a 30 min. test. Bled back 0.5 bbl to Final WHP= 305/40/0. 09/14/11 WELL SHUT IN ON ARRIVAL. INITIAL T /I /O = 50/0/0 PSI. RIH WITH 4.5" HES PLUG. PERFORMED TIE IN PASS TO TUBING TALLY DATED 13 -AUG -1988. CONFIRMED WITH WSL SET DEPTH = 9755' MID ELEMENT, TOP OF PLUG = 9754', CCL TO ME = 7.8', CCL STOP DEPTH = 9747.2', SET PLUG AND TAGGED TO CONFIRM GOOD SETTING. POOH AND LAY DOWN FOR THE DAY. ARRIVE ON LOCATION. RIG UP POWERCUTTER TOOL STRING, HOT CHECK AND ARM. RIH TO 9665', CORRELATE AND ATTEMPT TO SHOOT. FINAL T /1 /0 = 180/0/0 PSI. Page 1 of 2 • • S -09, Well History (Pre Rig Workover) Date Summary 09/15/11 INITIAL T/I/0 = 180/0/0 PSI. ATTEMPT TO DETONATE POWERCUTTER. MISRUN. POOH. TROUBLESHOOT MISRUN. RIG UP NEW TOOL STRING. HOT CHECK AND ARM POWERCUTTER. RIH. CUT TUBING AT 9665' WITH 4.15" POWERCUTTER IN 5.5" TUBING. CCL TO ME = 6.35'. CCL STOP DEPTH = 9658.7'. TUBING PRESSURE BEFORE FIRING = 30 PSI. TUBING PRESSURE AFTER FIRING = 230 PSI. POOH. FINAL T /I /O = 230/0/0 PSI. JOB COMPLETE. NOTIFY DSO. LEAVE LOCATION. 09/16/11 T /I /O =0/0/0 Temp =SI CMIT T/I Passed to 500 psi/ Circ -out/ Freeze protect flow line (Prep for RWO) CMIT T/I pressured up to 720/500 psi with 1.1 bbls neat methanol. T/I lost 0 psi in 30 minutes. Circ -out - Pumped 5 bbls neat methanol spear, 1002 bbls 1% kcl and 147 bbls diesel. Let u -tube for 1 hr. Freeze protect hardline and flow line on well #32 with 6 bbls neat and 1 bbl diesel in hardline. Final WHP= 200/200/20. 09/17/11 T /I /O= SSVNac /Vac. Temp =SI. Bleed IA & OA to 0 psi. IA & OA FLs near surface. 09/18/11 T /I /O= SI /0 /0 Temp =S1 PPPOT -T (PASS) (W /H repair ) PPPOT -T : RU 1 HP BT onto THA test void 0 psi, verified with SBS. Flushed void until clean returns, pressured to 5000 psi for 30 minute test, 4950/ 15 min, 4950/ 30 min. Bled through SBS, RD test equipment, removed Alemite and removed internal check, re installed Alemite. RU 1 HP BT pressured to 5000 psi for 5 min test, no pressure loss. RD test equipment, re installed cap. Page 2 of 2 1 • North America - ALASKA - BP Page 1 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/19/2011 06:00 - 11:00 5.00 MOB P PRE CHECK PLANITARIES ON RIG. - REMOVE SCAFFOLDING AND BERM'S AROUND RIG. - PULL RIG MATS FROM UNDER RIG. - PREP DERRICK TO LAY OVER. - INSTALL WALL IN WHEEL WELL. - CHANGE HOSES AROUND ON MOVING SYSTEM. 11:00 - 14:00 3.00 MOB P PRE RIG UP AND START TO MOBILIZE MAN CAMP TO MOBILE PAD. - INSTALL REAR BOOSTERS ON RIG. - RIG LOADER EXPERIENCED OIL LEAK. @ 13:30, LESS THAN 1 GAL. WELLS HSE, MPU ENVIRONMENTAL, AND RWO SUPERINTENDENT WERE NOTIFIED. MPU ENVIRONMENTAL TO CONTINUE CLEAN UP AND MONITORING OF PAD. 14:00 - 20:00 6.00 MOB P PRE HOLD PJSM FOR POSITIONING RIG FOR DERRICK DOWN - STARTED TO REPOSITION RIG AS PLANED FOR DERRICK DOWN. - DURING REPOSITIONING PAD GAVE WAY AND RIG WAS STUCK. - REASSESS AND MADE NEW PLAN FORWARD. - LAYED DERRICK OVER. - INSTALLED FRONT BOOSTERS. - CUT LUMBER TO CRIB UNDER TIRES. - PULLED RIG FORWARD AND STAGED ONTO MILNE POINT ROAD. 20:00 - 00:00 4.00 MOB P PRE MOVE RIG FROM TEXACO PAD TO MPU ROAD AND SPINE ROAD INTERSECTION. 9/20/2011 00:00 - 06:00 6.00 MOB P PRE STAGE RIG AT MPU AND SPINE ROAD INTERSECTION, WHILE TOOL SERVICE LAYS MATS ON SPINE ROAD AS NEEDED. 06:00 - 19:00 13.00 MOB P PRE CONTINUE TO STAGE RIG AT MPU AND SPINE INTERSECTION WHILE KUPARUK AND MPU BUSES TRANSPORT PEOPLE TO AND FROM THE AIRPORT. 19:00 - 20:00 1.00 MOB P PRE MOVE RIG DOWN SPINE TOWARD GPB. Printed 11/14/2011 1:58:24PM Nora Orioa - ALASKA - Bp Pa 2 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) . Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 MOB N RREP PRE AT 20:00 RIG WAS TRAVELING OVER A SERIES OF CULVERTS —150 YARDS EAST OF THE KUPARUK GUARD SHACK WHEN THE REAR DRILLER'S SIDE TIRE FELL THROUGH THE ROAD. THE IMPACT AND WEIGHT OF THE RIG TRANSFERRED TO THE FRONT BOOSTER AXLE AND BROKE OFF THE AX EL HOUSING BODY. ALL LEVEL 0 NOTIFICATIONS WERE MADE INCLUDING COMMUNICATION WITH KUPARUK, PIONEER AND ENI SINCE TRAVEL WILL BE RESTRICTED. THE IMT COMMANDER WAS ALSO NOTIFIED. DOYON SAFETY, DOYON SUPERINTENDENT, DOYON TPS, BP WSLS, MPU ENVIRONMENTAL AND BP FIELD ENGINEERS MET AT THE RIG TO EVALUATE A PLAN FORWARD. PLAN FORWARD: - RECOVER MATS ON ROAD EAST OF THE RIG TO FACILITATE ACCESS, ESTIMATED TIME 6 HOURS -STAGE GRAVEL ON KUPARUK SIDE OF RIG, ESTIMATED TIME 4 HOURS -WAIT FOR DAYLIGHT TO FACILITATE A SAFE • PLAN FORWARD WITH BP SAFETY AND DOYON UPPER MANAGEMENT. 9/21/2011 00:00 - 06:00 6.00 MOB N RREP PRE RECOVER RIG MATS EAST OF RIG -STAGE GRAVEL ON KUPARUK SIDE OF RIG -RIG CREW PAINTING IN MOTOR ROOM - CONTINUE TO WAIT ON DAYLIGHT AND RISK ASSESSMENT 06:00 - 10:00 4.00 MOB N RREP PRE WAIT ON FINAL PLAN FORWARD DEVELOPMENT AND APPROVAL. -BP AND DOYON SUPTS AND SAFETY ON LOCATION TO RISK ASSESS FORWARD OPERATIONS FOR RIG EXTRACTION -RIG MAT REMOVAL FROM SPINE ON PRUDHOE SIDE OF RIG FINISHED Printed 11/14/2011 1:58:24PM Northrica = ALASKA - BP Page 3 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 12:00 2.00 MOB N RREP PRE EXTRACTION PLAN MEETING IN ATTENDANCE: BP RWO SUPTS, MPU HSE, MPU OSM, MPU, OTL, MPU ROADS & PADS, MPU OPS COORDINATOR, COP ENVIRONMENTAL, MPU ENVIRONMENTAL, COP CAMP MANAGER, TOOL SERVICE, DOYON 16 DRILLER AND TP, AES ROADS & PADS SUPT AND LEAD, KUPARUK ROADS & PADS, DOYON SUPT, DOYON SAFETY, WSL, BP DRILLING HSE, BP FIELD ENGINEERS PLAN SUBMITTED FOR FINAL APPROVAL 1. REMOVE FRONT BOOSTER SYSTEM 2. REINFORCE 2 CULVERTS IN FRONT OF DAMAGED CULVERT INTERNALLY WITH TIMBERS 3. SHORE UP DAMAGED CULVERT END WITH SEALS AND PLYWOOD - -NO PERSONNEL ENTRY 4. FILL HOLE BELOW RIG TIRE, DOWN TO DAMAGED CULVERT WITH BAGS OF GRAVEL AND WOOD IF NEEDED. 12:00 - 00:00 12.00 MOB N RREP PRE FILL 100 BAGS OF GRAVEL TO PREP FOR HOLE FILLING. -PAINT IN VARIOUS LOCATIONS INSIDE RIG: RIG FLOOR, MOTOR ROOM FLOOR. 9/22/2011 00:00 - 06:00 6.00 MOB N RREP PRE CONTINUE TO PAINT IN VARIOUS LOCATIONS INSIDE RIG: RIG FLOOR, MOTOR ROOM FLOOR. 06:00 - 12:00 6.00 MOB N RREP PRE RISK ASSESS CULVERT ENTRY WITH BP AND COP ROAD CONSTRUCTION/CULVERT ENGINEERS. REPORT SUBMITTED FOR APPROVAL AND PLAN FORWARD. RIG CREW CONTINUE PAINTING PROJECTS INSIDE RIG. 12:00 - 15:00 3.00 MOB N RREP PRE HAZARD ASSESS FRONT BOOSTER TIRE REMOVAL WITH BP SUPT, BP SAFETY, PEAK, RIG CREW, DDI SUPT WAIT FOR APPROVAL OF PLAN FORWARD. 15:00 - 19:00 4.00 MOB N RREP PRE APPROVAL RECIEVED FOR BOOSTER TIRE REMOVAL. OPERATION OVERSIGHT BY DDI SUPT AND BP WSL. -5 PJSM BEFORE EACH STEP OF THE OPERATION. - 1QTAXLE GREASE CLEANED UP UNDER BROKEN AXLE. THIS LEAK OCCURED WITH THE INITIAL INCIDENT, BUT CLEAN -UP WAS POST -PONED UNTIL AREA MORE SECURE. 19:00 - 20:30 1.50 MOB N RREP - PRE RIG CREW FILL 150 ADDITIONAL SANDBAGS WITH GRAVEL FOR A TOTAL OF 250 -50# BAGS. 20:30 - 00:00 3.50 MOB N RREP _ PRE RIG CREW CONTINUE WITH PAINTING PROJECTS AND FILLING 200 SANDBAGS. 9/23/2011 00:00 - 06:00 6.00 MOB N RREP _ PRE FILL 200 SAND BAGS, CONTINUE WITH PAINTING PROJECTS INSIDE RIG. Printed 11/14/2011 1:58:24PM North -rica - ALASKA - BP Page 4 of 25 . Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 09:30 3.50 MOB N RREP PRE SITE CONTROL PLAN ESTABLISHED WITH SPOC, SECURITY AND WSL (AREA AUTHORITY) -RIG CREW WORKING ON DERRICK LIGHTS - ELECTRICIAN FINISHED CONNECTION FOR RIG POWER BOX TO MPU ESP SPOOLER 09:30 - 11:00 1.50 MOB N RREP PRE LEVEL 2 RISK ASSESSMENT MEETING FOR PLAN FORWARD - SPOTTERS DESIGNATED FOR VEHICLES TURNING AROUND ON BOTH SIDES OF FOOT BRIDGE 11:00 - 13:00 2.00 MOB N RREP PRE ENVIRONMENTAL IMPACT INSPECTION OF CONTROL OF WORK AREA WITH BP WSL AND MPU ENVIRONMENTAL - DRIP - LINERS IN PLACE, PARKING AREA, BUILT BERM AT BUS RAMP TO PREVENT ANY RELEASE FROM GETTING TO THE WATER. 13:00 - 15:00 2.00 MOB N RREP PRE CONTINUE AND FINISH LEVEL 2 RISK ASSESSMENT WITH BP SUPT, FIELD ENGINEERS, BP SAFETY AND DOYON SAFETY, BP WSL, DOYON TP, AND MPU ENVIRONMENTAL 15:00 - 17:00 2.00 MOB N RREP PRE DOYON LEADERSHIP DISCUSSED RIG SITUATION / SAFETY WITH NEW CREW FROM TOWN. - MOBILIZED PPE AND SAFETY EQUIPMENT FOR PLAN FORWARD ON LOCATION 17:00 - 19:00 2.00 MOB N RREP PRE DAY /NIGHT CHANGEOUT FOR TP AND WSL - STANDBY WAITING ON FINAL APPROVAL OF PLAN FORWARD AND RISK ASSESSMENT. 19:00 - 00:00 5.00 MOB N RREP PRE CONTINUE TO STAND BY FOR FINAL APPROVAL TO PROCEED. -STAGE EQUIPMENT FOR CULVERT PROJECT (PPE, RIP -RAP, BARRICADES) -RIG CREW ASSISTING WITH SITE CONTROL AND PAINTING IN PIPE SHED 9/24/2011 00:00 - 06:00 6.00 MOB N RREP PRE STANDBY WAITING ON FINAL PLAN APPROVAL, RIG CREW SORTING PLYWOOD FOR CULVERT SHORING AND PAINTING PROJECTS 06:00 - 12:00 6.00 MOB N RREP PRE CONTINUE TO STANDBY FOR FINAL APPROVAL OF PLAN FORWARD -11:00 APPROVAL RECEIVED FROM IMT/ BP SUPT - MOBILIZE TOOL SERVICE, CH2MHILL SUPPORT FOR CULVERT PROJECT 12:00 - 13:30 1.50 MOB N RREP PRE BP ENGINEER, MIKE WASSMANN, ON SITE FOR INSPECTION OF RIG WEIGHT 13:30 - 15:30 2.00 MOB N RREP PRE PJSM TO REMOVE TRUNION ON FRONT BOOSTER SYSTEM -VISIT FROM IMT COMMANDER SHAWN CROGHAN, MPU OSM WAYNE HAUGER, ADW AND BP SAFETY 15:30 - 16:30 1.00 MOB N RREP PRE PJSM FOR PLAN FORWARD WITH RIG CREW AND D &C FIELD ENGINEER 16:30 - 20:00 3.50 MOB N RREP PRE FILL SUPER BAGS WITH GRAVEL AND PLACE 1 IN CREEK BED NEAR CULVERTS TO CREATE FOUNDATION FOR RIG MATS. -CUT SHARP EDGE OF CULVERT #6 OFF FOR ACCESSIBILITY Printed 11/14/2011 1:58:24PM North Oh Oa - ALASKA - BR Page 6 of 25 Operatio Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 20:30 0.50 MOB N RREP PRE PJSM FOR INSTALLING LUMBER AND PLYWOOD INTO CULVERTS #6 AND #7 -RIG CREW, TOOL SERVICE CREW, FIELD ENGINEER, MPU ENVIRONMENTAL DISCUSSED HAZARDS, LIGHTING, TEAM WORK -CALL FROM IMT COMMANDER WITH FINAL APPROVAL TO ENTER CULVERTS 20:30 - 00:00 3.50 MOB N RREP PRE BEGIN CULVERT SHORING TOOL SERVICE CREW WORKING IN CULVERT #6 - PLACED 18 -3 "X12" LUMBER, 146 -4'X8' PLYWOOD, ADSORB AND 13 CLIPS AROUND OUTSIDE OF CULVERT RIG CREW WORKING ON CULVERT #7 - PLACED 20- 20'X3 "X12" LUMBER, 10- 10'X3 "X12" LUMBER, 60 -4'X8' PLYWOOD, ADSORB AND 10 CLIPS AROUND OUTSIDE OF CULVERT CONTINUED DOCK EXTENSION BY PLACING 11 MORE SUPER BAGS FILLED WITH GRAVEL IN THE CREEK AS FOUNDATION FOR RIG MATS. END CULVERT WORK AT 00:00. 9/25/2011 00:00 - 06:00 6.00 MOB N RREP PRE PREPPING LUMBER FOR CULVERT PROJECT CONTINUATION AROUND 8 AM. PAINTING PROJECTS INSIDE RIG. 06:00 - 07:30 1.50 MOB N RREP - PRE SAFETY MEETING WITH RIG CREW 07:30 - 10:00 2.50 MOB N RREP PRE TOOL SERVICE AND FIELD ENGINEER ON LOCATION TO BEGIN CULVERT WORK FOR THE DAY. -PJSM WITH CREWS - CONTINUE PLYWOOD WORK IN CULVERTS #6 AND #7 - FINISH SHIMMING CULVERT #7 ON TOP OF PLYWOOD BUNKS. 10:00 - 13:00 3.00 MOB N RREP PRE PJSM FOR FLUID TRANSFER AROUND RIG OF CORROSION INHIBITOR TO MPU -VISIT FROM IMT -BP ENVIRONMENTAL, MPU OTL, NALCO, WELL SUPPORT TECHS - SUCCESSFUL TRANSFER OF 1000 GAL OF CORROSION INHIBITOR 3 TOTES) 13:00 - 14:30 1.50 MOB N RREP - PRE VISIT FROM BP ENGINEER FOR SITE ASSESSMENT -VISIT FROM KUPARUK IMT 14:30 - 15:30 1.00 MOB N RREP PRE PJSM FOR AXLE WORK -WELD BOOSTER AXLE TO TRUNION -CLEAR ALL PERSONEL FROM CULVERTS TO ENERGIZE THE MOVING SYSTEM TEMPORARILY. 15:30 - 16:00 0.50 MOB N RREP PRE KUPARUK MEDIVAC PATIENT CAME THROUGH ON FOOT BRIDGE -WORK HALTED UNTIL INDIVIDUAL WAS CLEAR Printed 11/14/2011 1:58:24PM North Orica 7,ALASKA - BP : Page 6 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 16:00 - 17:00 1.00 MOB N RREP PRE PJSM/PLAN FORWARD FOR SHIMMING WHEEL WELLS -ADW SAFETY AND DOYON SUPT PRESENT - FINISHED CULVERT #7 AT 16:45 17:00 - 21:30 4.50 MOB N RREP PRE CONTINUE WORKING ON CULVERT #6 - FINISH CULVERT #6 AT 21:15 -TOOL SERVICE CREW RELEASED -RIG WELDER CUT OFF ROLLED EDGES OF CULVERT #5 PREPPING FOR LUMBER INSTALLATION SECOND FLUID TRANSFER OF CORROSION INHIBITOR FROM GPB TO MPU FROM 18:00 - 20:30. 21:30 - 00:00 2.50 MOB N RREP PRE FINISH PLACING SUPER BAGS FOR CULVERT #5 DOCK - POSITION RIG MATS FOR DOCK -SHUT DOWN CULVERT OPERATIONS UNTIL NEXT MORNING. 9/26/2011 00:00 - 06:00 6.00 MOB N RREP _ PRE SHIMMING RIG, CUT SHIMS, STAGE PLYWOOD IN CELLAR 06:00 - 07:30 1.50 MOB N RREP - PRE EXTEND DOCK WITH ANOTHER LAYER OF RIG MATS FOR MORE STABLE FOUNDATION FOR LOADER. 07:30 - 08:00 0.50 MOB N RREP _ PRE MORNING CALL WITH TOWN: ADW FIELD ENGINEER, BP SUPT, WSL PRESENT 08:00 - 10:00 2.00 MOB N RREP - PRE START WORKING ON CULVERT #5 -SCOOP GRAVEL OUT OF CULVERT WITH LOADER 10:00 - 13:00 3.00 MOB N RREP PRE RE- EVALUATE PLAN FORWARD BASED ON CULVERT #5 CONDITION AFTER REMOVING GRAVEL -DOYON SUPT, BP WSL AND ADW FIELD ENGINEER 13:00 - 16:00 3.00 MOB N RREP - PRE RIG WELDER CUT COLLAPSED SECTIONS OF CULVERT OUT WITHOUT ENTERING. -MPU SAFETY ON LOCATION 16:00 - 19:00 3.00 MOB N RREP PRE SUPERSUCKER ON LOCATION TO REMOVE GRAVEL FROM CULVERT #5 FROM ABOVE -START REMOVING GRAVEL, SHUT DOWN OVER WATER TURBIDITY -BUILD BARRIER TO ISOLATE TURBID WATER INSIDE CULVERT FROM CREEK BED 19:00 - 21:00 2.00 MOB N RREP PRE ON STANDBY FOR MPU AND KUPARUK ENVIRONMENTAL AND NS BOROUGH FIELD INSPECTOR, CHARLES RUSSELL, TO DO SITE INSPECTION. 21:00 - 00:00 3.00 MOB N RREP PRE BUILD HERCULITE BARRIER WITH SAND BAGS AT EDGE OF RIG MAT DOCK TO PROTECT CREEK BED - SHOVEL AND SMOOTH OUT GRAVEL IN CULVERT #5 WITH ZOOM BOOM -PLACE 20' X 3 "X12" RAFT IN CULVERT #5 WITH LOADER AND STINGER -STAGE 20' X 10" X 10" LUMBER FOR CULVERT SHORING. 9/27/2011 00:00 - 07:30 7.50 MOB N RREP _ PRE STAGE TIMBERS FOR CULVERT SHORING WHICH WILL CONTINUE LATER IN THE DAY 07:30 - 08:00 0.50 MOB N RREP - PRE MORNING CALL WITH TOWN Printed 11/14/2011 1:58:24PM .: North ,irica - ALASKA - BP Page 7 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 08:00 - 17:00 9.00 MOB N RREP PRE START TIMBER INSTALLATION IN CULVERT #5 WITH ZOOM BOOM - CONTINUE SHORING UP CULVERT #5 -VISIT FROM NS BOROUGH INSPECTOR, CHARLES RUSSELL -WSL AND ADW FIELD ENGINEER CHANGEOUT 17:00 - 20:30 3.50 MOB N RREP PRE SHIM RIG IN PREPARATION FOR MOVING - FINALIZE TIMBER STRUCTURE IN CULVERT #5 20:30 - 21:30 1.00 MOB N RREP PRE DEFLATE INTERIOR TIRE ON REAR DRILLER'S SIDE TO STRAIGHTEN TIRE SET AND LIFT AS HIGH AS POSSIBLE WITH CYLINDER. -STAGE LUMBER FOR HOLE FILL 21:30 - 00:00 2.50 MOB N RREP PRE PJSM FOR HOLE FILLING -PLACE 6 LAYERS OF 10 "X10" LUMBER REINFORCED WITH SAND BAGS INTO HOLE OVER CULVERT #5 FROM ABOVE. -PLACE RIG MATS IN FRONT OF RIG 9/28/2011 00:00 - 01:00 1.00 MOB N RREP PRE CREW CHANGE AND PJSM FOR HOLE FILL FINALIZING - FINISH FINAL LAYER OF TIMBERS UNDER REAR TIRES (6 TOTAL LAYERS OF 10" X 10 ") -PLACE SAND BAGS AROUND ALL SURFACE TIMBERS FOR STABILITY 01:00 - 02:00 1.00 MOB N RREP PRE PJSM FOR RIG MOVE, POSITIONS OUTLINED, RADIO COMMUNICATION CONFIRMED - NOTIFIED SECURITY AND MPU OF JACKING - JACKED UP RIG AND MOVED FORWARD —120' @ 1:35AM ✓ - NOTIFIED IMT LEAD, TOOL SERVICE, FIELD ENGINEER 02:00 - 07:00 5.00 MOB N RREP PRE RIG CREW GATHERING LUMBER, SHIMS, EQUIPMENT AND DEBRIS FROM EXTRACTION SITE. 07:00 - 08:00 1.00 MOB N RREP PRE IMT MEETING AND MORNING CALL WITH TOWN 08:00 - 13:00 5.00 MOB N RREP PRE KUPARUK BEGIN ROAD REPAIR -RIG WELDER CONTINUE WORK REPAIRING MINOR DAMAGE ON REAR BOOSTERS - INSPECT BEAM SYSTEM ON THE BOTTOM OF RIG 13:00 - 18:00 5.00 MOB N RREP PRE CONTINUE ROAD WORK -CLEAR OUT PARKING AREA TO STAGE SUPPLIES FOR MPU AND KUPARUK -RIG CREW STARTING GPB COMISSIONING CHECKLIST FOR RETURN TO PRUDHOE BAY. - INSTALL FRONT BOOSTER TIRES TO REPAIRED AXLE SYSTEM. 18:00 - 19:00 1.00 MOB N RREP PRE CONTINUE SPINE ROAD WORK -LAY RIG MATS IN FRONT OF RIG UP TO WHERE BUSES ARE STAGED -RIG CREW CONTINUING RIG COMMISSIONING PREP WORK 19:00 - 20:00 1.00 MOB N RREP PRE NS BOROUGH INSPECTOR VISIT. - PLEASED WITH THE WAY THE EXTRACTION WAS CARRIED OUT. Printed 11/14/2011 1:58:24PM .. North erica - ALASKA- BP Page 8 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 00:00 4.00 MOB N RREP PRE CONTINUE SPINE ROAD WORK -LAY RIG MATS IN FRONT OF RIG UP TO WHERE BUSES ARE STAGED -RIG CREW CONTINUING RIG COMMISSIONING PREP WORK AT 22:30 CREW MEMBER WAS GRINDING IN THE CELLAR WHEN A FUME CLOUD IGNITED AND HE PUT IT OUT WITH A NEARBY FIRE EXTINGUISHER. PRIOR TO STARTING THE JOB HE HAD CLOSED THE "FLAMMABLES" CLOSET DOOR SEVERAL FEET AWAY FROM WHERE HE WOULD BE WORKING AND ENGAGED THE NOZZLE OF A CAN OF BRAKLEEN. THE EXTINGUISHER WAS BROUGHT TO CAMP FOR SERVICE. 9/29/2011 00:00 - 02:30 2.50 MOB N RREP PRE FINISH SPINE ROAD WORK - COMPLETE DERRICK INSPECTION (THE CROWN WILL NEED TO BE INSPECTED WHEN RAISED) - FUNCTION TEST RIG MOVING SYSTEM: FORWARD, BACKWARD, UP, DOWN AT 2 AM 02:30 - 03:00 0.50 MOB N RREP PRE SAFETY MEETING WITH NEW CREW ON TOUR ABOUT FUME IGNITION INCIDENT. EMPHASIZED PERMITTING, HOUSEKEEPING AND FIRE EXTINGUISHER USE. 03:00 - 07:00 4.00 MOB N RREP PRE RIG CREW BEGIN AUDIT CHECKLIST. 07:00 - 08:00 1.00 MOB N RREP PRE IMT MEETING AND MORNING CALL WITH TOWN 08:00 - 10:00 2.00 MOB N RREP PRE SPINE ROAD REPAIR INSPECTION BY COP STRUCTURAL ENGINEER - DETERMINED ROAD QUALITY ADEQUATE FOR VEHICLE TRAFFIC 10:00 - 12:00 2.00 MOB N RREP PRE RIG MOVE ROUTE INSPECTION BY ADW FIELD ENGINEER, TOOLPUSHER AND IMT -PLAN DEVELOPED FOR LAYING 350 -400 RIG MATS IN CRUCIAL SPOTS FROM RIG TO Z PAD. 12:00 - 15:30 3.50 MOB N RREP PRE MOVE BUSES STAGED EAST OF RIG AND LAY RIG MATS OVER ENTIRE SECTION OF ROAD ON WHICH THE RIG WILL BE MOVING FORWARD AND BACKWARD DURING SUPPLY STAGING AND DELIVERY TO KUPARUK AND MILNE POINT. -MOVE THE RIG EAST AND WEST OF THE STAGING AREA SEVERAL TIMES. 15:30 - 17:00 1.50 MOB N RREP PRE FIRE INCIDENT DISCUSSION -WSL, TOOLPUSHER, DOYON SAFETY, DOYON ANCHORAGE MANAGER, 2 RIG CREW MEMBERS INVOLVED WERE PRESENT - IR-3955644 17:00 - 22:00 5.00 MOB N RREP PRE CONTINUE SUPPLY STAGING FOR TRUCK ACCESS TO MPU AND KUPARUK AT 8 PM. -ALLOW TRAFFIC FROM KUPARUK TO TRAVEL EAST 22:00 - 00:00 2.00 MOB N RREP PRE BEGIN TO FILL PARKING AREA FOR TRAFFIC HEADING WEST TO KUPARUK AND MILNE POINT -SPOT TRUCKS IN STAGING AREA -WAIT FOR FINAL TRUCK Printed 11/14/2011 1:58:24PM North erica - ALASKA - BP Pais 9 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 9/30/2011 00:00 - 01:30 1.50 MOB P PRE RIG MOVE TO EAST OF STAGING AREA ALLOWING TRAFFIC TO ACCESS KUPARUK AND MILNE POINT. 01:30 - 11:00 9.50 MOB P PRE LAY RIG MATS EAST OF RIG FOLLOWING RIG MOVE ROUTE PLAN. - STAGING MORE RIG MATS ON L PAD FOR UPCOMING MOVE 11:00 - 18:00 7.00 MOB P PRE SHUFFLING THE RIG BACK AND FORTH TO ALLOW FOR SUPPLY TUCKS TO GET INTO KUPARUK AND MILNE PT. - SHUFFLING RIG FOR CHANGE OUT BUSSES. - TOOL SERVICES AND MPU ENVIRO REMOVED THE SAND BAGS AND RIG MATS FROM THE RIVER AREA NEXT TO THE CULVERTS WHERE THE RIG BROKE THRU. 18:00 - 00:00 6.00 MOB P PRE SPINE RD SHUT DOWN - ACCESS THRU TO THE WEST SHUT DOWN TO ALLOW FOR TOOL SERVICES TO LAY THE RIG MATS IN ORDER TO MOVE THE RIG TO THE Z -PAD TURN OFF. 10/1/2011 00:00 - 06:00 6.00 MOB N RREP PRE CONTINUE LAYING RIG MATS ON THE SPINE ROAD. - START MOBOLIZING RIG TOWARDS Z -PAD ACCESS @ 05:30 06:00 - 11:30 5.50 MOB N RREP PRE RIG ON THE ROAD FROM THE CULVERT BRIDGE TO THE Z -PAD TURN OFF. 11:30 - 16:30 5.00 MOB N RREP PRE MOVE RIG MATS FROM BEHIND THE RIG TO THE Z -PAD TURN OFF. - MOVE THE RIG INTO THE TURN OFF SO THAT THE SPINE ROAD WAS UNABSRUCTED. 16:30 - 19:30 3.00 MOB N RREP PRE CONTINUE TO REMOVE THE RIG MATS FROM BEHIND THE RIG. 19:30 - 00:00 4.50 MOB N RREP PRE ROAD IS STILL UNDER THE IMT CONTROL. - THE RIG WILL REMAIN IN THIS POSITION FOR A MIN OF 24 HOURS TO ALLOW FOR TRUCK TRAFFIC REVIEWED THE FIRE INCIDENT FROM THE 28TH WITH CREW ON TOWER. - DISCUSSED THE CAR REPORT AND THE ACTION ITEMS. THE ACTION ITEMS WILL BE DOCUMENTED IN TRACTION IR # 3955644 10/2/2011 00:00 - 06:00 6.00 MOB N RREP PRE RIG IS SITTING ON THE Z -PAD TURN OFF . ROAD IS STILL UNDER THE IMT CONTROL. - THE RIG WILL REMAIN IN THIS POSITION FOR A MIN OF 24 HOURS TO ALLOW FOR TRUCK TRAFFIC TILL AT LEAST 16:00 TONIGHT. THIS MAY BE EXTENDED BY THE IMT 06:00 - 18:00 12.00 MOB N RREP PRE DISCUSSED PLAN FORWARD WITH DOYON 14 WSL - DUE TO DOYON 14 HAVING AN UPCOMING 2 STAGE CEMENT JOB THE DECISION WAS MADE TO START THE RIG MOVE AFTER THEY COMPLETE THE FIRST STAGE AND GET THE CEMENT TRUCKS OUT. 18:00 - 00:00 6.00 MOB N RREP PRE RIG ON STANDBY AT Z -PAD TURN OFF. 10/3/2011 00:00 - 10:00 10.00 MOB N RREP PRE STILL WAITING ON D -14 TO COMPLETE THEIR FIRST STAGE OF THE CEMENT JOB Printed 11/14/2011 1:58:24PM Nprth .+ rid _ ALASKA BP Page 10 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:00 - 15:30 5.50 MOB P PRE MOBOLIZE RIG FROM Z -PAD TURN OFF TO S -PAD WELL # 9 15:30 - 20:00 4.50 MOB P PRE SET UP ON S PAD , - SET UP SCS TRAILER - RIG CREW SETTING RIG MATS AROUND THE WELL. - REMOVE BOOSTER WHEELS - RAISE THE DERRICK , - C/O VBR'S IN THE BOP , INSTALL 3 -1/2" X 6" - PU BOP'S 20:00 - 00:00 4.00 MOB P PRE PERFORMING RIG ACCEPTANCE CHECKLIST - SPOT RIG OVER THE WELL, - SPOTTING THE SLOP TANK 10/4/2011 00:00 - 06:00 6.00 MOB N RREP PRE RE -SPOT THE RIG - THE FRONT BOOSTER WHEELS CAUSED LIMITED ACCES AROUND THE BACK OF THE RIG. - THE PAD OPERATOR WAS NOT HAPPY WITH THE CONFIGURATION. THE RIG WAS RESPOTTED TRYING TO MAKE MORE ROOM UNTIL THE PAD OPERATOR WAS HAPPY. - PERFOMING THE DERRICK INSPECTION - WHILE PERFORMING THE INSPECTION THE # 2 GENERATOR WENT DOWN. NC CAT MAN WAS CALLED OUT. - SPOTTED AND START RIGGING UP THE # 2 PUMP. 06:00 - 08:00 2.00 MOB N RREP PRE RE- POSITION THE DERRICK, - THE TORQUE TUBES WOULD NOT PIN RIGHT, IT WAS FOUND THAT ONE OF THE LIFTING EYES WAS PINCHED WHEN THE DERRICK WAS RAISED. THE CREW RE- POSITIONED THE DERRICK AND REMOVED THE LIFTING EYE. THE NC CAT MECHANIC IS ON LOCATION WORKING ON THE # 2 GENERATOR. FOUND THAT THE SOFT START FOR TH COOLANT FAN WAS NOT WORKING PROPERLY,. 08:00 - 13:30 5.50 MOB P PRE BRIDLE UP, FINISH RIGGIN UP THE FLOOR FINISHING THE DERRICK INSPECTION - PERFORMING THE CROWN INSPECTION. - FUNCTION TESTED THE ESD, HAD THE ELECTRICIAN PRESENT FOR THE TEST, THE SYSTEM TESTED PERFECTLY, SHUTTING DOWN BOTH GENERATORS AND ALL POWER. - RIG CREW CONTINUING THE RIG UP FOR WELL WORK OPERATIONS Printed 11/14/2011 1:58:24PM North *rim- ALASKA:- BP Page 1 1 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 22:00 8.50 RIGU P PRE THE WELDER IS WORKING ON THE PRESSURE RELIEF LINE FROM THE # 2 MUD PUMP. - BP SAFETY AND DOYON TP AND SAFETY ARE WORKING ON THE RECOMMISSIONING CHECKLIST. DONE WITH THE CHECK LIST AT 16:30 , WSL AND BP SAFETY CALLED RWO TL TO CONFIRM THAT THE RIG WAS READY TO GO BACK TO WORK. -RIG UP THE CREW TRAILER - DOUBLE CHECK THE BOLTS ON THE TORQUE TUBES TAKING ON SEAWATER TO THE PITS , 100 DEG, 8.55 PPG - CHECK THE CROWN 0 MATIC AND - RIG UP CIRCULATING LINES 22:00 - 22:30 0.50 RIGU P PRE RIG EVAC DRILL AND AAR - ONE HAND DID NOT MUSTER, DRILL WAS CALLED OUT ON GAI- TRONICS AND HARMONY RADIO. HAND WAS USING BATHROOM IN CHANGE TRAILER AND DID NOT KNOW ABOUT DRILL. FOUND THAT GAI TRONICS CORD IS TOO SHORT TO PLUG INTO THE RIG IN IT'S CURRENT LOCATION AND TOOL PUSHERS WILL HAVE AN EXTENSION BUILT ASAP. -ALL TRUCK DRIVERS AND DSM CREWS REPORTED TO PRIMARY MUSTER AREA. -RIG HANDS BROUGHT UP THAT TRUCK DRIVERS NEED TO BE MINDFUL TO SHUTDOWN THERE TRUCKS WHEN THEY LEAVE THEM FOR THE MUSTER POINT, OR "SIMULATE" IT FOR DRILLS TO BE IN THE HABIT FOR THE REAL THING. 22:30 - 00:00 1.50 RIGU P PRE PJSM/ RU DSM LUBRICATOR AND PRESSURE TEST TO 250/4,000 PSI FOR 5 MIN TEST AGAINST CLOSED SSV AND MASTER VALVE -CHASE AIR OUT OF TREE/LUBRICATOR. 10/5/2011 00:00 - 02:00 2.00 BOPSUR P PRE CONTINUE TO WORK AIR OUT OF TREE - REPACK DSM LUBRICATOR AND GREASE TREE -GOT GOOD TEST 250 LOW / 4000 HIGH FOR 5 CHARTED MIN 02:00 - 03:00 1.00 BOPSUR P PRE PULL BPV - DSM CREW REPORTED WELL HAD A SMALL VAC WHEN BPV PULLED RD DSM LUBRICATOR 03:00 - 07:00 4.00 BOPSUR N RREP PRE RU TO TOP OF TREE TO CIRCULATE OUT DIESEL FROM WELL, ATTEMPT PRESSURE TEST SURFACE LINES - UNABLE - RE -ALIGN MUD PUMP 1 POP -OFF LINE ATTEMPT PRESSURE TEST SURFACE LINES - UNABLE - TIGHTEN UP BLIND FLANGE ON CHOKE MANIFOLD Printed 11/14/2011 1:58:24PM •, North America - ALASKA -SP. • 0 Page 12 of 25 'Operation S Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:00 - 13:00 6.00 BOPSUR N RREP PRE REMOVED FLANGE FROM BLOCK VALV E. - FLANGE IS BAD, TRYING TO FIND A NEW ONE, TROUBLES FINGING ONE WITHOUT A PORT ON IT - - FOUND A 3 -1/8" 5K POUND NON PORTED FLANGE. -MPI'D MUD PUMP #2 POP OFF LINE - FINISH R/U MUD PUMP #2 -H2S RIG EVAC. DRILL 13:00 - 16:30 3.50 BOPSUR P PRE PJSM FOR TESTING SURFACE LINES. - FILLED LINES AND GAS BUSTER - TEST TO 250 PSI LOW AND 4000 PSI HIGH, GOT GOOD TEST FOR BOTH LOW AND HIG PRESSURES 16:30 - 19:00 2.50 BOPSUR P PRE LINED UP TO REVERSE CIRCULATE 51 BBLS OF DIESEL FREEZE PROTECT FROM THE TBG - SWITCH AND PUMP DOWN THE TBG AND UP THE IA , CIRCULATE DIESEL OUT TILL RETURNS CLEAN UP. - PUMPED MAX 5 BPM ,180 -280 PSI. 19:00 - 20:00 1.00 BOPSUR P PRE CIRCULATE BOTTUMS UP AT 5 BPM & 350 PSI MONITOR WELL - NO FLOW 20:00 - 20:30 0.50 BOPSUR P PRE RIG DOWN CIRCULATING EQUIPMENT 20:30 - 23:00 2.50 BOPSUR P PRE PJSM/ RU DSM LUBRICATOR PRESSURE TEST LUBRICATOR AGAINST CLOSSED MASTER AND SURFACE SAFETY VALVES -250 PSI LOW / 4,000 PSI HIGH - CHART FOR 5 MIN SET TWC AND TEST - TEST 250 / 4000 PSI FROM ABOVE AND THEN BELOW - CHART FOR 5 MIN EACH 23:00 - 00:00 1.00 BOPSUR P PRE RD DSM AND SUCK OUT TREE 10/6/2011 00:00 - 03:30 3.50 BOPSUR P PRE PJSM / ND TREE AND LD WITH OA OPEN AND MONITORED TO SLOP TANK - BLEED OFF & SECURE CONTROL LINES - REMOVE TREE FROM CELLAR - EXERCISE LOCK DOWN SCREWS AND MEASURE - 5 -1/2" MAX OUT, 4 -1/2" CLEAR, 3 -1/2" FULL IN 03:30 - 06:00 2.50 BOPSUR P PRE PJSM, NU BOP - TIGHTEN PIPE RAM DOORS - FUNCTION TEST KOOMEY 06:00 - 15:00 9.00 BOPSUR P PRE CHANGING OUT THE BLOCK VALVE ON THE CHOKE MANIFOLD. - MU TEST EQUIPMENT FOR BOP TESTING - CONDUCT BODY TEST ON THE BOP , 250 LOW AND 4000 HIGH, TIGHTEN LEAKS - INVENTORY OF THE NEW DP STRING, AND RENTAL EQUIPMENT. 15:00 - 17:00 2.00 BOPSUR N RREP PRE CONTINUE CHANGING OUT THE 5 WAY BLOCK ON THE CHOKE MANIFOLD 17:00 - 18:30 1.50 BOPSUR P PRE FILL AND SHELL TEST CHOKE MANIFOLD SHELL TEST WAS GOOD AND NO MORE LEAKS ON MANIFOLD Printed 11/14/2011 1:58:24PM North A�ica - ALASKA - BP • Page 13 of 25 Operation' Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:30 - 19:30 1.00 BOPSUR N WAIT PRE TOOLPUSHER NOTIFIED US HE HAD A GOOD SHELL TEST AND READY TO TEST - NOTIFIED STATE THAT WE ARE READY TO TEST BOP'S - 18:45 JOHN CRISP OF AOGCC CALLED BACK AND ASKED US TO WAIT FOR HIM TO BE ABLE TO START - HE SAID HE WAS ABOUT AN HOUR OUT. 19:30 - 00:00 4.50 BOPSUR P PRE TESTING 13 -5/8" BOPE TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -RAMS TESTED TO 250 PSI LOW AND 4,000 PSI HIGH. -HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 4" AND 5.5" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP AND JOHN CRISP OF AOGCC. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT -AK -10-45 10/7/2011 00:00 - 01:30 1.50 BOPSUR P PRE TESTING 13 -5/8" BOPE TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC REGS. -RAMS TESTED TO 250 PSI LOW AND 4,000 hO PSI HIGH. - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH It -TEST USING 4" AND 5.5" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP AND JOHN CRISP OF AOGCC. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT- AK -10 -45 KOOMEY DRAW DOWN TEST: - 2900 PSI DRAW DOWN TO 1900 PSI. - 200 PSI INCREASE IN 17 SECONDS. - FULL PRESSURE IN 75 SECONDS. - 5 N2 BOTTLES @ 2200 PSI. NO FAILURES 01:30 - 02:30 1.00 BOPSUR P PRE RD TEST EQUIPMENT, BLOW DOWN CHOKE AND KILL LINES, CLEAN RIG FLOOR 02:30 - 05:00 2.50 BOPSUR P DECOMP RU DUTCH RISER, CLEAN OFF TOP OF TWC, FILL BOP'S, RU LUBRICATOR TEST LUBRICATOR TO 250 PSI LOW AND 4,000 PSI HIGH - CHARTED PULL TWC & MONITOR FOR FLOW RD LUBRICATOR AND SEND OUT 05:00 - 05:30 0.50 BOPSUR P DECOMP RU TO PULL HANGER MU LANDING JOINT TO TOP OF TUBING SPOOL AND MU TO TOP DRIVE 05:30 - 06:00 0.50 BOPSUR P DECOMP PJSM/ BOLDS PU TUBING HANGER - TUBING HANGER BROKE FREE AT 175K,BUT PULLED 25 -35 K OVER , WHILE PICKING UP - OVERPULL FINALLY DROPPED OFF - TUBING HANGING WEIGHT = 145 K Printed 11/14/2011 1:58:24PM North Africa - ALASKA - BP . Page 14 of 25 Operation Summary Report „' Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 08:00 2.00 BOPSUR P DECOMP CLOSE BAG AND CBU THROUGH CHOKE AND GAS BUSTER OBTAINED SPR = 40 SPM @ 80 PSI AND 50 SPM @ 110 PSI CBU AT 7 BPM AND 220 PSI 08:00 - 09:00 1.00 BOPSUR P DECOMP PULL HANGER TO THE RIG FLOOR, BREAK, AND LAYDOWn MONITORED WELL FOR FLOW FOR 10 MIN. - NO FLOW 09:00 - 13:00 4.00 BOPSUR P DECOMP PJSM FOR PULLING TUBING - POOH WITH 5- 1/2 ",17# TC4STBG FROM 9,655' CUT JOINT TO 7,625' - PUW -162K , SOW -140K KICK WHILE TRIPPING DRILL WITH AAR: 13:00 - 13:30 0.50 BOPSUR P DECOMP DISCONNECT CONTROL LINE FROM TBG, - BREAK AND LD SLB SPOOLER 13:30 - 00:00 10.50 BOPSUR P DECOMP CONTINUE TO LAY DOWN 5- 1/2 ",17 #,TC4S TBG FROM 7,625' - LD 251 JTS, 1 SLIDING SLEEVE ASSEMBLY, AND 1 19.14' JET CUT JOINT - FLARE OF JET CUT WAS 6.30" OD AND SPLIT VERTICALLY - RECOVERED 4 SS BANDS AND 26 CLAMPS 10/8/2011 00:00 - 02:00 2.00 BOPSUR P DECOMP RIG DOW LINER RUNNING EQUIPMENT - RIG UP DRILL PIPE RUNNING EQUIPMENT - SET WEAR RING WITH 9 1/8" ID 02:00 - 05:30 3.50 BOPSUR P DECOMP PJSM FOR MU OF BHA, DISCUS WELL CONTROL CONTINGENCIES, AND NON SHEARABLE PLAN MONITORED WELL FOR FLOW FOR 10 MIN. - NO FLOW MAKE UP CLEAN OUT BHA WITH: - 8 1/2 X5 9/16 DRESS OFF SHOE - 8 1/8 TSWP EXTENSION - 8 1/8 TSWP EXTENSION - 8 1/8 TSWP EXTENSION -7 X 4 3/4 INNER MILL OAL 2.80 - 8 1/8 WASH OVER BOOT BASKET - DOUBLE PIN SUB4 1/2 REG X 4 1/2 IF - 7" BOOT JUNK SUB - 7" BOOT JUNK SUB - 9 5/8 CASING SCRAPER - BIT SUB 4 1/2 REG X 4 1/2 IF - STRING MAGNET - STRING MAGNET - XOVER 4 1/2 IF PIN X 3 V2 IF BOX- 4 3/4 BUMPER SUB - 43/4 JARS - 3 1/2 IF PUMP OUT SUB - XOVER 3 1/2 IF PIN X 4" HT38 BOX - 6 - 4 3/4 DRILL COLLARS 05:30 - 18:00 12.50 BOPSUR P DECOMP TIH ON 4" HT 38 DRILL PIPE - TIH WITH DRESS OFF BHA TO — 8992' 18:00 - 19:00 1.00 BOPSUR P DECOMP P/U STORM PACKER -TIH TO 9087' -P /U 5' SET PACK - 79' BELOW R OE 89' BELOW RKB) Printed 11/14/2011 1:58:24PM • North Africa - ALASKA - BP Page 15 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 20:00 1.00 BOPSUR P DECOMP PULL 1 STD AND STAND BACK CLOSE BLIND RAMS AND TEST RTTS 250 PSI FOR 5 MIN. 1000 PSI FOR 10 MIN CHARTED 20:00 - 20:30 0.50 BOPSUR P DECOMP SUCK OUT STACK AND BLOW DOWN LINES -P /U RUNNING TOOL - PULLWEAR RING. - L/D SAME. 20:30 - 23:00 2.50 BOPSUR P DECOMP NIPPLE DOWN BOP AND TUBING SPOOL WITH DOUBLE BARRIERS: COMPOSITE BRIDGE PLUG IN TAIL PIPE AND oK 9 -5/8" X 5 -1/2" PRODUCTION PACKER AND 9 -5/8" RTTS - OA OPEN TO SLOP TANK - BLEED OFF ALL PRESSURES - BACK OUT LDS - SPLIT STACK AND STAND BACK BOPS - SPLIT SPOOL 23:00 - 00:00 1.00 BOPSUR P DECOMP ATTEMPT TO BACK OUT SECURING BOLTS ON SLIP TOP RETAINING PLATE - ONE BOLT HEAD BROKE OFF - THREE BOLTS UNMOVABLE WHEN CASING WAS SET ORIGINALLY AND LDS WERE RUN IN, THE LOCK DOWN SCREWS DAMAGED THE TOP PLATE. THE TOP PLATE HAS RECESSED HOLES THAT THE RETAINING BOLT HEADS SIT DOWN IN. THE SIDES OF THESE HOLES GOT PUSHED IN AGAINST THE BOLT HEADS. WE BROKE THREE IMPACT SCREW DRIVER BITS TRYING TO TURN THESE BOLTS. ONE BOLT HEAD BROKE OFF. STOP THE JOB AND CONTACT TOWN AND DAY WSL. 10/9/2011 00:00 - 00:30 0.50 WHSUR P DECOMP NOTIFY DAY WSL OF PROBLEM, -CALL TOWN ENGINEER SEAN MCLAUGHLIN OF TROUBLE WITH RETAINING SCREWS - DISCUSS THE PROBLEM OF NOT BEING ABLE TO BACK OUT THE SLIP TOP PLATE RETAINING BOLTS - DISCUSS THE POTENTIAL PROBLEMS OF BREAKING OFF BOLTS - DISCUSS THE LOWER SEAL HAD A GOOD PREVIOUS PPPOT TEST AND ADVISE TO LEAVE IT IN PLACE, AND CHANGE THE UPPER SEAL ONLY, NU NEW TUBING SPOOL, AND TEST - DOE CALLED BACK AND ADVISED TO GO AHEAD AS PLANNED AND CHANGE ONLY THE TOP SEAL AND TEST. IF SEALS TEST GOOD AGAIN THEN GO AHEAD AND CONTINUE AS PLANNED. 100:30 - 02:00 1.50 WHSUR P DECOMP NU NEW 135/8" X 4 1/8" TUBING HEAD ADAPTER WITH NEW SECONDARY OA PACK -OFF 02:00 - 02:45 0.75 WHSUR P DECOMP TEST IC PACK OFF: -TEST 250 PSI LOW FOR 5 MIN -TEST 3,500 PSI HIGH FOR 30 MIN -GOOD TEST Printed 11/14/2011 1:58:24PM North nrioa - ALASKA - BP Page 16 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:45 - 04:30 1.75 WHSUR P DECOMP NU BOP TO NEW TUBING SPOOL NU SECONDARY IA VALVE SET TEST PLUG IN TUBING SPOOL 04:30 - 05:00 0.50 WHSUR P DECOMP FILL TREE AND PT TUBING SPOOL TO BOP BREAK 0'4 250 PSI LOW - 5 MIN 4 \4' 4,000 PSI HIGH - 5 MIN 05:00 - 06:30 1.50 WHSUR P DECOMP INSJoj I WEAR BUSHING INTO TUBING SPOOL WEAR BUSHING WITH 9 -1/8" ID MU RTTS RETRIEVAL TOOL - RIH ONE STAND TO THE TOP OF RTTS, RELEASE RTTS - FLOW CHECK WELL, VERIFY ZERO PRESSURE - POOH WITH RTTS LD SAME. 06:30 - 07:30 1.00 CLEAN P DECOMP PJSM FOR PICKING UP DP FROM PIPE SHED - RIH ON SINGLES FROM THE PIPE SHED FROM 9,087 TO 9600' - SCRAPE AND ROTATE FROM 9530' TO 9600 THREE TIMES. - RIH AND TAG 5 -1/2" STUMP AT 9654' DP MEASURMENT. 07:30 - 09:30 2.00 CLEAN P DECOMP TAKE SLOW PUMP RATES - MP #1 @ 30 SPM/130 PSI , 40 SPM / 190 PSI OBTAIN PARAMETERS: - PUW 190K , SOW 150K 09:30 - 10:30 1.00 CLEAN P DECOMP WASH OVER THE TOP OF THE 5 -1/2" STUMP 8654' - DRESS OFF THE TOP OF TUBING STUB AT 6 BPM WITH 520 PSI , PUMPING SWEEPS AS NEEDED - SWEEPS BROUGHT BACK MINIMAL AMOUNTS OF METAL - DRESSED OFF 1' OF THE STUMP LEAVING THE TOP OF THE STUMP AT 9,653' 10:30 - 12:00 1.50 CLEAN P DECOMP FLOW CHECK THE WELL, NO FLOW DETECTED - GREASE THE TOP DRIVE. -POH 12:00 - 13:00 1.00 CLEAN P DECOMP RIG SERVICE , - DERRICK INSPECTION 13:00 - 18:00 5.00 CLEAN P DECOMP POOH WITH DRESS OFF BHA ON 4" DP RACKING BACK IN DERRICK - POOH FROM 9,653' TO 7,300' - SCRAPE AND ROTATE PAST THE — 7350 AREA FOR PACKER SETTING DEPTHS THREE TIMES MOTOR MAN DOING A SPCC WALK AROUND FOUND A DIESEL DRIP OUTSIDE UNDER THE FRONT CANTILEVER. IT WAS DRIPPING FROM A DIESEL SUPPLY LINE CONNECTION. LOOKED TO BE ABOUT A CUP OF DIESEL. NON EMERGENCY SPILL WAS NOTIFIED. SRT CALLED OUT AND TOLD US TO GO AHEAD AND SHOVEL IT INTO AN OILY WASTE BAG AND THEY WOULD PICK IT UP. IR # 3963801 Printed 11/14/2011 1:58:24PM North Arica - ALASKA - BP , Page 17 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:00 - 20:30 2.50 CLEAN P DECOMP FLOW CHECK WELL AND PJSM FOR LD OF BHA - LD BHA #1 - CLEAN OFF MAGNATES AND JUNK BASKETS RECOVERING ABOUT 5 GAL OF DEBRIS AND 10 TO 15 POUNDS OF STEEL 20:30 - 21:30 1.00 DHB P DECOMP CLEAN AND CLEAR RIG FLOOR - BREAK DOWN CLEAN OUT BHA AND PALLETIZE WITH BANDING - SEND OUT MILLING TOOLS BRING IN RTTS 21:30 - 22:30 1.00 DHB P DECOMP PJSM FOR MU OF BHA PU AND MU 9 -58" RTTS AND SETTING TOOL 22:30 - 00:00 1.50 DHB P DECOMP TIH ON 4" DRILL PIPE -TRIP IN HOLE 35 STANDS NIGHT CREW HAD WEEKLY SAFETY MEETING PRIOR TO COMING ON TOWER 10/10/2011 00:00 - 04:00 4.00 DHB P DECOMP CREW CHANGE, PJSM FORTIH, SERVICE RIG FLOOR EQUIPMENT - CONTINUE TO RIH WITH RTTS - RIH TO 9622.5 FT COE ON RTTS 04:00 - 04:30 0.50 DHB P DECOMP PJSM ON SET OF PACKER AND CASING TEST PROCEDURES -SET RTTS AT 9622.5 FT COE 04:30 - 05:45 1.25 DHB P DECOMP PRESSURE TEST 9 -5/8" CASING AGAINST SET RTTS AT 9622.5 FT AND VARIABLE PIPE RAMS CHART CASSING TEST ON ROLL CHART G - 400 PSI LOW FOR 5 MIN - 4200 PSI HIGH FOR 30 MIN 4220 PSI AT 04:47 MIN 4190 PSI AT 05:02 MIN - -- 30 PSI LOST 4180 PSI AT 05:17 MIN - - -10 PSI LOST - GOOD TEST CALL WELLS TEAM LEAD JIM WILLINGHAM AND VERBALLY REPORT TEST RESULTS BY PHONE. REVIEWED RESULTS AND GOT GO AHEAD TO CONTINUE WITH OPPS AND POH. 05:45 - 15:30 9.75 DHB P DECOMP PJSM AND POH STANDING BACK DRILL PIPE - POOH FROM 9,622' WITH HES STORM PACKER ON 4" HT38 DP - TOH TO THE BHA, FLOW CHECK THE WELL BEFORE PULLING THE BHA THRU THE BOP - NO FLOW 15:30 - 16:00 0.50 DHB P DECOMP BREAK OUT THE HES 9 -5/8" STORM PACKE}Z - LAYDOWN TO THE PIPE SHED 16:00 - 17:00 1.00 EVAL P DECOMP PU /MU THE DUTCH RISER, WITH 7" OTIS CONNECTION. - INSTALL WEAR RING 17:00 - 18:30 1.50 EVAL P DECOMP PULL AND LID DUTCH RISER -PULL TEST PLUG -RESET WEAR RING 18:30 - 21:30 3.00 EVAL P DECOMP PJSM WITH SCHLUMBERGER AND CREW -RU WIRE LINE UNIT 21:30 - 00:00 2.50 EVAL P DECOMP RIH WITH USIT LOG TO 9,650 FT -RIG CREW WORKING ON FIXING BILL HOPKINS AUDIT ITEMS Printed 11/14/2011 1:58:24PM North Arioa - ALASKA - BP Page 18 of 25 Operati Summary, Repar t . Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/11/2011 00:00 - 03:30 3.50 EVAL P DECOMP E -LINE CONVEYED USIT LOG FROM 9,650 FT TO SURFACE - RIG CREW MAKING GOOD USE OF TIME TO REPAIR BILL HOPKINS AUDIT ITEMS 03:30 - 06:00 2.50 EVAL P DECOMP TAG UP AND LAY DOWN USIT LOG BHA - RE -HEAD FOR PERF TOOLS - RU DUTCH RISER TO BOP - FINALIZE USIT LOG FOR TOWN AND STATE 06:00 - 10:00 4.00 EVAL P DECOMP PU / MU SLB FULL PRESSURE CONTROL - RU FULL PCE ON TOP OF THE DUTCH RISER, WITH 7" OTIS CROSS OVER ON TOP. 10:00 - 14:00 4.00 EVAL N WAIT DECOMP WAITING ON STATE REVIEW OF THE USIT LOG TO APPROVE THE PERF DEPTHS - ATTEMPT TO PRESSURE TEST PRESSURE CONTROL EQUIPMENT TO 250/3,500 PSI - UNABLE TO GET A GOOD TEST. GOT EMAIL FROM TOWN ENGINEER AT 12:00 WITH OK TO PERF PER PLAN 14:00 - 18:30 4.50 PRFADD N WSEQ DECOMP UNABLE TO GET GOOD TEST AND CONCLUDE THAT TEST PLUG IS LEAKING - STAND BACK SLB EQUIPMENT - PULL TEST PLUG CLEAN AND RESET - PRESSURE TEST PLUG TO 250 PSI LOW, 4,000 PSI HIGH AGAINST BLIND RAMS - RESET DUTCH RISER AND SLB BOP - PRESSURE TEST TO 250 PSI LOW AND 3,500 PSI HIGH 18:30 - 20:00 1.50 PRFADD P DECOMP PJSM/ TEST FIRE WIRE LINE HEAD -PU GUN #1 AND ARM - PRESSURE TEST AT SLB QUICK TEST SUB TO 3,500 PSI 20:00 - 22:30 2.50 PRFADD P DECOMP RIH WITH GUN RUN #1 - 20 FT - LOG AND GET ON DEPTH TO PUT SHOTS FROM 7,643 FT TO 7,663 FT - PLACE SHOTS ON DEPTH - REVIEW WELL CONTROL CONTINGENCIES WITH CREW - CLOSE KILL LINE AND PUMP IN SUB TO ISOLATE WELL - SHOOT GUNS, WELL ON VERY SMALL VAC -POH WITH WELL STATIC -LD GUNS - AL SHOTS FIRED 22:30 - 00:00 1.50 PRFADD P DECOMP RIH WITH GUN # 2 - 8 FT OF SHOTS - LOG AND GET ON DEPTH TO PUT SHOTS FROM 7,635 FT TO 7,643 FT - PLACE SHOTS ON DEPTH 10/12/2011 - PRFADD P DECOMP RIH WITH MILL OUT BHA -30 STANDS IN AND HELD D-1 DRILL, 1.5 MINUTES. 00:00 - 01:30 1.50 PRFADD P DECOMP PJSM WITH NEW CREW, REVIEW WELL CONTROL CONTINGENCIES - WITH GUNS ON DEPTH FIRE GUN #2 - CLOSE KILL LINE AND PUMP IN SUB TO ISOLATE WELL - MONITOR WELL WITH VERY SLIGHT VAC - POOH CIRCULATING ACROSS TOP -LD GUN #2 - ALL SHOTS FIRED Printed 11/14/2011 1:58:24PM North rica - ALASKA - BP Page 19 Of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 01:30 - 04:00 2.50 PRFADD P DECOMP RIH WITH GUN RUN #3 - 20 FT OF GUNS - LOG AND GET ON DEPTH TO PUT SHOTS FROM 7,590 FT TO 7,610 FT - PLACE SHOTS ON DEPTH - CLOSE KILL LINE AND PUMP IN SUB TO ISOLATE WELL o - SHOOT GUNS, WELL ON VERY SMALL VAC .,n - POH WITH WELL STATIC - LD GUNS - ALL SHOTS FIRED 04:00 - 06:30 2.50 PRFADD P DECOMP RIH WITH GUN RUN #4 - 20 FT OF GUNS - LOG AND GET ON DEPTH TO PUT SHOTS FROM 7.570 FT TO 7,590 FT - PLACE SHOTS ON DEPTH - CLOSE KILL LINE AND PUMP IN SUB TO ISOLATE WELL - SHOOT GUNS, WELL ON VERY SMALL VAC 06:30 - 07:00 0.50 PRFADD P DECOMP - POH WITH WELL STATIC - LD GUNS - ALL SHOTS FIRED 07:00 - 09:00 2.00 PRFADD P DECOMP PJSM WITH SWS -RD WIRE LINE BOPS AND LUBRICATOR ASSEMBLY. 09:00 - 09:30 0.50 PRFADD P DECOMP CLEAN AND CLEAR RIG FLOOR. 09:30 - 10:30 1.00 CLEAN P DECOMP BRING BHA EQUIPMENT TO RIG FLOOR. 10:30 - 16:00 5.50 CLEAN P DECOMP PJSM WITH BAKER FISHINGMAN -MU MILL -OUT BHA WITH CREW CHANGE AT 12:00 -BHA= 16:00 - 19:45 3.75 CLEAN P DECOMP TIH WITH 4" DRILL PIPE FROM DERRICK TO STAND # 77 19:45 - 21:00 1.25 CLEAN P DECOMP OBTAIN SLOW PUMP RATES: 30 SPM = 190 PSI 40 SPM = 380 PSI SCRAPE CASING WITH CASING SCRAPPER WITH STANDS 78 & 79 TO WORK SCRAPER ACROSS PERFORATIONS AT 7570 FT TO 7663 FT - WORK STANDS UP AND DOWN WHILE - ROTATING AT 40 RPM - 5.7 BPM AT 870 PSI - WENT TO BREAK OFF AND PU STAND # 80 - NO FLOW BUT RETURNS ARE DIRTY AND "FIZZY" - MONITOR WELL AND NO FLOW - ELECTED TO SHUT ANNULAR AND CBU 21:00 - 22:55 1.92 CLEAN P DECOMP WITH ANNULAR CLOSED AND CIRCULATING THROUGH CHOKE LINE AND GAS BUSTER - BEGIN TO CBU AT 5 BPM @ 960 PSI DPP -- AT 1734 STKS OF 5,500 PLANED - NOTED HIGHER DPP PRESSURE OF 1030 AND TOTCO SHOWING A 2 BBL GAIN � - SHUT DOWN PUMPS AND CLOSED CHOKE YY - PRESSURES SLOWLY CLIMBING ABOUT 10 e PSI PER 2 TO 3 MIN - NOTIFIED DAY WSL AND DISCUS PLAN TO CBU - NOTIFIED RWO SUPERINTENDENT OF SITUATION AND PLAN FORWARD - HUT IN PRFSSURFR ('.AM 20 MIN PRIOR TO SECOND CBU Printed 11/14/2011 1:58:24PM North Attica .ALASKA - BP _ • Page 20 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:55 - 00:00 1.08 CLEAN P DECOMP ZERO STROKE COUNTER AND CONTINUE TO CBU THROUGH CHOKE WITH 60 TO 80 PSI OF BACK PRESSURE. - WORK CHOKE TILL FOUND BALANCE BETWEEN LOSSES VS GAIN ON TOTCO - 43 SPM @ 430 PSI APROX 60 TO 80 PSI WITH VERY SMALL LOSSES -CBU OF 5500 STKS (BIT DEPTH OF 7925 FT) 457 BBLS FOR BU - CONTINUE TO CBU WHILE DRILLERS CHANGE OUT 10/13/2011 00:00 - 01:30 1.50 CLEAN P DECOMP FINISH CBU AND SHUT DOWN PUMPS - MONITOR FOR PRESSURES AGAINST CLOSED CHOKE - NO PRESSURE BUILDING IN 15 MIN - OPEN ANNULAR - NO FLOW, SMALL AMOUNT OF BUBBLES AND FLUID LEVEL IS BELOW BAG - FILL STACK TO MONITOR WELL BETTER - NO FLOW NO BUBBLES -BLOW DOWN CHOKE LINES PJSM WITH NEW CREW ON TIH FOR ANOTHER 20 STANDS - BLOW DOWN TOP DRIVE 01:30 - 03:00 1.50 CLEAN P DECOMP CONTINUE TO TRIP IN HOLE AT STAND 98 GET PARAMETERS ABOVE TUBING TAIL UP WT =186 K DN WT = 158 K 170 K WITH 10 RPM W/ 4 K TQ 16 SPM = 60 PSI AND LOSSES START STOP ROTATING BUT KEEP PUMPING AT ABOUT 1.2 BPM / 16 SPM -SET DOWN AND FIND SHEAR PINS AT 9661 FT FOR TOP OF TUBING STILL AT 9655 FT -SHEAR OUT WITH 10 K DOWN - 15 SPM = 60 PSI IN 4 -1/2 TUBING 03:00 - 04:00 1.00 CLEAN P DECOMP PU STAND # 99 AND MU - TURN PUMPS BACK ON AND PLUGGING OFF AT 6 BPM PRESSURED UP TO 1080 PSI - PRESSURE UP AND BLEED OFF A FEW TIMES - NO LUCK - STAND BACK # 99 AND KELLY UP - STILL PLUGGING OFF - PRESSURE UP AND DUMP PRESSURE SEVERAL TIMES - WORK PIPE WITH PRESSURE AND WITHOUT - PLUG CAME FREE AND RETURNED TO NORMAL CIRCULATING PRESSURES -60 SPM @ 780 PSI CONTINUE TO PUMP AND ROTATE AT 60 RPM TO HELP CLEAN OUT TUBING Printed 11/14/2011 1:58:24PM • North illtioa - ALASKA - BP Page 21 of 25 Operation Summary Report . Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 CLEAN P DECOMP MU STAND # 99 AGAIN AND TAG UP IN X NIP AND /OR TOP OF PLUG AT 9,738 DRILLERS DEPTH - TRY TO SLIDE BY WITH NO ROTATION AND UNABLE WITH 7 K WOB -PU ROTATE AGAIN AT 60 RPM - GOT NEW SPR'S OR : -30 SPM = 250 PSI -40 SPM= 410 PSI -60 SPM = 820 PSI MILL THROUGH WITH 5 TO 7 K WOB AT 60 RPM AND TRQ= 6.5 K AND CLEAN PUSHING THROUGH AT 9740 FT CHASE PLUG OUT OF TUBING TAIL 05:00 - 05:30 0.50 CLEAN P DECOMP CLOSE ANNULAR AND BULL HEAD AWAY 75 BBLS AFTER PUMP IS UP TO RATE -PUMP DOWN DP ONLY AT 100 SPM AND 3100 PSI DPP - SHUT DOWN PUMPS AND MONITOR WELL 05:30 - 10:30 5.00 CLEAN P DECOMP MONITOR WELL AND ALLOW PRESSURE TO / REI AX -SIDPP = 240 PSI SICP = 470 PSI - AFTER 30 MINUTES SIDPP =0 SICP = 160 - BLEED OFF 1 BBL AT A TIME TO SIDPP = 0 PSI AND SICP = 10 PSI (2 BBLS TOTAL) - CBU @ 5 BPM / 870 PSI THROUGH THE GAS BUSTER AND LOST 23 BBLS. - MONITOR WELL. WELL STATIC - KWF = 8.5 PPG SEAWATER. ***TALK TO AOGCC STATE INSPECTOR CHUCK SCHEVE, AND NOTIFIED HIM OF BOPE USED, AND NOTICE OF WEEKLY BOPE TEST PLANED FOR THIS TRIP OF POH LID DP. CHUCK SCHEVE WAIVED STATES RIGHT OF WITNESS. 10:00 HRS 10/13/2011. * ** 10:30 - 11:00 0.50 CLEAN P DECOMP RIH AND NO-GO AT 9848' MD -2 BPM/ 130 PSI 11:00 - 11:30 0.50 CLEAN P DECOMP PULL 3 STANDS TO CLEAR THE 5 1/2" TBG STUMP F/9848' T/9637' MD. - OBSERVED 15 -K OVER PULL WHEN THE SHEAR GUIDE CAME OFF THE 5 1/2" TBG STUMP. - PULL 3 STANDS TO CLEAR THE 5 1/2" TBG STUMP 11:30 - 12:00 0.50 CLEAN P DECOMP MONITOR WELL, STATIC. - BLOW DOWN CHOKE AND GAS BUSTER. - WTLAND RWO SUPERINTENDENT, BPADW HSSE ADVISER, DOYON RIG DRILLING AND FIELD SUPERINTENDENTS. MADE RIG VISIT. 12:00 - 13:00 1.00 CLEAN P DECOMP SERVICE TOP DRIVE 13:00 - 00:00 11.00 CLEAN P DECOMP POH UD 4" DP TO PIPE SHED 1X1. - 2 BPH LOSS RATE. - LAY DOWN 255 JOINTS OF 303 DAILY LOSSES OF 178 BBLS Printed 11/14/2011 1:58:24PM North rica - ALASKA - BP Page 22 of 25 Operation Summary Report .. Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10/14/2011 00:00 - 01:00 1.00 CLEAN P DECOMP CREW CHANGE /PJSM - FINISH LAY DOWN OF DRILL PIPE FROM JOINT 255 TO JOINT 303 -LOST 47 BBLS ON TRIP OUT OF HOLE FOR AVERAGE LOSS RATE OF 5 BPH - FLOW CHECK /MONITOR WELL -PJSM FOR LD OF BHA 01:00 - 04:00 3.00 CLEAN P DECOMP LAY DOWN CLEAN OUT BHA - RECOVERED ABOUT 1.5 TO 2 GAL OF FILL AND METAL SHAVINGS - MAGNETS WERE COVERED IN METAL SHAVINGS - MILL HAD SOME SMALL GOUGES ON THE SIDE BUT IN GOOD CONDITION OTHERWISE 04:00 - 05:00 1.00 CLEAN P DECOMP RD ALL BAKER TOOLS AND SEND OUT -CLEAR RIG FLOOR 05:00 - 06:00 1.00 CLEAN P DECOMP RU TO TEST BOPS 06:00 - 12:00 6.00 CLEAN P DECOMP TESTING 13 -5/8" BOPE TEST BOPE PER WELL PLAN, PERMIT TO DRILL, AND AOGCC V REGS. - RAMS TESTED TO 250 PSI LOW AND 4,000 PSI HIGH. - HYDRILL TESTED TO 250 PSI LOW AND 3,500 PSI HIGH -TEST USING 4" AND 5.5" TEST JOINTS. - PRESSURE TEST FOR 5 CHARTED MIN. -ALL TEST WITNESSED BY BP WSL / DDI TP. -ALL TEST FOLLOW TESTING CRITERIA DOCUMENTED IN CRT - AK -10 -45 -AOGCC STATE INSPECTOR CHUCK SCHEVE WAIVED STATES RIGHT OF WITNESS. KOOMEY DRAW DOWN TEST: - 2050 PSI DRAW DOWN TO 1850 PSI. - 200 PSI INCREASE IN 16 SECONDS. - FULL PRESSURE IN 77 SECONDS. - 5 N2 BOTTLES @ 2100 PSI. - ANNULAR =21 SECONDS. -BLIND RAMS = 13 SECONDS. - PIPE RAMS = 6 SECONDS. NO FAILURES 12:00 - 12:30 0.50 CLEAN P DECOMP RD TEST EQUIPMENT. 12:30 - 15:00 2.50 RUNCOM P RUNCMP R/U TO RUN 4.5" TBG COMPLETION. 15:00 - 15:30 0.50 RUNCOM P RUNCMP HELD PJSM WITH HALLIBURTON REP'S, TOOLPUSHER, WSL, CREW AND DOYON CSG CREW. Printed 11/14/2011 1:58:24PM North rica - ALASKA - BP Page 23 of 25 • Operation Summary Report. Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:30 - 00:00 8.50 RUNCOM P RUNCMP AT 17:45 AOGCC INSPECTOR HERRERA WAIVED STATE WITNES OF IA TEST RUN 4 -1/2" 12.6# L -80 TC-II TUBING WITH 2 PACKERS AND SLIDING SLEEVE COMPLE1 ION - MU USING DOYON CASING TORQUE TURN SERVICES TO OPTIMUM TORQUE OF 3,850 FT /LB - USE JET LUBE SEAL GUARD THREAD COMPOUND ON ALL CONNECTIONS - BAKER LOCK ALL CONNECTIONS BELOW THE PACKER - RUN TO JOINT #140 OF 225 JTS LOSSES TO THE WELL = 74 BBLS 10/15/2011 00:00 - 06:00 6.00 RUNCOM P RUNCMP CONTINUE TO RUN 4 1/2 COMPLETION FROM JOINT 140 TO JOINT 225 - PU JOINT 226 TO SPACE OUT 06:00 - 09:00 3.00 RUNCOM P RUNCMP M/U TIW VALVE ON JT#226 -HAD TO WORK AND CIRCULATE OVER 5 1/2" TBG STUMP. -1 BPM/ 100 PSI, 3 BPM/ 110 PSI, 4 BPM/ 170 PSI. - OBSERVED FIRST SHEAR @ 9661' MD WITH 20 K. - OBSERVED SECOND SHEAR @ 9669' MD WITH 18 K. - OBSERVED NO-GO @ 9671' MD -UD JT #225 AND #226 - M /U SPACE OUT PUPS 2.04' AND 9.80' - M /U JT# 225 09:00 - 10:00 1.00 RUNCOM P RUNCMP CAMERON WELL HEAD REP M/U TBG HANGER AND LANDING JT. - LAND TBG HANGER (9665' MD) -RILDS 10:00 - 11:00 1.00 RUNCOM N WAIT RUNCMP DISCUSS PLAN FORWARD WITH JERRY BIXBY -THE WIND SPEED MAY DELAY THE WELLS GROUP WIRE LINE OPERATION TO FREEZE PROTECT THE TBG AFTER THE RIG MOVES OFF. -SEND 550 BBLS INHIBITED SEAWATER TO MI MUD PLANT TO WEIGHT UP TO 9.8 PPG BRINE -WHICH WILL BE USED AS TEMPOARY FREEZE PROTECT -UD CASING CREW EQUIPMENT -CLEAN AND CLEAR RIG FLOOR. 11:00 - 17:30 6.50 RUNCOM N WAIT RUNCMP WAIT ON 9.8 PPG BRINE FROM MI MUD PLANT. - CIRCULATE DOWN IA 2 BPM/ 1500 PSI WITH 12 BPH LOSS RATE. - CIRCULATE DOWN TBG 2 BPM / 170 PSI -CREW WORKING ON HARD LINE INVENTORY. PJSM FOR DISPLACEMENT Printed 11/14/2011 1:58:24PM • North rica - ALASKA =BP Page 24 of 25 Qperation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TOR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 17:30 - 22:30 5.00 RUNCOM P RUNCMP - CIRCULATE 232 BBLS 9.8 PPG CORROSION INHIBITED BRINE DOWN THE TUBING - 2 BPM. / 220 PSI - PUMPED IN 232 BBLS AND GOT 200 BBLS BACK - SD PUMPING DOWN TUBING OR WE WONT GET INHIBITED BRINE ALL THE WAY AROUND - BULLHEAD 348 BBLS. DOWN THE IA - STAGE UP PUMPS TO 4 BPM AT 2,000 PSI IA AND 550 PSI TUBING PRESSURE 22:30 - 00:00 1.50 RUNCOM P RUNCMP PJSM/ RIG UP LITTLE RED TO PUMP DIESEL - RU LITTLE RED TO MUD MANIFOLD ON RIG FLOOR SO WE WONT HAVE TO RE -RIG AND RE -TEST 10/16/2011 00:00 - 01:30 1.50 RUNCOM P RUNCMP CONTINUE TO RU LRHOS -PT LINES TO 250 PSI / 4,000 PSI - ISOLATE LRHOS AND PT THEIR LINES TO 250 PSI LOW / 4,800 PSI HIGH FOR 5 MIN 01:30 - 03:30 2.00 RUNCOM P RUNCMP BULL HEAD IN 170 BBLS OF DIESEL INTO IA - 40 BBLS HEATED TO 85 DEG THEN 130 BBLS AT AMBIENT TEMP - 2.5 BPM AT 2150 PSI IA AND 600 PSI TUBING PRESSURE - SHUT IN IA AND BULL HEAD IN 10 BBLS INTO TUBING AT 300 PSI - SHUT DOWN AND ALLOW 300 PSI TO BLEED OF TO FORMATION - OPEN TO PITS AND NO FLOW - OPEN LANDING JOINT AND DROP BALL AND ROD 03:30 - 04:00 0.50 RUNCOM P RUNCMP SET PACKER WITH LRHOS - PRESSURE UP TUBING TO 250 PSI AND CHART FOR 5 MIN - PRESSURE UP TO 1,800 PSI AND MAY HAVE SEEN PACKER SET - PRESSURE SENSATOR FAILED CONTINUED TO PRESSURE UP TO 3,500 PSI USING MECHANICAL -GAUGE ON MUD MANIFOLD. - BLEED OFF PRESSURE AND CHANGE SENSATOR 04:00 - 05:30 1.50 RUNCOM P RUNCMP PRESSURE TEST TUBING AND IA TUBING TEST AGAINST BALL ON SEAT - 03:56 4150 PSI - 04:11 4120 PSI ( -30 PSI) - 04:26 4175 PSI (+ 55 PSI) THERMAL EXPANSION IA TEST - 05:03 4075 PSI - 05:18 3960 PSI - 05:33 3950 PSI GOOD TEST - CALL WELLS TEAM LEAD AND DISCUSS TEST RESULTS 05:30 - 06:00 0.50 RUNCOM P RUNCMP RIG DOWN LRHOS Printed 11/14/2011 1:58:24PM North likrica - ALASKA - BP Page 25 of 25 Operation Summary Report Common Well Name: S -09 AFE No Event Type: WORKOVER (WO) Start Date: 9/19/2011 End Date: 10/16/2011 X4- 00TQR -E (2,750,000.00 ) Project: Prudhoe Bay Site: PB S Pad Rig Name /No.: DOYON 16 Spud Date/Time: Rig Release: Rig Contractor: DOYON DRILLING INC. UWI: Active Datum: S -09 @66.98ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 06:00 - 08:00 2.00 WHSUR P RUNCMP PULL LANDING JT, INSTALL TWC VALVE, RE- INSTALL LANDING JT, TEST TWC WITH DIESEL, 250 PSI LOW, 4000 PSI HIGH, 10 MINUTES CHARTED EACH = GOOD TEST, PULL LANDING JT, THREADS ON LANDING JT WERE GALLED 08:00 - 10:00 2.00 BOPSUR P RUNCMP CHANGE RAMS TO 2 7/8 X 5" VARIABLE, NIPPLE DOWN BOP, RIG DOWN CIRCULATING MANIFOLD, AND DUAL ANNULUS VALVE. 10:00 - 12:00 2.00 WHSUR P RUNCMP INSPECT HANGER THREADS, TOP 4 THREADS GALLED. -MAKE UP ADAPTER FLANGE AND TEST 250 PSI LOW 5 MINUTES, 5000 PSI HIGH 30 MINUTES, CHARTED 12:00 - 13:30 1.50 WHSUR P RUNCMP PJSM -M /U 13 5/8" X 4 1/8" 5M - REPLACE O.A. INSTRUMENT FLANGE. 13:30 - 14:00 0.50 WHSUR P RUNCMP RU TO PRESSURE TEST TREE 14:00 - 15:00 1.00 WHSUR P RUNCMP PT TREE TO 250 PSI LOW / 5000 PSI HIGH FOR 5 CHARTED MIN 15:00 - 16:30 1.50 WHSUR P RUNCMP RU LUBRICATOR - PT TO 250 LOW 4000 PSI HIGH FOR 5 CHARTED MIN 16:30 - 17:00 0.50 WHSUR P RUNCMP PULL TWC - 320 PSI ON TUBING -110 PSI ON IA 17:00 - 17:30 0.50 WHSUR P RUNCMP RU LUBRICATOR - PT TO 250 LOW 4000 PSI HIGH FOR 5 CHARTED MIN 17:30 - 18:00 0.50 WHSUR P RUNCMP T BPV RD LUBRICATOR -CURE TREE RIG RELEASED FROM S-09i @ 18:00 HRS SEE S -102 FOR FURTHER UPDATES Printed 11/14/2011 1:58:24PM TREE = CM/ • WELLHEA■D = McEVOY SAFETY NOTES: WELL.UIRES A SSSV WHEN ON A'€TUATOR= BAKERC S -09 MI. KB. ELEV = 66.98' BF. ELEV = 38.50' KOP = 3200' I I I 2089' (- 14 -1/2" HES X NIP, ID = 3.813" Max Angle = 40° @ 5500' Datum MD = 10098' Datum TV D = 8800' SS - 2614' 1-19-5/8" DV PKR I 13 -3/8" CSG, 72 #, L -80 BUTT, ID = 12.347" H 2678' I 7240' - I-14-1/2" HES X NIP, ID = 3.813" -, 0 7312' H9 -5/8" X 4 -1/2" HES TNT PKR, ID = 3.903" I Minimum ID = 3.725" @ 10258' I I , 7473' I-14-1/2" HES XD SLD SLV , ID = 3.813" 4 -1/2" OTIS XN NIPPLE ti-' K��aetf �G P fs 7790' H 9 -5/8" DV PKR I M 9499' H9-5/8" X 4-1/2" HES TNT PKR, ID = 3.903" I ■ 9577' H 4 -1/2" HES X NIP, ID = 3.813" I 14 -1/2" TBG, 12.6 #, L -80 TCII, .0152 bpf, ID = 3.958" I-I 9649' I 9665' I- I9 -5/8" X 4 -1/2" UNIQUE OVERSHOT I 5 -1/2" TBG STUB (10/09/11) H 9653' 9700' I-I PBR TBG SEAL ASSY I 5 -1/2" TBG, 17 #, L -80 TC4S, .0232 bpf, ID = 4.892" H 9702' ;_� 9702' - -5/8" X 5 -1/2" TIW HPBP PKR ASSY, ID = 4.00" I I 9706' H 6" MILLOUT EXTENSION, ID = 4.50" I TOP OF 4 -1/2" TBG I 9711' 9711' 1-16" x 4 -1/2" XO, ID = 3.958" I 9741' H4 -1/2" PARKERX NIP, ID = 3.813" I 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" II 9806' I 8773' H4-1/2" PARKER X NIP, ID = 3.813" I PERFORATION SUMMARY II 9806' H4 -1/2" WLEG, ID = 3.958" I REF LOG: BHCS On 07/18/82 ??/??/?? ANGLE AT TOP PERF: 39° @ 7570' I 9788' I�ELMD TTLOGON Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 17 14 7570 - 7610 2 0 10/11/11 I ' 7 14 7635 - 7663 0 10/11/11 3 -3/8" 6 9931 - 9976 0 02/18/89 10175' H9-5/8" MARKER JOINT I 2 -7/8" 4 10066 - 10137 0 01/19/84 2 -7/8" 1 10138 - 10250 0 07/04/84 I 3 -1/8" 1 10264 - 10289 0 10/12/85 I I 10250' H9 -5/8" X 4 -1/2" OTIS WD PKR, ID = 4.00" I I TOP OF 4-1/2" TBG 1-1 ' 10254' --I4 -1 /2" OTIS X NIP, ID = 3.813" I I 10258' H4 -1/2" OTIS XN NIP, ID = 3.725" I 4-1/2" TBG, 12.6 #, L -80, 0.0152 bpf, ID = 3.958" I-I 10261' I--../ ■ I 10261' H4-1/2" OTIS TBG TAIL, ID = 3.980" I PBTD H 10439' I H ELMD TT NOT LOGGED I •.,+,.,.,.,s.,.,.. 19 -5/8" CSG, 47 #, L -80 BUTT, .0733 bpf, ID = 8.681" H 10480' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/25/82 N22E ORIGINAL COMPLETION 1 09/20/11 TTW/ PJC SET CBP / JET CUT (9/14- 15/11) WELL: S -09 ' 08/14/88 NIES RWO 11/11/11 SM/JMD DRLG DRAFT CORRECTIONS PERMIT No: 1821040 10/21/11 D -16 RWO API No: 50- 029 - 20771 -00 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE SEC 35, T12N, T12E, 1642' FNL & 1634' FWL 06/26/11 TH/ PJC DRAWING CORRECTIONS BP Exploration (Alaska) FW: Doyon 16 BOP Usage Report for S-011110-12-2011- Enterprise Vault ArchivedIt... Page 1 of 1 From Regg, James B (DOA) Date Thursday, October 13, 2011 11:14:45 AM To Brooks, Phoebe L (DOA); Schwartz, Guy L (DOA) Cc Subject FW: Doyon 16 BOP Usage Report for S -09i on 10 -12 -2011 VJBOPE usage S- 09I.10- 12- 2011.docm (16 KB HTML ) Jim Regg 1 AOGCC 333 W.7th Avenue, Suite 100 Anchorage, AK 99501 907 - 793 -1236 From: Sarber, Greg J [mailto:SarberJG @BP.com] Sent: Thursday, October 13, 2011 9:56 AM To: DOA AOGCC Prudhoe Bay Cc: Daniel, Ryan; Willingham, James M; Kilfoyle, Jeffery A; Reem, David C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft) Subject: Doyon 16 BOP Usage Report for S -09i on 10 -12 -2011 All, Doyon 16 is currently conducting a tubing swap workover on well S -09i. At approximately 21:00 hrs last night there was a minor influx of gas /crude circulated out of the well. The BOP usage report for that event is attached to this email. The plan forward is to come out of the hole and test BOP's prior to running the completion. Please contact me if there are any additional questions or information needed. Sincerely, Greg Greg Sarber Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) +1 (907) 242 -8000 (Cell Phone) Harmony 2157 Alternate: Jim Willingham https ://ancev02. soa. alaska. gov/EnterpriseVault/ViewMessage .asp ?VaultId= 17A3EF6017F... 12/2/2011 • • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of y BOPE use to ry p e ent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: David Johnston Contact Number: 659 -5329 Contact Number: 659 -4177 Traction Number: Well Location & Name: GPB S- ' Permit To Drill (PTD) Number 182 -104 Date and Time of Incident: 10/12/2011 21:00 Original Scope of Work: Run 9 -5/8" scraper with composite bridge plug mill out assembly. Dress off new perfs in 9 -5/8" casing in Kuparuk formation, then trip in hole and mill out 4 -1/2" composite bridge plug in tubing tail. Operational Description Leading up to Well Control Event: After dressing off perfs at 7570 ft to 7663 ft, shut down pumps to make up another stand and start to trip in hole to mill out plug. Noted the returns were getting dirty and saw bubbling in well head with no flow. Monitored well and it did not flow, and there was no pit gain at this time. Elected to close bag and circulate a bottoms up as a precaution. During the circulation we took a 2 bbl gain, shut down and closed choke to monitor pressure. Pressure built to 90 psi BOPE Used and Reason: Annular Preventer was shut -in to circulate a bottoms up through the choke as a precaution. After the gain was taken the annular was used to circulate out the well to get all remaining influx out. Held a little back pressure with the choke during circulation (60 to 80 psi). After circulation well was static with no flow and no bubbles. Is a BOPE Test Required after use ( Yes / No): If no, why Yes, Plan to test first trip out of hole Plan Forward: Continue to trip in hole and mill out composite bridge plug, then POH to test BOP's. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa. aogcc.prudhoe.bay(cr�alaska.gov Email CC List Well Integrity Team Leader Ryan Daniel HSE Advisor Jeff Kilfoyle Engineering Team Leader Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager Steve Rossberg Wells Intervention Manager Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC August 2, 2010 HRE 1 . 1.1.2.- lo4 24 -OCT -2011 2ttc) t Schrerger LIAR 2 7 2013 No. 5802 Alaska Data & Consulting Services , 1# Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Depeription ... Date BL Color CD Z -21A BG4H -00097 PPROF W /DEFT & GHOST 9- Oct -11 1 1 13 -15 BINC -00066 PRIMARY DEPTH CONTROL LOG 21- Sep -11 1 1 13 -25 BJGT -00070 PRIMARY DEPTH CONTROL LOG 26- Sep -11 1 1 R -12A AWJI -00158 USIT 16- Aug -11 1 1 Z-65 BX69 -00003 ISOLATION SCANNER 5- Oct -11 1 1 • A -25B AV1 P -00098 USIT 6- Aug -11 1 1 18 -12C AWJI -00162 MDT _ 13- Sep -11 1 1 S -09 BVYC -00011 USIT 11- Oct -11 1 1 R -12A BBSK -00098 PRIMARY DEPTH CONTROL LOG 28- Sep -11 _ 1 - 1 Y -36 BVYC -00007 PPROF 2- Oct -11 1 1 06 -21B BD88 -00173 MEMORY DEPTH DETERMINATION 28- Sep -11 1 1 06 -21 B BD88 -00173 PPROF W /DEFT & GHOST 29- Sep -11 1 1 W -10A BCRC -00132 PPROF 11-Sep-11 1 1 N -04A BVYC -00009 CROSSFLOW CHECK 5- Oct -11 1 1 A -25B BG4H -00096 SCMT 7- Oct -11 1 1 17 -04B BR12 -00019 LEAK DETECT LOG 3- Oct -11 1 1 W -16A BCRC -00133 PPROF _ 12-Sep-11 1 1 Z -21A BR12 -00020 MEMORY STP SURVEY 5- Oct -11 1 1 Z -29 BD88 -00168 PPROF W /DEFT & GHOST 22-Sep-11 1 _ 1 3- 45/M -39 BD88 -00175 IPROF 3- Oct -11 1 1 R -12A BBSK -00098 SCMT 29-Sep-11 1 1 R -12A BVYC -00005 ISOLATION SCANNER 12- Sep -11 1 1 14 -30A BG4H -00093 PRIMARY DEPTH CONTROL LOG 3- Oct -11 1 1 N-04A BINC -00069 PPROF 14- Oct -11 1 1 S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 Page 1 of 1 Regg, James B (DOA) From: Sarber, Greg J [SarberJG @BP.com] Pm 1 vz. 104o Sent: Thursday, October 13, 2011 9:56 AM �` i of (31 tl To: DOA AOGCC Prudhoe Bay Cc: Daniel, Ryan; Willingham, James M; Kilfoyle, Jeffery A; Reem, David C; Rossberg, R Steven; Cismoski, Doug A; Sheffrey, Tom (Fircroft) Subject: Doyon 16 BOP Usage Report for S -09i on 10 -12 -2011 Attachments: BOPE usage S- 091.10- 12- 2011.docm All, Doyon 16 is currently conducting a tubing swap workover on well S -09i. At approximately 21:00 hrs last night there was a minor influx of gas /crude circulated out of the well. The BOP usage report for that event is attached to this email. The plan forward is to come out of the hole and test BOP's prior to running the completion. Please contact me if there are any additional questions or information needed. Sincerely, Greg Greg Sarber Operations Superintendent RWO /CTD +1 (907) 659 -5329 (Office - slope) +1 (907) 242 -8000 (Cell Phone) Harmony 2157 Alternate: Jim Willingham 10/13/2011 • Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: David Johnston Contact Number: 659 -5329 Contact Number: 659 -4177 Traction Number: Well Location & Name: GPB S -09i Permit To Drill (PTD) Number: 182 -104 Date and Time of Incident: 10/12/2011 21:00 Original Scope of Work: Run 9 -5/8" scraper with composite bridge plug mill out assembly. Dress off new perfs in 9 -5/8" casing in Kuparuk formation, then trip in hole and mill out 4 -1/2" composite bridge plug in tubing tail. Operational Description Leading up to Well Control Event: After dressing off perfs at 7570 ft to 7663 ft, shut down pumps to make up another stand and start to trip in hole to mill out plug. Noted the returns were getting dirty and saw bubbling in well head with no flow. Monitored well and it did not flow, and there was no pit gain at this time. Elected to close bag and circulate a bottoms up as a precaution. During the circulation we took a 2 bbl gain, shut down and closed choke to monitor pressure. Pressure built to 90 psi BOPE Used and Reason: Annular Preventer was shut -in to circulate a bottoms up through the choke as a precaution. After the gain was taken the annular was used to circulate out the well to get all remaining influx out. Held a little back pressure with the choke during circulation (60 to 80 psi). After circulation well was static with no flow and no bubbles. Is a BOPE Test Required after use ( Yes / No): If no, why Yes, Plan to test first trip out of hole Plan Forward: Continue to trip in hole and mill out composite bridge plug, then POH to test BOP's. Additional Comments: Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa .aogcc.prudhoe.baynalaska.gov Email CC List Well Integrity Team Leader Ryan Daniel HSE Advisor Jeff Kilfoyle Engineering Team Leader Ken Allen, John Egbejimba, John McMullen, Dave Reem Wells Operations Manager Steve Rossberg Wells Intervention Manager Doug Cismoski Organizational Capability Tom Sheffrey BOPE Usage Report for AOGCC August 2, 2010 HRE 1 Page 1 of 1 • • Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) Sent: Thursday, October 06, 2011 10:53 AM To: McLaughlin, Sean M Cc: Maunder, Thomas E (DOA) ,0 Subject: RE: S -09i - AOGCC review of USIT prior to perforating (PTD 04) Sean, You can email me over the weekend with the log results. I wanted to look at the USIT before we authorize perforating the Kuparuk zone ( new pool). Could you have them text me first to let me know the USIT has been run and I will check my email for the log. My cell number is below. Area Injection Order 22E authorizing comingled injection of the Kuparuk (Aurora Oil Pool) and Prudhoe Oil Pool was approved in August of this year. Regards, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) ya ' , 1 4 ; i4) I'1 f, , 1 0 ? ti 1l 444 -3433 (cell) From: Maunder, Thomas E (DOA) Sent: Thursday, October 06, 2011 10:33 AM To: Schwartz, Guy L (DOA) Subject: FW: S -09i - AOGCC review of USIT prior to perforating Before I reply, I expect the review would be in town by one of us. They should send the relevant log section in pdf so we can read it at home. I will not be around on Sunday so you'll have the cover that day. Tom From: McLaughlin, Sean M mailto:Sean.McLau hlin @b .com 9 � [ 9 P l Sent: Thursday, October 06, 2011 10:30 AM To: Maunder, Thomas E (DOA) Subject: S -09i - AOGCC review of USIT prior to perforating Tom, Doyon 16 is currently on S -09i. Per the sundry "Commission to review USIT results before perforating ". There is a chance this could happen this weekend. Do you know if the review of the USIT needs to happen on the slope or in town. If in town with who? Regards, sean Sean McLaughlin RWO Engineer 564 -4387 Office 223 -6784 Cell 10/6/2011 • • Page 1 of i Maunder, Thomas E (DOA) From: Schwartz, Guy L (DOA) l D tO Sent: Tuesday, July 19, 2011 11:01 AM To: Maunder, Thomas E (DOA); Roby, David S (DOA) Cc: Saltmarsh, Arthur C (DOA) Subject: RE: S -09 commingled injection.doc Dave, I only saw one issue. Are we requiring them to log Inj profiles for both phases of injection fluid (water and MI) ? That is how I read the Conclusion 9. Not sure what the standard we have used in the past for multiple pool injectors. Guy Schwartz Senior Petroleum Engineer l.sQ3 (D . D-- l t AOGCC 793 -1226 (office) 444 -3433 (cell) From: Maunder, Thomas E (DOA) Sent: Monday, July 18, 2011 1:27 PM To: Roby, David S (DOA) Cc: Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Subject: FW: S -09 commingled injection.doc F. t aj?Olt I did some editing. From: Roby, David S (DOA) Sent: Monday, July 18, 2011 12:27 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Subject: FW: S -09 commingled injection.doc Did any of you have any comments on this? Dave Roby (907)793 -1232 From: Roby, David S (DOA) Sent: Thursday, June 16, 2011 2:19 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Regg, James B (DOA) Subject: RE: S -09 commingled injection.doc After discussions with John and Jody it was decided that the best way to proceed on this matter was to issue amended AlOs for both pools that adds a new rule covering the two commingled injection wells that are authorized (S -09 in this amended order and S -31A, which was authorized by A10 22C.002 and AIO 3.010) for the AOP and POP. Additionally, since the order was open I've updated the couple of rules in A10 3 that were modified via previous admin approvals, and added the new mechanical integrity language that was adopted for statewide operations back in 2004. I thought about doing more wholesale changes to AIO 3 to include a list of approved fluids and update the administrative actions language to be what we currently use but decided that it would be cleaner to 10/11/2011 • • Page 2 of wait a couple of months until we get a planned application from BP to adopt a standardized list of approved fluids for all PBU pools. At that time I plan to put out a hearing notice covering both BP's application and the Commission's own motion(s) to make more wholesale changes to bring the 25 year old A10 3 up to date (possibly even merging AlOs 3 and 4). If you can think of anything in any PBU AIO that should be updated when we have the opportunity to open the orders let me know and I'll add it to the list of topics in the hearing notice. Attached are the two draft amended AlOs. Please review and comment as you see fit. Thanks, Dave Roby (907)793 -1232 From: Maunder, Thomas E (DOA) Sent: Wednesday, June 15, 2011 9:26 AM To: Roby, David S (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Subject: RE: S -09 commingled injection.doc I spoke with Dave on this. My initial read is I am not sure this is the "form" that the approval should take. Dave indicated that this new protocol is the result of a regulation amendment. When we have authorized commingling previously, it has been via an administrative approval against the Area Injection Order for individual wells and in the case of pool wide commingling with an AA against the appropriate CO and AIO. The examples I found on the web site searching the Area Injection Orders using "commin" are: AIO 30.002 comingled produced water in Fiord Oil Pool AIO 26A.002 -CO 505A.001 -00 471.007 commingled MI in L -103 and V -105 in Orion and Borealis Oil Pools AIO 22C.002 -AI0 3.010 commingled WAG injection in S -31A in Prudhoe and Aurora Oil Pools It would appear that what is requested for S -09 is similar to what was approved for S -31A 12/7/06. My concern here is having new numbered orders applying to pools subject to prior issued actions. There is a very real possibility to lose the documents when they are not located within the original orders. That problem was encountered in the early days of the commission when subsequent orders were issued applying to pools already subject to orders. If you refer to CO 432 for Kuparuk Oil Pool, you will find ... 1. Various conservation orders and administrative approvals have modified Conservation Order 173. 2. Rule 8 of Conservation Order 173 was repealed and reenacted by Conservation Order 230 on May 6, 1987. 3. Conservation Order 230 was amended by Conservation Order 276 on August 6, 1991. 4. Rule 9 of Conservation Order 173 was amended by Conservation Order 276 on August 6, 1991, although the requirements of Rule 9(c), Conservation Order 173, have not been modified since the rule was adopted on May 6, 1981. My 2 cents. Tom From: Roby, David S (DOA) Sent: Tuesday, June 14, 2011 5:57 PM To: Maunder, Thomas E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA) Subject: S -09 commingled injection.doc Attached is a draft order authorizing commingled injection in the PBU S -09 well. Please review and comment as you see fit. Thanks, 10/11/2011 • • 11/0 olF A[LnsEA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 David Reem Engineering Team Leader g ) l BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU S -09 Sundry Number: 311 -203 Dear Mr. Reem: `' 0 201a 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, 4 0 - " Daniel T. Seamount, Jr. r yJ Chair DATED this L/ day of July, 2011. Encl. . STATE OF ALASKA C (/ ALASKA AND GAS CONSERVATION COMMISS+ �.(u ' c� APPLICATION FOR SUNDRY APPROVALVS' A�i��N .� t fl1 20 AAC 25.280 -_ 1. Type of Request: m i ID Abandon ❑ Plug for Redrill -® P erforate New Pool ❑ Repair Well ❑ Chang�'Y� FO Ors C Jirt11i1$SI011 ❑ Suspend ❑ Plug Perforations ❑ Perforate - k7.1 Pull Tubing ❑ Time Extension '?Ilrt? iri ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Development ❑ Exploratory 182 -104 3. Address: - ® Service ❑ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519 -6612 50- 029- 20771 -00 -00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: Greater than 2 miles PBU S-09 - Spacing Exception Required? ❑ Yes ® No 9. Property Designation: 10. Field / Pool(s): ADL 028257 & 028258 Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10480' - 9218' 10434' 9176' None None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2678' 13 -3/8" 2678' 2678' 4930 2670 Intermediate Production 10480' 9 - 5/8" 10480' 9218' 6870 4760 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9931' - 10289' 8715' - 9042' 5 -1/2 ", 17# x 4 -1/2 ", 12.6# L -80 9806' / 8602' Packers and SSSV Type: 9 -5/8" TIW 'HPBP' packer Packers and SSSV 9702' / 8508' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Development - IN Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: August 1, 2011 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date: ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned _ WAG ❑ SPLUG ❑ Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Rusty Knels, 564 -4676 Printed Nam David em Title Engineering Team Leader Wilmer Hoffman, 564 - 4592 Prepared By Name/Number. Signature ( .o Phone 564 - 5743 Date 6/N/20 J� Terrie Hubble, 564-4628 r Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3 1 1 Sundry Number: `..+ ❑ Plug Integrity relf BOP Test (Mechanical Integrity Test ❑ Location Clearance I goon use- /30P 7;.5 Other: if--2500 S' A n mt. „disci s f ` �`"`") / iL C �-) -fa Re-t i �w � / 4 ) Not � � e-ef: ,k4. 4...,k Pod. (--/ -, afc►4- b t. � crc. � "� p Subsequent Form Required: / p — S/O y C No p 4, 5) e�f // /6 a� C' k e4 - p4v' /� �t / a , APPROVED BY / l Approved By: COMMISSIONER THE COMMISSION Date 7 Form 10-403 Rev 01/2010 * 7 C 6 . /r Subm' I n Duplicate RBDMS JUL 07 �� '� /'f, .c ' �46 0 4/4 RIGINAL • • bP GPcji„ 4 S -09i Expense Rig Workover Scope of Work: Pull 5 -W L -80 completion, Replace Casing Pack- offspnd Tubing Spool, run USIT. If cement is adequate for zonal isolation, perforate Kuparuk formation. If cement is not adequate, then will not perforate into Kuparuk formation. Run 4 -1/2" L -80 single selective injection completion. MASP: 2,457 psi Well Type: Ivishak Injector Estimated Start Date: August 1 2011 Production Engineer: Mackie Derrick Intervention Engineer: Rusty Knels Pre -Rig Work Request: S 1 SBHPS. Run mechanical caliper from 9,680' to surface `i Check the tubing and casing hanger lock down screws for free movement. Completely back out and check each lock down screw for W 2 breakage (check one at a time). PPPOT -T & IC. F 3 MIT -OA to 2,000 psi, MIT -IA to 2500 psi. LLR if fails. Run and set composite plug at 9,755'MD. MIT -T to 1000 psi. LLR if fails. E 4 Jet cut 5 1/2" tubing at 9,665'. (Reference Tubing Tally 8- 13 -88) CMITxT -IA to 500 psi. Circulate with 8.6 ppg seawater and freeze protect F 5 to 2,200'. ✓ 6 Set BPV in tubing hanger. O 7 Remove the wellhouse and flow line. Level the pad as needed for the rig. • • Proposed Procedure: 1. MIRU. ND tree. NU 3 Preventer BOPE with annular, blind / shears, mud cross and 3 - %" x 6" ' VBR pipe rams. Pressure test Blind Rams and VBR's to 4,000 -psi, Annular to 3,500 -psi. 2. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. ✓ 3. Pull and LD 5 -' /z" tubing string from the jet cut. r 4. RIH with dressing assembly. Set storm packer. yodp o r r� 5. Change 9- casing packoff and tubing spool. ( mot 'T2 +' b rc 6. Pull storm packer. RIH, scrape casing and dress the tubing stub. POOH standing back DP. 7. RIH with 9 5/8" RTTS packer, set at -9,600', test casing to surface to 4000psi. POOH. ✓ 8. Rig up SLB E -Line and run USIT log to verify top of cement. 9. If cement bond is adequate for zonal isolation, RIH with perforation guns and perforate Kuparuk formation. 10. RIH and mill out composite plug, push remnants to bottom. Pull out and LDDP. 11. Run 4 -W, 12.6 # /ft, L -80 completion with HES TNT packer. Position lower packer at -9,575' MD. If Kuparuk formation is perforated, additional HES TNT packer will be set at -7,350' with a sliding sleeve placed between the two packers to allow injection into Kuparuk (If adequate cement bond exists). 12. Displace the IA to packer fluid and freeze protect to 2,200' MD. 13. Set the Packers, test tubing and IA to 4,000 -psi. 14. Set BPV. ND BOPE. NU and test tree. RDMO. Post -Rig Work: V 1 Install flowline, re -set wellhouse, pull BPV. Retrieve ball and rod. Pull RHC body. No GLV work - no GLMs run into S 2 well. F 3 AOGCC MIT IA -post RWO. il TREE = • 6" McEVOY WELLHEAD = McEVOY • SAFETY NO: WELL REQUIRES A SSSV WHEN ON ACTUATOR = OTIS S -09 M I. KB. ELEV = 66.98' BF. ELEV = 38.50' KOP= 3200' Max Angle = 40@ 5500' 1984' H 5 -1/2" HQR SSSV LANDING NIP, ID = 4.562" • Datum MD = 10098' Datum TVD = 8800' SS 113 -3/8" CSG, 72 #, L-80, ID 12.347" H 2678 2614' I-I 9 -5/8" DV PKR r Minimum ID = 3.725" @ 10258' 4 -1/2" OTIS XN NIPPLE 7790' H9-5/8" DV PKR I 0 .(°5 1 I I 9640' H5-1/2" OTIS XA SLIDING SLEEVE, ID = 4.562" I � '-'11 I 9700' I-I PBR TBG SEAL ASSY 1 a 9702' H9-5/8" TIW HPBP PKR, ID = 4.00" I =, 5 -1/2" TBG, 17 #, L -80 AB IPC, 0.0232 bpf, ID= 4.892" H 9702' • ' 0 9702' I_15 -1/2" x 4 -1/2" XO I I TOP OF 4-1/2" TBG H 9702' 1 1 9741' 1-14-1 /2" PARKER X NIP, ID = 3.813" I GBP t' i5> ' n^n 1 1 1 9773' H4_1/2" PA RKER X NIP, ID = 3.813" I 14 -1/2" TBG, 12.6 #, L -80, 0.0152 bpf, ID= 3.958" H 9806' I-/ ■ 9806' H4 -1/2" OTIS TBG TAIL, ID= 3.980" I 9788' H ELMD TT LOG UNAVAILABLE I PERFORATION SUMMARY r I REF LOG: BHCS ON 07/18/82 ANGLE AT TOP PERF: 25 © 9931' I Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 3 -3/8" 6 9931 -9976 0 02/18/89 10157' I-I MARKER JOINT 1 2 -7/8" 4 10066 -10137 0 01/19/84 I 2 -7/8" 1 10138 -10250 0 07/04/84 3 -1/8" _ 1 10264 -10289 0 10/12/85 _ 1 I TOP OF 4-1/2" TBG H 10250' _I g 10250' H OTIS WD PKR, 3/8" CHOKE INSTALLED I ' ' 10254' I-14-1/2" OTIS X NIP, ID = 3.813" I ' ' 10258' H4-1/2" OTIS XN NIP, ID = 3.725" I 4-1/2" TBG, 12.6 #, L -80, 0.0152 bpf, ID = 3.958" I 10261' I \ 10261'1-14-1/2" OTIS TBG TAIL, ID = 3.980" I I PBTD I 10434' ^ H ELMD TT NOT LOGGED I * 1 1 , 1 00004 4 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 8Q''' 4.1.1.1.14.1.1.1.1.1 104 SO I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/25/82 ORIGINAL COMPLETION 02/15/11 MB /JMD ADDED SSSV SAFETY NOTE WELL: S -09 08/13/88 RWO PERMIT No: 182 -1040 I 03/08/01 SIS -MH CONVERTED TO CANVAS I API No: 50- 029 - 20771 -00 03/12/01 SIS -MD FINAL SEC 35, T12N, T12E 11/29/01 RN/TP CORRECTIONS BP Exploration (Alaska) TREE =, . 6 " McEVOY WELLHEAD = McEV OY • S-09 Q SAFETY :WELL REQUIRES A SSSV WHEN ON ACTUATOR = OTIS M f' N KB. ELEV = 66.98' Proposed RWO BF. ELEV = 38.50' KOP = 3200' ill 11 I 2,100' 1-14-1/2" X Nipple = 3.813" Max Angle = 40@ 5500' Datum MD = 10098' Datum TVD = 8800' SS 2614' H9 -5/8" DV PKR I 13 -3/6" CSG, 72#, L -80, ID = 12.347" H 2678' Hr II= 4 1/2" 12 6# (.. -80 TC bing II -7300' 4 1/2" X Nipple= 3.813" ' Minimum ID = 3.725" @ 10258' :� -7350' 4 1/2" x 9 5/8" L -80 Production PKR 4-1/2" OTIS XN NIPPLE l -7500' 4 1/2" HES sliding sleeve 4 1/2" X Nipple= 3.813' - -7400' I -7570' - 7610' Perforate Kuparuk -7635' - 7663' Perforate Kuparuk — I 7700' I-19 -518" DV PKR I 4 1/2" x 9 5/8" L -80 Production PKR 9575' - g ►. 4 1/2" X Nipple= 3.813" - -9615' - — II -9650' Unique Machine Overshot 5 1/2" Power Jet Cut 9,665 - I 9,665' 1 9700' I -I PBR TBG SEAL ASSY III 0■11 9702' H9 -5/8" TNV HPBP PKR, ID = 4.00" I 5-1/2' TBG, 17 #, L -80 AB IPC, 0.0232 bpf, ID = 4.892" H 9702' ( 9702' H5-1 /2" x 4-1/2" XO I I TOP OF 4-1/2" TBG I-I 9702' I-''''' I I ( 9741' H4-1 /2" PA RKER X NIP, ID = 3.813" I I I 9773' H4-1/2" PA RKER X NIP, ID = 3.813" 4-1/2" TBG, 12.6 #, L -80, 0.0152 bpf, ID = 3.958" H 9806' I---/ \ I 9806' I-14-1/2" OTIS TBG TAIL, ID = 3.980" I 9788' H ELMD TT LOG UNA VA ILA BLE I PERFORATION SUMMARY I REF LOG: BRCS ON 07/18/82 ANGLE AT TOP PERF: 25 @ 9931' Note: Refer to Production DB for historical perf data I SIZE SPF INTERVAL Opn /Sqz DATE 7570 -7610 planned 10157' I. 1MA RKERJOINT I 7635 -7663 planned 3 -3/6" 6 9931 -9976 O 02118 ;89 I 2 -7/8" 4 10066 -10137 O 01/19/84 2 -7/8" 1 10138 -10250 0 07/04/84 I 3-1/8" 1 10264 -10289 0 10/12/85 I TOP OF 4 -1/2" TBG hi 10250' I , 10250' I-I OTIS WD PKR, 318" CHOKE INSTALLED I I I 10254' 1-14-1/2" OTIS X NIP, ID = 3.813" I ' I I 10258' ( -14 -1/2' OTIS XN NIP, ID = 3.725" I 4-1/2" TBG, 12.6 #, L -80, 0.0152 bpf, ID = 3.958" I—I 10261' J / ■ 10261' J--I -1 /2" OTIS TBG TAIL, ID = 3.980" I PBTD I 10434' 14 I—� ELMD TT NOT LOGGED I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H . x.....4...11.6.4.4...4.1 I0 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/25;82 ORIGINAL COMPLETION 02/15/11 MB /JMD A DDED SSSV SA FETY NOTE WELL: S -09 08/13/88 RWO 06/13/11 WWRK Proposed RWO PERMT No: 182 -1040 03/08/01 SIS -MH CONVERTED TO CANVAS API No: 50- 029 - 20771 -00 03/12/01 SIS -MD FINAL SEC 35, T12N, T12E 11/29/01 RN/TP CORRECTIONS BP Exploration (Alaska) • RECE!VED .1; Alo;; U & Gtv, Cori. 'sson ArICIIPtisge Well S-09 Completed AOR 6/30/11 9 / 1 ■ 7-If . • • S -09 AOR o There are 2 wells inside the 1 /4 mile radius of S -09. o These wells are Ivishak wells that penetrate the Kuparuk Horizon. o They are S -08 and S -02, both of which are outside the isolated fault block that S -09 is drilled but within the 1 /4 mile radius. o There are 2 major north/south faults that are sealing faults i o 2 minor faults inside the fault block that may baffle fluid migration cn 1 5 o a)5- _c � � c a) 0 0 CU = v th Cn 5 CCS . i 13) 0 1 7 ' N f • r C V C j , F Cl) O O rte, E N C ' ,t — .� • i !.IPI • r 1 a 4 7 a) .'- . \ __,---\ , '' 'Il ' ' E .2 A -; , . 7, c,) 4... , .• .:. i . , ._ ... ..... _ . cy, 1 cDca • • S -08 Review S -08 was drilled in 1982 through the Kuparuk horizon and into the Ivishak where it is currently an online producer. At the Kuparuk horizon the well penetrates with the 9 -5/8" production casing. During the original drilling of the well, the 12 -1/4" hole and 9 -5/8" casing was cemented through the shoe with 1218 cubic feet of cement. Calculated top of cement with a 30% wash out of the drilled hole is 5963' MD or 5807' TVD. This places the TOC —800' TVD above the Kuparuk horizon (-6600' TVD) at the Kuparuk penetration. No logs were run to determine the true TOC. The last MITIA was in 2001. The last TIFL was completed on 10/04/2010. S -02 Review S -02 was drilled in 1982 through the Kuparuk horizon and into the Ivishak where it is currently an online producer. At the Kuparuk horizon the well penetrates with the 9 -5/8" production casing. During the original drilling of the well, the 12 -1/4" hole and 9 -5/8" casing was cemented through the shoe with 1505 cubic feet of cement. Calculated top of cement with a 30% wash out of the drilled hole is 6736' MD or 5858' TVD. This places the TOC —750' TVD above the Kuparuk horizon (6600' TVD) at the Kuparuk penetration. No logs were run to determine the true TOC. There are no recent pressure tests completed on the well. Faulting S -09 in the Kuparuk Horizon lies in between two major north/south faults in an isolated fault block. The pressure in the fault block has depleted from the production of S -118. Through static bottom hole pressure surveys of the surrounding Kuparuk wells, there is a high confidence that the two north/south faults are sealing. And therefore would have no interaction with the two AOR wells S -02 and S -08. The two minor faults running interior to the two major faults are viewed as baffling faults that will allow for fluid migration in the isolated fault block in which S -09 will be supporting. ~ • ~~ BP Exploration (Alaska) Ina ~ Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 June 25, 2009 ~ ~~ Enclosed please find a spreadsheet with a list of wells from S-Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, P ..'~~~~~~~ ~ ;~~~ ~, ~: ~rsu~~ Torin Roschinger BPXA, Well Integrity Coordinator ~ . BP Expioration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report oi Sundry Operetions (10-404) &pad r ~ nneA 6/~S/~(109 Well Name PTD S Initial top of cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitod sealant date ft bb~s it na al S-O18 1952020 025 NA 025 NA 2.s 5/30/2009 5-02A 1941090 025 NA 025 NA 1.7 5/25/2009 5-03 1617900 13.25 NA 73.25 NA 92.65 5/20/2009 S-oa 1830780 0 NA 0 NA o.s 5/25/2009 S-05A 1951890 0 NA 0 NA 0.9 5/26/2009 S-06 1821650 0 NA 0 NA 0.9 5/26/2009 S-07A 1920980 0 NA 0 NA O.s 5/26I2009 5-088 2010520 0 NA 0 NA 0.85 5/27/2009 5-09 7821040 1.5 NA 1.5 NA 9.4 5/31/2009 S-t0A 1911230 0.5 NA 0.5 NA 3.a 5/31I2009 5-116 1990530 025 NA 025 NA 7.7 5/27I2009 S-72A 1851930 025 NA 025 NA 1.7 6/1I2009 S-t3 1821350 8 NA 8 NA 55.3 6/i/2009 S-15 7840170 0.25 NA 025 NA 3 6!2/'1009 S-17C 2020070 0.25 NA 025 NA 2.6 6/1/2009 S-18A 2021630 0.5 NA 0.5 NA 3 6/2I2009 S-19 1861160 0.75 NA 0.75 NA 22 5/19/2009 S-20A 2010450 025 NA 025 NA 13 5/19/2009 5-21 1900470 0.5 NA 0.5 NA 3.4 5/25/2009 S-228 1970510 0.75 NA 0.75 NA 3 5/19/2009 S43 1901270 025 NA 025 NA 1.7 5/25/2009 5-248 2031630 0.5 NA 0.5 NA 2.6 5/25/2009 S-25A 1982140 0.5 NA 0.5 NA 2.s 5/25/2009 5-26 1900580 0.75 NA 0.75 NA 3.4 5/26/2009 5-278 2031680 0.5 NA 0.5 NA 2.6 5/37/2009 5-280 2030020 0.5 NA 0.5 NA 2.6 5/31l2009 S-29AL7 1960120 0 NA 0 NA 0.85 5/27/2009 S-3o 1900660 0.5 NA 0.5 NA 5.1 5/31/2009 S37A /982200 0.5 NA 0.5 NA 3.4 5/26/2009 S-32 1901490 0.5 NA 0.5 NA 3.4 5/31/2009 S-33 1921020 0.5 NA 0.5 NA 4.3 5/26/2009 S-3a 7921360 0.5 NA 0.5 NA 3.4 5/31/2009 5-35 1921480 0 NA 0 NA .e5in 5/31/2009 S36 1927160 0.75 NA 0.75 NA 425 5/27/2009 5-37 1920990 125 NA 125 NA 11.9 5/27/2009 S-3& 1921270 025 NA 025 NA 102 5/27/2009 5-41 1960240 1.5 NA 1.5 NA 77.1 5/30/2009 5-42 1960540 0 NA 0 NA O.s 5l30/2009 S-43 1970530 0.5 NA 0.5 NA 1.7 5/28/2009 5-44 1970070 025 NA 025 NA 1.7 5/28/2009 5-100 2000780 2 NA 2 NA 21.3 5/29/2009 S-101 2001150 1.25 NA 125 NA 77.s 5/29/2009 S-10211 2031560 1.25 NA 725 NA 11.1 5/31/2009 5-103 2001680 1.5 NA 1.5 NA 17.9 5/18/2009 5-104 2001960 1.75 NA 1.75 NA 15.3 5/20/2009 S-105 2007520 4 NA 4 NA 32.7 5/20/2009 S-t06 2010120 1625 NA 7625 NA 174.3 6/2/2009 S-7o7 2011130 2.25 NA 225 NA 2e.s 5/18/2009 5-108 2011000 3.5 NA 3.5 NA a0 5/30/2009 S-tOS 2022450 2 NA 2 NA 27.3 5/30/2009 S-110 2011290 1/.75 NA 11.75 NA 98.6 5/30/2009 S-t t t 2050510 2 NA 2 NA 19.6 5/30/2009 5-112 2021350 0 NA 0 NA 0.5 5/30/2009 5-113 2021430 1.75 NA 1.75 NA 22.1 5/18/2009 S-t~4A 2021980 125 NA 125 NA ~02 5/30/2009 S-tt5 2022300 2.5 NA 2.5 NA 27.2 5/29/2009 5-116 2031810 1.5 NA 1.5 NA 13.6 5l28/2009 S-777 2030120 1.5 NA 1.5 NA 15.3 5/29/2009 S-t7a 2032000 5 NA 5 NA 76.5 5/28/2009 S-119 2041620 1 NA 1 NA 5.2 5/30/2009 5-120 2031980 5.5 NA 5.5 NA s72 5/29/2009 S-721 2060410 4.5 NA 4.5 NA 53.6 5/28/2009 5-122 2050810 3 NA 3 NA 21.3 5/29/2009 S-t23 2041370 1.5 NA 1.5 NA 20.4 5/26/2009 5-124 2061360 1.75 NA 1.75 NA 11.9 5/26/2009 S-t25 2070830 225 NA 225 NA 20.4 5/28/2009 S-126 20710970 1.25 NA 725 NA 15.3 6/1/2009 5-200 1972390 125 NA 125 NA 74.5 5/28/2009 S-207 ~ 2001840 0 NA 0 NA 0.85 6/19l2009 5-213A 2042130 2 NA 2 NA 13.6 5/29/2009 S-215 2021540 2 NA 2 NA 18.7 6/1/2009 S-216 2001970 4.75 NA 4.75 NA 51 5/29/2009 S-217 2070950 025 NA 025 NA 1.7 6/t/2009 5-400 2070740 2 NA 2 NA 9.4 5/29/2009 S-aot 2060780 16 NA 16 NA ss.5 6/2/2009 S-50a 0 NA 0 NA O.aS 5/28/2009 MEM 0 RAND UM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg K (111 Pol. Supervisor ~q -b II Ok DATE: Wednesday, August 04, 2004 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC S-09 PRUDHOE BAY UNIT S-O9 FROM: Lou Grimaldi Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv ,jÎ3~ Comm NON-CONFIDENTIAL Well Name: PRUDHOE BAY UNIT $-09 API Well Number: 50-029-20771-00-00 Inspector Name: Lou Grimaldi Insp Num: rnnLG040715130850 Permit Number: 182-104-0 Inspection Date: 7/15/2004 Rei Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 5-09 Type Inj. P TVD 9218 IA 180 2500 2450 2440 P.T. 1821040 TypeTest SPT Test psi 2127 OA 350 580 580 580 Interval 4YRT5T P/F P Tubing 1850 1850 1850 1850 Notes: Wednesday, August 04, 2004 Page I of I C. V~ C~atterton December 16, 1986 Cha' ,~.~ n .,. D.BDF.89 Lonnie C. Smith Commissioner Bobby D. Foster Petroleum Inspector Mech Integrity Test SAPC PBU Pads S, M, U, R, N, T, Y, H, F, X Prudhoe Oil Pool Wednesday, November 19, 1986: The tests began at 7:00 a.m. and were concluded for the day at 4:30 p.m. with 10'wells being tested. Thursday,..~ovember 20~ 1986: The tests began at 7:00 a.m. and were concluded for the day at 7:00 p.m. with 14'wells being tested. Friday, November 21, 1986: The tests began at 6:30 a.m. and were concluded for the day at 4:30 p.m. with 10'wells being tested. Saturday.,..~0vember 22~ 1986: The tests began at 6:30 a.m. and were concluded at 1:00 p.m.; and were resUmed at 6:00' p.m. and concluded for the day at 9:00 p.m. ~-.£ O~'~ As the attached mechanical integrity tes_t ort show were tested, all of which met theJAOGCC regulations. In summary, I witnessed the mechanical integrity tests on Standard Alaska Production Company's injections wells listed on the attached test forms. Attachments AI~SKA OIL AND. GAS CONSERVATION CCb~SSION b~-CHANICAL Ilq/Y_L'R.ITY TEST · *P *I TYPE OF PKR CASING TBG REQ TBG TIb~. WELL *S --- ANNUII~ TVD SIZE/WT/GRADEI SIZE TEST CSG TBG TBG TBG *M *N FLUID MD PRESS PRESS CSG CSG CSG PRESS PRESS PRESS , . , . ~' h u ~ ~ ~ ~D ~ ~,' ~.Sd . . /~- .. ..... FLUID: GRADIENT: AOGCC WITNESS SI · ~ S - SALT WATER INJ GLYCOL M - MISCIBLE INJECTION SALT WATER · I - INJECTING DRTfLING MUD !:.;N-NOT INJELTING OTHER · ?~:.~ ~:: ~ 20 AAC 25.030(a) 20 AAC 25.412(c) 20 AAC 25.252(d) MEMORANDUM TO: THRU: FROM: Dan Seamount ~)~ Chairman Blair Wondzell ,~~ P.I. Supervisor Lou Grimaldi ~- Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: September 23, 2000 SUBJECT: Mechanical Integrity Tests BPX S pad S-9 Prudhoe Bay Unit Prudhoe Bay Field NON- CONFIDENTIAL Packer DePth Pretest Initial 15 Min. 30 Min.. I WellI S-9 J Typelni.II I 00 I 00 I 00 I lntervall 4/ P:T.D.I 1821040 IT),petestI P ITestPsil 212'~ I Casingl 35(I I 24701 2'430 I 2420 I p/F I --P'f Notes: i. Type IN J, Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Test's Details Thc test went well, Joe Anders supplied pertinent well infonga, tion which helped well and I passed this well for continued injection,- I= Initial Test 4= Four Year Cycle V= Required by Vadance W= Test dudng Workover O= Other (describe in notes) . . . .~reparing for the test. The test went While on S pad I observed some Flow lines in need of extra support. I sPoke with the BPX W.O.A; lead operatOr Steve - Matonis. Steve was filling in for the Operation Team Leader this week and conveyed to me that they were aware of the subsidence problems on this and other pads. Steve will be getting back in touch with me later this week. with information. on this problem. M.I.T.'s performed: t_ Number of FailUres: .None Attachments: S-9 well schematic Total Time dudng tests: 2 hrs cC: Joe AnderslKevin Yeac~er {BPX) MIT report form 5/12/00 L.G. MIT PBU S-9 9-23-00 LG.xls 9/26/00 LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: 7 August 1995 RE: Transmittal of Data Sent by: ANCH.EXPRESS Dear Sir/Madam, Enclosed, please find the data as described below: # DESCRIPTION F-41 ST 1 PF6/PERF FINAL BL+RF R-27 1 PFC/PERF FINAL BL+RF Run ~ 1 5670.06 ECC No. Run # 1 __ 1984.01. Run ~ 1 2262.01 Run # 1 5628.03 Please sign and return to:-Attn. Re--leon . ~Services Received ~ .~.' ~ii~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 DATE: 06/19/92 T# 83612 BP CASED HOLE FINALS Enclosed is your copy of the materials listed below. If you have any questions, please contact BP Well Records at (907) 564-4004. A-25fZ'~ PROD-F 05/24/92 #1 a-12~e--I/~ STATIC 05/21/92 #1 A-21~-'g GAS LIFT SURVEY 05/24/92 #1 S-14~'1~ INJ 05/14/92 #1 D-17 ~-1~, GAS LIFT SURVEY 06/01/92 #1 S-09~-~? INJ 05/26/92 #1 M-21------~-~$, PROD-F 06/01/92 #1 P-15~--/~ GAS LIFT SURVEY 05/28/92 #1 X-12~O'~ GAS LIFT SURVEY R-05~'~ INJ R-27 ~'$/ CCL/PERF Y-34~['~ . GAS LIFT SURVEY A-27~Z~)? MISC GAS INJ S-09__,~2-' ~ INJ ~-17 $~,~ GAS ENTRY SURVEY 5 " D-21~~ GAS ENTRY SURVEY 5 " Z-Ol ~-~ SAS SNTRY SURW. Y 5 " C-01 ~).~o GAS ENTRY SURVEY 5 " 06/02/92 #1 06/06/92 #1 06/13/92 #1 05/13/92 #1 05/20/92 #1 05/14/92 #1 05/28/92 #1 12350.00-12525.00 CAMCO 5 " 8790.00- 9290.00 CAMCO 5 " 3000.00-12700.00 CAMCO 2/5" 10250.00-10800.00 CAMCO 5 " 100.00-10376.00 CAMCO 2 " 9840.00-10253.00 CAMCO 5 " 100.00- 9110.00 CAMCO 2/5" 0.00-12300.00 CAMCO 2/5" 2400.00- 8500.00 CAMCO 2 " 8890.00- 9165.00 SCH 5 " 8650.00- 9553.00 ATLAS 5 " 100.00- 9678.00 CAMCO 2 " 8300.00- 9116.00 CAMCO 5 " 9850.00-10200.00 CAMCO 5 " 10750.00-11080.00 CAMCO 05/26/92 #1 05/13/92 91 05/15/92 #1 9900.00-11220.00 CAMCO 10400.00-10782.00 CAMCO. 7200.00- 9070.00 CAMCO Information Control Well Records Adrian J. Martin '" ECEIVED JUN 2 6 1992 Alaska Oil & Gas Cons. Commission Anchorage BP EXPLORATION EOUSTON ARCO CHEVRON EXXON Date: TEXACO 'TO: Y~: MOBIL PHILLIPS STATE 0F ALASKA ARCHIVES INDEXED BP Exploration (Alaska) Inc. 900 East 8enson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-661::' (907) 561-5111 04-19-89 79984 REFERENCE: BP FINAL DATA - PRESSURE SURVEY DATA The following material Is being submi'M'ed herewith. Please acknowledge receipt by signing a copy of this .letter and returning if to this office: S-09I BHP--S tatic Gradient 03-26-89 Otis 3-28 BHP--S tatic Gradient 03-30-89 Otis J-10 BHP--S tatic Gradient 03-07-89 Otis Received Date Shirley R. McCurry ~ NFORMAI ~ ON CONTROL We~ ~ Records LR2-~ BP EXPLORATION BP Exploration (Alaska) Inc. 900 East Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 March 10, 1989 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-9 (44-34-12-12) PBU Gentlemen: Enclosed, in duplicate, is Form 10-404, Report of Sundry Well Operations, for the above-named well. This contains our subsequent report of perforating the well. Yours very truly, B. J. P61icky ~ Supervisor Waterflood & Miscible Flood BJP:JAM Enclosures (4) cc: L. Burke (MB12-1) Well Records (LR2-1) w/10 Well File STATE OF ALASKA AI..~SKA OIL AND GAS CONSERVATION COMMIS'~'~N REPORT OF SUNDRY WELL OPERATIONS Stimulate Plugging Alter casing. Repair well 5. Type of Well: Development X Exploratory Stratigraphic Service 10480feet Plugs (measured) BKB 9218feet 1. Operations performed: Operation shutdown Pull tubing 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1842' SNI_, 1635' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval N/A - water injection well At effective depth 341' NSL, 662' WEL, SEC. 34, T12N, RI2E, UPM At total depth 330' NSL, 674' WEL, SEC. 34, T12N, R12E, UPM 12. Present well condition summary Total depth: measured true vertical Perforate X Other__ 6. Datum elevation (DF or KB) KBE-- 66.98 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number S-09 (44-34-12-12) PBU g. Permit number/approval number 82-104 / 9-065 10. APl number 50- O29-20771 11. Field/Pool Prudhoe Oil Pool Effective depth: measured true vertical 10436feet Junk (measured) BKB 9178feet Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size Cemented Measured depth True vertical depth - - BKB 110 20 x 30 8 c.y. 138 138 2650 13 3/8 3720 c.f. 2678 2678 10452 9 5/8 2888 c.f. 10480 9218 .. measured true vertical 9931'- 9976' (Sag R.) 10067'- 10250', 10265'. 10290' (Ivishak) subsea 8649'-8689' (Sag R) 8772'- 8976' (two ivishak intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 9702' with 4 1/2" tallpipe to 9806' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary 14. 9 5/8" TIW PBR/packer at 9702'; 9 5/8" Otis WD packer w/TP assy. at 10250'; 5 1/2" BVN at 1984' ~ Intervals treated (measured) ~ ~ ~ -~ ~ ,~ ~.' .,,1 ~., - ;:.~ ~ ~:?~/'.:; ~.i~ ~ .... Treatment description including volumes used and final pressure ....~;;~_.:~.~_. ~ .......:~ Reoresent~ive Daily Average Pr~u~ion or Inie~ion D~a ~?O~0~ ''~' -~. .... . ~ T~ . "~I:Z ~ OiI-Bbl Gas-M~ W~er-Bbl C~ng Pressure T~g .Press~;~. Prior to well operation Subsequent to operation 2900 3000 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil Gas Suspended Service I 17' I hereby certify that/~ f°r_,~.,~l i~and c°rrect t° the best °f my kn°wledge'~ ' Signed/,.~..~.~_z~ ~,,,,"~~_ Title Supervisor Waterflood/Miscible Flood water in. iectiop well Form 10-40'4 Rev 0~15/'88 SUBMIT IN DUPLICATE WELL S-9 (44.34.12.12~ PBU ADD'L. P~RFORATION OPERATIONS The following Sag River interval was perforated February 18, 1989 using Dresser Atlas 3 3/8" carrier guns at 6 spf: 9931' - 9976' MD BKB (Ref. BHCS, 7/18/82) A lubricator was installed and tested to 3500 psi for all well work. The well was returned to injection immediately following perforating operations, then tested. jm 2/24/89 BP EXPLORATION HOUSTON ARCO CHEVRON E~ZXON TEXACO TO: MOBIL PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR REFERENCE:: ARC]SIrES ~ BP'CASED ~[OLE FINAL LOGS BP ~ploration (Alaska) Inc 900 ~ Benson Boulevard RO. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 Date: 03-1 3-89 T~: 79875 The following material is being submi'~fl-ed herewith. Please acknowledge receipt _by signing a copy of this le~-?er and returning it to this office: C-29 PITS 02-18-89 C-30 PROD-F 02-22-89 C-31 PITS 02-20-89 F-15 PITS 02-17-89 F-18 INJ 02-23-89 H-29 GLS 02-19-89 M-06 PROD-F 02-18-89 S-09 INJ 02-19-89 W-27 PROD-F 02-16-89 W-29 PROD-F 02-15-89 Y-06 INJ 02~-17-89 Y-08 GLS 02-16-89 : #1 //1 //1 //1 //1 //1 //1 //1 //1 //1 //1 //1 1 SUR 1 11400-11880 Camco 9300-9620 Camco 11400-11635 '-Camco 9100-9650 - Camco 1850-12350 Camco FACE.8700' -Camco 1000-11650 Camco 9850-10245 Camco 11250-11450 Camco 10500-10850 Camco 10600-11350 Camco 3100-88~7 Camco 5" 5': 5" 5" 5" 5" 5" 5" 5" Race i ved Da're Anchors, ge Shirley R. McCurry ! NFORMAT I ON CONTROL .. Wel I Records LR2-1 BP EXPLORATION HOUSTON ARCO CHEVRON E,~LXON TEXACO TO: MOBIL REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES B~ CASED HOLE FINAL LOGS BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage. Alaska 99519-6612 (907") 561-5111 INDEXED Date: 02-22-89 Ti: 79839 · The follo~eing material Is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: S-09 I CCL #1 9850-10200 02-18-89 Atlas 5" Rece i ved Date Shirley R. McCurry I NFOR,%~T I ON CONTROL Wel I Records LR2-1 Standard Alaska Production Company 900 East Benson Boulevard, P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 January 24, 1989 STANDARD ALASKA PRODUCTION Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-9 (44-34-12-12) PBU Gentlemen: Enclosed, in triplicate, is Form 10-403, Application for Sundry Approvals, for the above-named well. This contains our proposal to perforate the well. BJP:JAM Enclosures (g) cc: L. Burke (MB12-1) S-9 Well File Yours very truly, Waterflood & Miscible Flood A unit of the original Standard Oil Company Founded in Cleveland, Ohio, in 1870. STATE OF ALASKA A'L."'A'~SKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 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 X Other~ 2, Name of Operator Standard Alaska Production Company 3, Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development x Exploratory Stratigraphlc Service 4. Location of well at surface 1642' SNL, 1635' EWL, SEC. 35, T12N, R12E, UPM At top of productive interval N/A - water injection well At effective depth 341' NSL, 662' WEL, SEC. 34, T12N, R12E, UPM At total depth 330' NSL, 674' WEL, SEC. 34, T12N, R12E, UPM 12. Present well condition summary Total depth: measured 10480 feet true vertical BKB 9218 feet 6. Datum elevation (DF or KB) KBE = 66.98 AMSL feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 8-09 (44-34-12-12) PBU 9. Permit number 82-104 10. APl number 50- 029-20771 11. Field/Pool Prudhoe Oil Pool Plugs (measured) Effective depth: measured 10436 feet true vertical BKB 9178 feet Junk (measured) Casing Length Structural -- Conductor 110 Surface 2650 Intermediate 10452 Production -- Liner -- Perforation depth: Size 20x30 133/8 9 5/8 Cemented 8 c.y. 3720 c.f. 2888 c.f. measured 10067'- 10250', 10265'- 10290' Measured depth 138 2678 10480 True vertical depth BKB 138 2678 9218 true vertical subsea 8772'- 8976' (two intervals) Tubing (size, grade, and measured depth) 5 1/2" L-80 to 9702' with 4 1/2" tailpipe to 9806' .Oil .& Gas Cons. Packers and SSSV (type and measured depth) 9 5/8" TIW PBR/packer at 9702'; 9 5/8" Otis WD packer w/TP assy. at 10250~ 5 1/2" BVN at 1984' 13. Attachments Description summary of proposal X 14. Estimated date for commencing operation January/February 1989 16. If proposal was verbally approved Name of approver Date approved Detailed operations program __ BOP sketch ._Z__ 15. Status of well classification as: Oil __ Gas __ Suspended __ Service water injection well 17. I hereby cert~y that ~~7~ and correct to the best of~-~ ./'/~ my knowledge. .Signed~.~.~.,~~~..~.2.~ Title Supervisor Wa,El, d/Miscible Flood J ' ,...T FOR COMMISSION USE ONLY ~',onditions of approval: Notify ~mmission so representative may-witness Plug integrity ~ BOP Test~ Location clearance ~ Mechanical Integrity Test__ Approved by order of the Commission Form 10-403 Rev 06/15/88 uired 10- ,~-/'o ~ Commissioner Ap~.~oved C.opy WELL S-9 (44-34-12-12~ PBU ADD'L. PERFORATION PROPOSAL We propose to perforate the following Sag River interval during February 1989: 9931' - 9976' MD BKB (Ref. BHCS, 7/18/82) A lubricator will be installed and tested to 3500 psi for all well work. The well will be returned to injection immediately following perforating operations, then tested. jm 1/23/89 FLOW TUBES & PACKOFF FLOWLINE FLOWLINE VALVE BOWEN x..¢,.,..~r PACKOFF J-*--HAND PUMP GREASE SEAL FLOWTUBE GREASE LINE GREASE MANIFOLD GREASE PUMP RISER B --,-GREASE RESERVOIR OP STATE OF ALASKA '---~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operation performed: Operation shutdown [] Stimulate [] Plugging [] Perforate [] Pull tubing [] Alter casing [] Other [] 2. Name of Operator Standard Alaska Production Company 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E At top of productive interval 519' WEL, 481' NSL, Sec. 34, T12N, R12E At effective depth 662' WEL, 341' SNL, Sec. 34, T12N, R12E At total depth 674' WEL, 330' NSL, Sec. 34, T12N, R12E 5. Datum elevation (DF or KB) KBE-- 66.98 feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number S-9i (44-34-12-12) 8. Approval number 8-455 9. APl number 5 0 - 029-20771 10. Pool Prudhoe Oil Pool 1. Present well condition summary Total depth: measured true vertical Effective depth: Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: measured true vertical Length 10,480 feet 9218 BKB feet 10,436 feet 9178 BKB feet Size 82' 2O"x3O" 2650' 13-3/8" 10,452' 9-5/8" Plugs (measured) Junk (measured) Cemented 8 cu ft Concrete 3720 cu fl Arctic Set il 2058 cuft Class G 700 cu fl Class G 130 cu fl Arctic Set ! Measured depth BKB 110' 2678' 10,480' measured 10067'-10250' 10265'- 10290' true vertical (Subsea) 8772'-8939' 8953'- 8976' Tubing (size, grade and measured depth) 5-1/2" 17#L-80 TC4S Tubing w/4-1/2" Tailpipe 9803'. True Vertical depth BKB 110' 2678' 9218' Packers and SSSV (type and measured depth)9-5/8" TlWPacker at 9702'; BVN at 1PK4E C E ~ V E D 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure OCT 2 7 ~98,3 Oil & Gas Cons, C0mmissl0i--.-: , Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure 1800 bbl 1400 bbl Tubing Pressure 1260 psig 900 psig 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~ Form 10- - - Tit le Workover/Completions Supervisor Date Submit in Duplicate WELL S-9i WORKOVER PROCEDURE SUMMARY ATTACHMENT I . 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. Pulled ball valve. Set plug in tailpipe. Circulated tubing to kill weight brine. Freeze protected well. Set BPV. MIRU workover rig. Accepted rig @1800 hrs on 8/6/88. Pulled BPV. Circulated diesel from well. Set two-way check valve. ND tree. NU & tested BOPE to 5000 psi. Pulled 4-1/2" tubing. Recovered slick stick. Test 9-5/8" casing to 2500 psi- OK. Milled and recovered 9-5/8" packer. Cleaned out to 10436'. Ran 9-5/8" casing scraper to 10436' and reverse circulated. Ran casing corrosion log. Set storm packer and replaced 9-5/8" packoff. Recovered storm packer. Ran 8.5" gauge ring to 10400'. RIH with 9-5/8" WD packer-tailpipe assembly. Logged into place and set @10: RIH with 5-1/2" tubing with 4-1/2" tailpipe. Set two-way check valve. ND BOPE. NU 6" tree and tested to 5000 psig. Set plug in tailpipe. Set 9-5/8" permanent packer. Opened sliding sleeve. Changed over annulus to 9.6ppg brine + 35 bbl diesel & tubing to diesel. Closed sliding sleeve. Tested annulus to 2500 psi- OK. Set BPV. Cleaned out cellar. Released rig '@2000 hrs on 8/13/88. REcEiVED Gas Cons, Comrnt,~u,o, Anchorage. RVS 1 10/26/88 STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Workover August 1, 1988 at 0600 hrs Rig: Nabors 1ES Well: S-9I AFE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: 0600 Depth: Day: -2 Current Operation: Moving to location. STANDARD ALASKA PRODUCTION Rig: Nabors 1ES Well: S-9I Daily Drilling Report -- PBU -- Workover August 2, 1988 at 0600 hr$ AFE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current AmOunt: 0600 Depth: Day: -3 Current Operation: Rig repair. Rig repair and maintenance. i/ STANDARD ALASKA PRODUCTION Rig: Nabors 1ES Well: S-9I Daily Drilling Report -- PBU -- Workover August 3, 1988 at 0600 hrs AFE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: 0600 Depth: Day: -4 Current Operation: Rig maintenance. Routine rig maintenance. STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Workover August 4, 1988 at 0600 hfs Rig: Nabors IES Well: S-9I AFE # 160419 (Expense) 'AlE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: 0600 Depth: Day: -5 Current Operation: Rig maintenance. Routine rig maintenance. STANDARD ALASKA PRODUCTION Rig: Nabors 1ES Well: S-9I Daily Drilling Report -- PBU -- Workover August 5, 1988 at 0600 hfs AlE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: Current,Operation: Rig up derrick. Pinned derrick. 0600 Depth: Day: -6 STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Norkover August 8, 1988 at 0600 hours Rig: NABORS 1ES Nell: S-9I AFE// 160419 AFE Amount: (Expense) AFE //120734 AFE Amount: (Investment) Current Amt. 0600 Depth: 10,436' Day: 2 Current Operation: RIH. Accept rig 1800 hrs on 8-6-88. Pull BPV. Circulate well. ND tree.. NU & test BOPs to 3500 psi. Pul-l 4-1/2" tubing. Change rams to 3-1/2" and test to 5000 psi. RIH to fish slick stick. STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Norkover August 9, 1988 at 0600 hours Rig: NABOR§ 1E§ Nell: S-9I AFE# 160419 AFE Amount: (Expense) AFE #120734 AFE Amount: (Investment) Current Amt. 0600 Depth: 10,436' Day: 3 Current Operation: POH. Recover slick stick. Pressure test 9-5/8" to 2500 psi. Mill packer. POH. STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Workover August 10, 1988 at 0600 hrs Rig: Nabors 1ES Well: S-9I AFE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: 0600 Depth: 10,436' PBTD Day: 4 Current Operation: Washing out fill. ,. POH with packer tailpipe assembly. Run gauge ring. Tight spot @ 8683'. R.IH 8-1/2" bit and scraper. Work fight spots 7795', 8487', 10,275' & 10,396'. Wash out fill to 10,434'. STANDARD ALASKA PRODUCTION _ Rig: Nabors IES Well: S-9I Daily Drilling Report -- PBU -- Workover August I1, 1988 at 0600 hfs AFE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: Current Operation: 0600 Depth' 10,436' PBTD Day: 5 RIH with storm packer. Clean out to 10,436' OKB. CircUlate to clean brine. Ran 8.5" gauge ring. Ran casing corrosion log. RIH with storm packer. STANDARD ALASKA PRODUCTION Rig: Nabors 1ES Well: S-9I Daily Drilling Report-- PBU-- Workover August 12, 1988 at 0600 hrs AFE # 160419 (Expense) AFE # 120734 (Investment) AFE AmoUnt: AFE Amount: Current Amount: 0600 Depth: 10,436' PBTD Day: 6 Current Operation: Set and test storm packer, kelease from packer' POH. ND BOP & tubing spool. Replace 9-5/8" primary packoff and tubing spool. NU & test BOP. Recover storm packer. Make 8.5" gauge ring mn to 10,400'. RIH with WD packer. _ STANDARD ALASKA PRODUCTION Daily Drilling Report -- PBU -- Workover August 15, 1988 at 0600 hrs Rig: Nabors 1ES Well: S-9I AFE # 160419 (Expense) AFE # 120734 (Investment) AFE Amount: AFE Amount: Current Amount: 0600 Depth: 10,436' PBTD Day: 8 Current Operation: Rig released. Set WD packer. Ran 5-1/2" tubing. ND BOP. NU & test tree @ 5000' psi. Set plug in tailpipe. Set packer. Shifted sleeve. Changed over backside to 9.6 brine + 35 bbl diesel and tubing to diesel. Close sleeve. Test annulus 2500' psi. Witnessed by A.O.G.C.C. Set BPV. Released rig 2000 hours on 8-13-88. Production Company 900 Eo'd ~"m, on ~.oule~,,~,d PO Bo~ 19661~ An(ho~og~. AlonZO 99519.661~ ~907~ 564 5111 HOUSTON ARCO CHEVRON EXXON TEXACO TO: blOBIL REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION D~te: 8/17/88 TI: 79215 The following material Is being submitted herewith. Please acknowledge receipt by signing a copy of thls letter and returnlng it to this office: S-09I VERTILOG 08/09/88 #i 50~i0419 Atlas 5" S-09I CCL 08/12/88 #1 9950-10350 Atlas 5" Drilling - Vertilog Only Reservior Operations - Vertilog Only Discipline Engineering - Vertilog Only Rece i ved Date Alaska Oil & Gas Cor~s. C°mmis~,/ ~''~1'o4 ~ Anchorage ~ n ~ A un,f O! the O~,g;nOI .~,Ondo,.d O,I ComponF l:ou-ded ,~ (::le.elond. Ohm. ,. 1870 Alice Beck I NFORJMAT I ON CONTROL Wel I Recocds LR2-1 Slandard Alaska Production Company 900 East Benson B~ule.ord P.O. 8.o~ 196612 Anchorage, Alaska ~519-~1~ (9071 564.51 I I HOUSTON ARCO CHEVRON EXXON TEXACO TO: MO B I L REFERENCE: PHILLIPS STATE OF ALASKA GEOSCIENCES RESERVOIR ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Dete: 08/22/88 TI: 79232 The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to thls office: A-12 A-17 R-05 S-07 S-09 Collar 07/18/88 #1 7980-9600 GO 5" Collar 07/30/88 #1 10100-10300 GO 5" Collar/Per~ 07/25/88 #1 8950-9150 GO 5" Collar/Perf 07/22/88 #1 10450-10630 GO 5" Collar 07/17/88 #1 9250-9840 GO 5" Rece i ved Da t'e A u,~,! O! ,he o,,90noI $1ando,d O,I Coral)anI, founded ,- Cleveland. Ofl,o. ,n 1810 Jennifer Dietz I NFC>PJUAT I ON CONTROL Wel I Records LR2-1 '---, STATE OF ALASKA '-.~ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS · Type of Request: Abandon r-I Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time exlension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate [] Other [] Name of Operator Standard Alaska Production Company Address P. O. Box 196612, Anchorage, Alaska 99519-6612 Location of well at surface 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E At top of productive interval 519' WEL, 481' NSL, Sec. 34, T12N, R12E At effective depth 662' WEL, 341' SNL, Sec. 34, T12N, R12E At total depth 674' WEL, 330' NSL, Sec. 34, T12N, R12E 5. Datum elevation (DF or KB) KBE= 66.98 feet Unit or Property name Prudhoe Bay Unit 7. Well number 1. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 10,480 feet 9218 BKB feet 10,436 feet 9178 BKB feet Size 82' 20" x 30" 2650' 13-3/8" 10,452' 9-5/8" Plugs (measured) Junk (measured) Cemented 8 cu ft Concrete 3720 cu ft Arctic Set !1 2058 cu ft Class G 700 cu fl Class G 130 cu ft Arctic Set I s-gi (44-34-12-12) 8. Permit number 82-104 9. APl number 5 0 - 029-20771 O. Pool Prudhoe Oil Pool Measured depth BKB 110' 2678' 10,480' True Vertical depth BKB 110' 2678' 9218' Date Submit in triplicate Perforation depth: measured 10067'-10250' 10265'-10290' true vertical (Subsea) 8772'-8939' 8953'- 8976' Tubing (size, grade and measured depth) 4-1/2" L-80 tubing with tailpipe to 9874". RECEIVED JUN 1 0 1988 Alaska Oi~ & Oas Cons. Comrnission Anchorage. Packers and SSSV (type and measured depth) 9-5/8" Baker Packer at 9732'; 4-1/2" B VN at 1955'. 2. Attachments Description summary of proposal [] Detailed operations program [] BOP sketch [] 3. Estimated date for commencing operation August, 1988 4. If proposal was verbally approved Name of approver Date approved 15. I here,,~ce~y that the/~for/~oing _/i,s truen ;~,lfl/correct to the best of my knowledge -Signed ~..~~_..,~;'~,c~_ ~.V''°- Title Workover/Completions Supervisor // Commission Use Only Conditions of approval Notify commission so representative may witness IApproval [] Plug integrity [] BOP Test [] Location clearance I No. ORIGINAL SIGNED BY Approved by lflNNIE C. SMITH Form 10-403 Rev 12-1-85 Approved Copy Returned . ..--- ..-,.~ey order of _(~_'m m,; ~'~., o n e'f-/¢3 ~e commission Attachment 1 Well S-9i W0rkover Procedure Outline 1. Pull ball valve. 2. Spot sized salt pill. Set plug in tailpipe. 3. Circulate tubing to kill weight brine. 4. Freeze protect well, 5. Set blanking sleeve. 6. Set BPV. 7. MIRU. 8. Pull BPV. Circulate diesel from well. 9. Set two-way check. 10. ND tree. NU & test BOP to 5000 psig. 11. Pull 4-1/2" tubing. 12. Replace 9-5/8" secondary seals. 13. Mill packer, punch tailpipe, retrieve packer/tailpipe assembly. 14. Clean out fill to .+..10,436'. 15. RIH 9-5/8" casing scraper to 10,436'. Reverse circulate. 16. RIH 9-5/8" RTTS, set @ +9700'. 17. Test 9-5/8" casing to 2500 psi. 18. Possibly run casing corrosion log from TD to surface. 19. Run 9-5/8" gauge ring to +10,260' 20. RIH with 9-5/8" WD packer tailpipe assembly. Log into place & set @ +10,250'. 21. RIH with 5-1/2" tubing with 4-1/2" tailpipe. Set two-way check. 22. ND BOP. NU 6" tree & test to 5000 psig. 23. Set plug in tailpipe. Set packer. 24. Open sliding sleeve. 25. Change over annulus to 9.6 brine + 35 bbl diesel & tubing to diesel. 26. Close sleeve. Set BPV. 27. Clean out cellar. Release rig. B.O.P. STACK CONFIGURATION 13-5/6 IN. TRIPLE RAM STACK 5000 PS! WP DRILLING t/ ANNULAR PREVENTER 1 i ! PIPE RAMS I ! t PiP~ RAMS i I DRILLING SPOOL I 2 IN. KILL LINE I GATE GATE RAMS I J 4 IN. CHOKE LINE J GATE GATE I)AI.I.AS ARCO CttEVRON E,'C:(ON TEXACO TO: MOBIL REFERENCE: PHILLIPS GEOSCIENCES ARCHIVES SAPC CASED HOLE FINAL LOGS INDEXED STANDARD ALASKA PRODUCTION Date: TI: 05/24/88 78869 Tho following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office: A-30 B-09 C-7 E-23 E-26 F-24 G-02 N-16 R-7 R-14 S-9 Prod-F 04/30/88 #1 10650-11070 Leak Detection 05/05/88 #1 8600-8872 CCL/GR 04/24/88 #1 9450-11756 Prod-F 05/03/88 #1 11400-11625 Prod-F 05/04/88 #1 9350-9600 Pre Frac Temp/FM 04/19/88 #1 11600-12000 Prod-F 04/21/88 #1 9900-10225. WHUT 04/24/88 #1 9800-10410 Injection Profile 04/23/88 #! 9400-9998 Leak Detection 05/01/88 #1 2500-9500 Leak Detection 05/06/88 #1 Surf-9750 CaIDco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5" Camco 5"/2" Rece I ved Date ,- , v Victoria Aldridge [ NFORHAI [ ON CONIROL Wel I Records LR2-1 A un,I el ,h* ~'c~,n¢lo,d CM Co.npony Pwodu¢ tion Company 900 East Bcn~o,~ Boule~,d P 0 Bo. 19661]? Anchorage. AIo,,$.o 9~ -661~ 19071 564.5 I I I TO: REFERENCE: DALLAS ARCO CHEVRON EXXON TEXACO MOBIL PHILLIPS ¢ ~ATE OF ALASKA GEOSCIENCES ARCHIVES SAPC CASED HOLE FINAL LOGS I NDEX£D STANDARD ALASKA PRODUCTION Date: 05/18/88 78841 The following material is belng submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning It to this office.: B-24 E-8 R-4 R-15 S-9 S-9 U-2 U-6 X-3 Y-1 Collar 05/11/88 H1 9850-10630 Atlas 5" CH/CNL 05/08/88 Hi 9500-10149 Atlas 5" CH/CNL 05/07/88 #1 9100-9921 Atlas 5" Production 05/09/88 #1 ' 8950-9397 Sch 5" Noise 05/08/88 H1 0-2400 Sch 2" Spinner/Temp (Leak Detection) 05/08/88 #1 0-2400 Sch 5" Collar 05/10/88 HI 9600-10222 Atlas 5" Collar 05/10/88 H1 8320-9216 Atlas 5" CH/CNL 05/09/88 #1 11400-12032 Atlas 5" CH/CNL 05/13/88 HI 11750-12802 Atlas 5"' Rece i ye( io.,,d~:d I¢-~-Io,,H O~,n. ,,~ tRiO Victoria Aldridge INFORMAl ION CONIROL Wel I Records LR2-1 INDEXED TO: DA1.LAS ARCO CHEVRON EXXON T E,v, Ac 0 MOBIL PHILLIPS STATE OF' ALASKA STANDARD ALASKA PRODUCTION Date: 04/28/88 Ti: 78765 REFERENCE: SAPC FINAL DATA - PRESSURE SURVEY DATA The following material Is being submitted herewith. Please acknowledge rece pt by signing a copy of fhls letter and returning It to this offlce:: F-24 Static 04/18/88 GO G-12 Static Gradient 04/22/88 Camco G-25 " " 04/22/88 Camco G-30 " " 04/21/88 Camco S-8 " 04/17/88 GO ~S~9 e~ " Gradient 04/20/88 Camco S-12A " 04/17/88 GO S-13 Static Gradient 04/20/88 Camco S- 17 Camco Static Gradi~/14/88 D Alaska (Iii & Gas Coris. Commission ~,ece I Anchorage Victoria Aldridge ~NFO~HAI ION CONIRO[ Date Wel I Records LR2-1 Standa;d Alaska Pwoduction Cempan¥ ~,~ 900 EO$! I~en$on Boulevmcl P.O. 8o~ 196612 Ancho,oge, Alaska 99519.6612 (907! 564-511 I INDEXED . DALLAS ARCO CHEVRON EXXON TEXACO Dote :. ,02 / 02 / 87 TO: MOBIL T!: 77694 PHILLIPS STATE OF ALASKA GEOSCIENCES STANDARD ALASKA PRODUCTION REFERENCE: SAPC CASED HOLE FINAL LOGS , The following material Is being submitted herewith. Please acknowledge receipt by signing o copy of this letter and returning It to this office: ~ A-35 ~ B-19 '---- F-5 ----F-5 ~ G-4 ~--~ G-32 -~ H-2 ~ H-2 -- X-11 --- H-15 ~-X-l. 1 CNL/GR 11/02/86 #1 9300-9922 Sch 5" Spin/Temp 0!/21/87 #1 8400-9754 .Camco 5" PFC 11/20/86 #1 9340-11332 Dres 5" PFC 12/02/86 #2 10550-11350 Dres 5" WOPITS 01/22/87 #1 10000-10300 ' Camco 5,, PFC 11/16/86 #1 8350-9544 Dres 5" Cont. Flow 12/28/86 #1 8700-9050 GO 5" ltydro 12/28/86 #1 8700-9050 GO 5" CCL/Perf. 12/19/86 #1 9150-9450 GO 5" FloPetrol Petrol 01/02/87 #1 100-11630 Sch 5" Injection Profile 01/24/87 #1 100Q0-10600 Camco 5" Injection Profile 01/25/87 #1 9950'10350 Camac 5" Injection Profile 01/18/87 #1 9000-9600 Camco 5" Rece i ved Date A unit al the original Slondard (~1 Company Founded in Cle,elond. C~'o. ,n 1870 Anchorage Victoria Aldridge I NFO~MAT I ON CONTRC~ Wel I Records LR2-1 SOHIO ALASKA PETROLEUM COMPANY 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 November 12, 1985 Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Gentlemen' Mr, C V Chatterton Well S-9 (44-34-12-12) PBU Enclosed in duplicate, are the follouing forms for the above-named well- 1. Form 10-407, Completion Report 2. Form 10-403, Sundry Notices and Reports on ¥~ells 3. Form 10-404, lqonthly Report of Drilling and Workovers Very truly yours, MDM/~H/dg/1026N Enclosure SOHIO ALASKA PETROLEUM COMPANY M. D. Martin Senior Petroleum Engineer cc' T. N. Tyler Well Records Well File #17 oil & Gas Cons. ~nchO~ag~ STATE OF ALASKA ~ ALASKA U~TL AND GAS CONSERVATION COM-'d'~VIISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG - ,, 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED []SERVICE m Water Tn~ie~-i:or 2. Name of Operator 7. Permit Number SOHIO ALASKA PETROLEUM COMPANY 82-104 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 so~329-20771 4. Location of well at surface 9. Unit or Lease Name 1635'EWL, 1642'SNL, Sec. 35, T12N, R12E, UPM Prudhoe Bay Unit At Top Producing Interval (top Sag R. SST) lo. Well Number 519'WEL, 481'NSL, Sec. 34, T12N, R12E, UPM S-9 (44-34-12-12) At Total Depth 11. Field and Pool 674'WEL~ 3301NSL~ Sec. 34, T1 2N, R1 2E, UP~I 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay KBE - 66.90' A:ISLI ADL 28258 Prudhoe 0il Pool 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 116. No. of Completions 7/5/02 7/19/82 7/25/82 feetMSLI One 17. Total Depth (MD+TVD) 18.Plug Back Depth (ME~TVD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost 10430I!ID 9218'TVD 10436'MD 9178'TVE YES[~ NOD 1955 feetMDI 1870' 22. Type Electric or Other Logs Run DIL/FDC/CNL/SP/GR/CAL, DIL/BHCS/GR/SP, CBL/VDL/GR/CCL - 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"X30I' Insulate( Conduct( r Surfade ll01 36" 8 cu. yd$, c0nc 'ere 13-3/8" 72# L-80 Surface 2678' 17-1/2" 3720 cu. ft. Arcti(:set II 9--5/8" 47# L-80 Surfade 10480' 12-1/4" 2058 cu. ft. Class G' (lst stage) 700 cu. ft. Class G (2nd sta~e 130 cu. ft. Arcti(:set I (3rd stage 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD TVDss .4-1/2" 9,074' 9732' Too: 1 0067 '8772' Prudhoe 0il Pool - Bottom: 10290'8976' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10067' - 10250'BKB (8772' -8939'TVDss) 10205' - 10290'BKB (0953' - 8976'TVDss) _ ,. . 27. PRODUCTION TEST Date'First Production I Method of Operation (Flowing,.gas lift, etc.) January 19, 1984I Water n.iection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-M~F WAT~:R-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ~ I · Flow Tubing Casing Pressure CALCULATED ~! OIL-BBL GAs-McF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR.RATE 28. cORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. A~ask,'a Oii & Gas Co~$. Oommis~io~ Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. ~KB Subsea Sao ,River SST 9941 I Shublik 9976' o=o~, Ivishak 10062' S758' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best (~f my knowledge Sign Title Sr. Petrol eum Date _ , INSTRUCTIONS Geheral' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in. item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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 STATE OF ALASKA ALASKA O'lT2 AND GAS CONSERVATION COI~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL [] OTHER [] 2. Name of Operator 7. Permit No. SOHIO ALASKA PETROLEUM COMPANY 82-104 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20771 4. Location of Well At Surface' 1635'EWL, 1642'SNL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AHSL 6. Lease Designation and Serial No. ADL 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-1 2-1 2) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other [] [] [] 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following additional interval was perforated October 12, 1985 using Dresser Atlas 3-1/8" carrier guns at 4 spf. A lubricator was installed and tested to 3500 psi on all work. 10265'-10290' BKB (Ref. BHCS/GR, 7-18-82) An SSSV was set and tested in the ball valve nipple at 1955'. RECEIVED NOV 1 1985; /~aska Oil & Gas ~s. Commisslor~ Anchorage 1~. I hereby certify that the foregoing is true and correct to the best of my knowledge. I The space below for Commission use Date Conditions of Approval, if any: By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA Oi'E AND GAS CONSERVATION COI~'~ISSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS . Drilling well [~ Workover operation [] 2. Name of operator SOHIO ALASKA PETROLEU?-~ COHPANY ~. Address P.O. Box 196612, Anchoraqe, Alaska 99519-6612 4. Location of Well at surface 1635'EWL, 1642'SNL, Sec. 35, TI2N, R12E, UP.H 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 66.98' ^HSL ADL 28258 7. Permit No. 82-1 04 8. APl Number 50- 029-20771 9. Unit or LeaSe Name Prudhoe Bay Unit 10. Well No. S-9 (44-34-12-12) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool For the Month of. October ,19 85 i12. Depth at end of mort[h, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 16. DST data, perforating data, shows of H2S, miscellaneous data See attached Alaska 0il & Gas Cons, Commission Anchorage lf. I hereby certify that the foregoing is true and correct to the best of my knowledge. LE Sr. Petroleum Engineer DATE ~(IOTE--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Rev. 7-1-80 Submit in duplicate PERFORATING DATA - Well S-9 (44-34-12-12) PBU October 12, 1985- Rigged up Dresser Atlas and perforated the following additional interval using 3-1/8" Carrier guns at 4 spf' 10265' - 10290' BKB (Ref, BHCS/GR, 7-18-82) October 13, 1985- Put well on water injection RECEIVED Alaska 0{t & Gas Cons. Commission Anchorage INDEXED ~o: S FO/UNIT/STATE: SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TEXACO (-Mar a t hon) MOB IL PHILLIPS STATE ~ BPAE (Transmittal Only) 31 11 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: T#: 10-04-85 76474 REFERENCE: SOHIO FINAL DATA - PRESSURE SURVEY DATA The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- ~ R-24 V/ ~- R-24 ~ ~'~ R-24 U/ 6-08-85 6-08-85 5-15-85 4-18-85 4-20-85 Flowing Gradient Pressure Survey Sch Flowing Pressure Survey Sch Flowing Pressure Survey Sch Flosing Pressure Survey Sch BHPD S ch RECEIVED DATE SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CIIEVRON EXXON TO SFO/UNIT/STATE: TE~OkCO (-.~iara thon) MOBIL PHILLIPS STATE OF AK BPAE 31 1 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 09/13/85 T#: 76430 ~ M_12~' ~ -~ M_14~ -~xJ N-5~ ~'-- N_ 21~ ~ -o R_7~~- "-,~ R_i 8.~- -x "~R-24~- ~ xo S_9~ x ~ S_ll~- ~ -o U_9.~ REFERENCE: SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- GCT Gyro Survey 07/18/85 #1 SURF-9921 Sch 5" EPL-Injection Profile 01/28/85 #! 9650-10310 Sch 5" EPL-Injection 02/25/85 #1 9700-10400 Sch 5" EPL 02/27/85 #1 10100-11000 Sch 5" EPL 03/04/85 #1 10150-10650 Sch 5" GCT Gyro Survey 05/28/85 #1 42-11312 Sch 5" EPL 03/06/85 #1 9500-10320 Sch 5" Spinner-Temp. 08/25/85 #1 9100-10300 Camco 5" EPL-POST-FRAC 06/09/85 #2 8600-9360 Sch 5" EPL 04/13/85 #1 9900-10388 Sch 5" EPL 04/15/85 #1 9200-9600 Sch 5" EPL 07/08/85 #1 10900-11300 Sch 5" RECEivED OAT~ Victoria Aldridge LR2-1 Technical Documentation Records Management SOHIO ALASKA PETROLEUM COMPANY · 900 EAST BENSON BOULEVARD ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 P.O. BOX 6612 ANCHORAGE, ALASKA 99502-0612 September 3, 1985 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention' Mr. C.V. Chatterton Wells R-20, S-6~'S-9~ S-ll~ and S-14 PBU Gentlemen' Enclosed in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above named wells. These contain our proposals to perforate additional intervals in these wells. MDM :~~~kkm 09038~: 0662N Enclosures Yours very truly, Michael D. Martin SAPC Petroleum Engineer RECEIVED SEP 0 9 198.5 cc' T. N. Tyler, MBg-2 Well Records (LR2-1) Well File #17 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COI;t~i~ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL'E] OTHER [] 2. Name of Operator SOHIO Alaska Petroleum Company 3. Address P. O. Box 6612, Anchorage, Alaska 99502 4. Location of Well At Surface' 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 12. 6. Lease Designation and Serial No. ADL 2R?.~8 7. Permit No. 82-104 8. APl Number 5o-029-20771 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-o (44-34-! 2-! 2 )PBU 11. Field and Pool Prudhoe Bay Prudhoe O~! Poe! Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate J~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following additional intervals will be perforated in September, 1985, 10265' -10290' BKB (Ref. BHCS/GR, 7-18-82) $~b.c~tuent Wc~-k RepoSed RECEIVED Alaska Oil & Gas Cons. C0rnmiss/0n Anchorage ig" I hereby certify that the foregoing is true an~rect ne ~VThe space below for Commission use to the best of my knowledge. Title SAPC Petroleum Engineer Conditions of Approval, if any: Approved by {Rllillltt SIll[8 13¥ 1.8NNI[ C. $1tiTH ApprOV~:~ By Order of COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To- SFO/UNIT/STATE: TE;LACO (-Marathon) biOB IL PHILLIPS STATE ,.OF AK ! BPAE CENTRAL FILES (CC# ' s-Transmittal Only) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 12/5/84 CC#: 75911 REFERENCE ~HIO CASED HOLE FINAL LOGS he following material is being submitted herewtth. Please acknOwledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/State: M-8Y TDT-M 8/8/84 #2 10450-11659 Sch 5" S-9~'. EPL 9/3/84 #1 3000-3250 Sch 5" Y-18J EPL 9/1/84 #1 10975-11200 Sch 5" U~West End Test Well Temp. 7/30/84 #1 9050-9695 Sch 5" S-16~'GR in Casing 7/31/84 #2 9550-9900 Sch 2"/5" ! !/84) R[C[ ~v[ro [')All Victoria ^ldridge TP1-5 G0~iimiSSi0~eve lopmen t Geology Cons. .' ' SOHIO ALASKA PETROLEUM COMPANY S¥0 ARCO CHEVRON EXXON GETTY TO~ SFO/UNIT/STATE: (-Marathon) MOBIL PHILLIPS · " STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmit tal Oniy) 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 Date: 11/15/84 CC#: 75875 REFERENCE: SO>F~ CASED HOLE FINAL LOGS /efollowing material is submitted herewith. Please acknowledge receipt by signing a being copy of this letter and returning it to this office:-- R-10 S-9 Cont. Flow Survey 10/17/84 #1 10000-10400 GO 5" Temp. Log 10/11/84 #1 0-1950 GO 5" (4~82) RECEIVED DATE 19 Victoria. ~ldridge Development Geology Well Records . TP1-5 SOHIO ALASKA PETROLEUM COMPANY 3111 "c" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 October 10, 1984 Alaska Oil & Gas Conservation C~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Wells M-i, M-2, M-3, M-12, M-13, M-14, R-2, R-5, R-7, R-20 S-6, S-9, S-11, S-14, PBU Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our subsequents to converting the wells from oil wells into water injection wells. Yours very truly, Enclosures J. D. Hartz Well File #17 ~trict Petroleum Engineer (Acting) RECEIVED oc'r 1 21984 Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA q..~. AND GAS CONSERVATION cO, /IlSSION SUNDRY NOTICES AND REPORTS N WELLS 1. DRILLING WELL [] 2. Name of Operator COMPLETED WELL 7. Permit No. OTHER [] Sohio Alaska Petroleum Company 3. Address P.O. Box 6612, Anchorage, Alaska' 4. Location of Well At SUrface: 1635' EWL, 99502 1642' SNL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 12. 35, T-i2N, R12E, UPM I 6. Lease Designation and Serial No. ADL 28258 82-104 8. APl Number 50- 029-~20771 9. Unit or Lease Name Prudhoe Ba_v Unit 10. Well Number $-9 (44-34-12-12) PBU 11. Field and Pool Prudhoe BaY. prud/aoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-497 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). This well was converted from a Prudhoe Bay Production well into a produced water injection well for .1984 P.W.I. water flow evaluation on August 19, 1984. Water was injected through the following perforations at 4 s.p.f. 10067'--10250' BKB RECE iVED OCT 1 2 Alaska 0ii & Gas Cons. Oommissio~ g,. I hereby certify that the foregoing is true and correct to the best of my knowledge. ed (~~ ~~ Title District Petroleum Engineer ~he spF;e~ow ior Commission ~se ~J Condi¢o~s of Approval, if any: V By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 September 10, 1984 Alaska Oil & Gas Conservation Co~mtission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Well S-9 (44-34-12-12) PBU Gentleman: Enclosed, in duplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our subseqUent to performing scale inhibitor treatment on this well. JAB/~/pjw Enclosures cc: J. D. Hartz Well File #17 Yours very truly, strict Petroleum Engineer (Acting) RECEIVED S EP 1 1 Alaska Oil & Gas Cons. Cemmission Anchorage STATE OF ALASKA ALASKA ~.~- AND GAS CONSERVATION C(~_~MiSSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL I-I 2. N~m~qf Oper~ator, ~onzo azasKa Petroleum Company 3. Address P 0 BOX 6612, Anchorage, Alaska 99502 4. Location of Well Ak Surface: COMPLETED WELL ~] 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 12. 7. Permit No. 82-104 8. APl Number s0- 029-20771 9. Unit or Lease Name I -6. Lease Designation and Serial No. ADL 28258 OTHER [] Prudhoe B~y S-9 (44-34-12-12) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) {Submit in Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing !-'1 Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other ~ Pull Tubing [] Other ~.. Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following interval in this well was_ treatedwithl70 barrels of DiAmmonium EDTA solution on August 12, 1984. The treatment'was conducted through a bullhead method. The SSSVwas removed prior to the trea~tand reset after the job at 1955'. 10067'-10250' BKB (Ref. BHCS/G~, 7-18-82) 'RECEIVED SEP 1 1 198 Alaska 0il & Gas Cons. Commission Anchorage 14..~1 hereby certify tha, t the foregoing is true and correct t,o the best of my knowledge. The space be,~o;Commission' us; Condit~~Approval, if any: By Order of Approved by COMMISSIONER the Commission Date ~ (~/~ Date Form 10,~03 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON TO- SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS BPAE (Transm±ttal Only) CENTRAL FILES (CC#' s-Transmittal 0nly) REFERENCE: 3111 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 8'28~84 CC#: 75665 SOHIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:- N-5 / Spinner · 8-1,2,3-84 #1 8950-10635 Camco S-9 / DFT 8-11-84 #1 9900-10250 Camco S-14/'-- DFT 8-10-84 #1 10250-10880 Camco S-14 ~" Spinner 8-10-84 #1 10250-10880 Camco (4/82) RECEIVED DATE Carolyn Bishop Development Geology' Well Records SOHIO ALASKA PETROLEUM COMPANY SF0 ARCO CHgVRON · EXXON 31 ] i -.r',~ · 51[t[[] AN(:rtOI~AG[. ALASKA I£LEPHONE [907! 26.5 0000 MAIL POUCH 6-612 ANCHORAGE. ALASKA 99.502 '~o SFO/UNIT/STATE- (-Marathon) GETTY blOB I L PHILLIPS BPAE (Transmittal Only) CENTRAL FILES(CC#'s-Transmittal Only) Da te CC# ' 75641 REFERENCE iAS E_____~D FINAL LOGS HOLE lng material is being submitted herewith. Please acknowledge receipt by signing a s letter and returning it to this office:- -~M-3 ~ M-14 "~N-8 ~R-22 ~---S-9 ~West End Test Well ..' DIFF. TEMP. LOG 7-25-84 ~1 ,,~16400-10984 GO Diff. Temp. Log 7-24-84 ~1 9950-10800 GO Diff. Temp. Log 7-28-84 MI 9400-9960 GO Diff. Temp. Log 7-20-84 ~1 9500-10250 GO Diff. Temp. Log 7-29-84 ~1 10400-10800 GO Diff. Temp. Log 7-21-84 ~t 9800-10390 GO Diff. Temp. Log 7-16-84 ~1 9600-9696 GO 11 (4/82) RECEIVED DAT[ Carolyn Bishop Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 August 2, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gent 1 emen: Wells M-l, M-13 ,. R-5, S-6, S-9, and S-14 Enclosed, in triplicate, are Forms 10-403~ Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perform scale inhibitor treatments on these wells. Enclosur es cc: J. D. Hartz Geology Well File ~17 Yours very truly, ~is~;i~[ Petroleum Engineer RECEIVED AUG 0 6 191 Alaska Oil & Gas Cons. Commission Anchorage ALASKA r",. AND GAS CONSERVATION Cr~{MISSION SUNDRY I r,.PTICES AND REPORT --ON WELLS DRILLING WELL COMPLETED WELLx~:I OTHER [] 2. Name of Oparltor Sohio Alaska Petroleum Company 3. Addre~ Pouch 6-612, Anchorage, AK 99502 4. Location of Well At Sur face: 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 6. Lease Designation and Serial No. ADL 28258 7. Permit'No. 82-104 8. APl Number so- 029-20771 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-12-12) PBU 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate ['-] Alter Casing [] Perforations r-I Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other .J~ Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment ~ee 20 AAC 25.105-170). The following interval in this well will be treated with l70 . barrels of DiAmmonium EDTA solution in August, 1984. The treatment will be conducted through a bullhead method. The SSSV will be removed prior to the treatment and reset after the job at 1955 ' . 10067'-10250' BKB (Ref. BHCS/GR, 7-18-82) RECEIVED AUG 0 61~ A~k~ Oi~ & G~s ¢on~. Oommi$~ion Anchorage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ned ~t~.~ Title Dis%rict Petroleum Engineer Date. I:)RIG'NAL SIG#EB RY /Oll/ilE C. SMITll Approved by. COMMISSIONER Approved Copy ~eturned i By Order of the Commission Date Form 10-403 Rev. 7-14~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON To: SFO/UNIT/STATE: GETTY (-Marathon) MOBIL PHILLIPS .: . STATE OF AK BPAE (Transmittal Only) CENTRAL FILES (CC#' s-Transmittal Only) 31 I 1 "C" STREET ANCHORAGE. ALASKA TELEPHONE (907) 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 7/27/84 CC#: 75572 REFERENCE: S~O CASED HOLE FINAL LOGS T,he following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- C-20'''' Ct~/GR 6/30/84 #1 11500-12475 Dres 5" S-6, CNL/GR 6/28/84 #1 9800-10693 Dres 5" S-Ii CNL/GR 6/27/84 #1 9000-9909 Dres 5" S-14" CNL/GR 6/25/84 #1 9985-11085 Dres 5" S-9 '' Spinner 7/7/84 #1 9950-10350 Camco 5" West End Test Well~- Basket Flowmeter 7/12/84 .#1 9660-9697 Camco West End Test Well Basket Flowmeter 7/14/84 #1 9061-9698 Camco (4182) RECEIVED DATE Victoria Aldridge TP1-5 Development Geology Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 25, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well S-9 (44-34-12-12) PBU Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our amended proposal to convert it frcm an oil well into a water injection well. Enclosures cc: J. D. Hartz Well File #17 RECEIVED JUL 3 0 1984 Alaska 0il & Gas Cons. Commission Anchorage STATE OF ALASKA ALASKA ,_._.._ AND GAS CONSERVATION CC~_~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL OTHER [] 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum ~y 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, AlaSka 99502 50-029-20771 4. Location of Well At Surface: 1635' ~v~, 1642' SI~, Sec. 35, T12N, R12E, L~M 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 6. Lease Designation and Serial No. ADL 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-12-12) PBU 11. Field and Pool Prudhoe Oil Pool 12. (Submit in Triplicate) Perforate [] Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other ~ Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). With reference to the previous Sundry Notices dated~: November 22, 1983, and June 25, 1984 for the perforation of S-9 in. the 9-5/8" casing, it is intended to convert this Prudhoe Bay production well into a produced water injection well for 1984 P.W.I. water' flow evaluation. Water will be-injected through perforations (4SPF) at 10067'-10250' BKB RECEIVED JUL 3 0 i984 1 oing is true and correct to the best of my knowledge. Sig~ed_/~/ ..~ 3 ~ ¢%.~ TitleDiStrict Petroleum Engineer Date 7/~[~ Th~(ace bel~ fo, r C~..mission use Con~0ns of Approval, if any: ~ ~proved Cop'.,. ~;eturned, By Order of Approved by. COMMISSIONER the Commission Date Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY 'ro: SFO/UNIT/STATE: (-Marathon) SFO ARCO CHEVRON EXXON GETTY MOBIL PHILLIPS :~ -4.~ ~.-2 :~2~_ _~-~ BP~ (Transmittal 0nly) , CENT~L FILES (CC~/'s - Transmittal Only) 311 I "C" STREET ANCHORAGE, ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-61 2 ANCHORAGE, ALASKA 99502 Date: 7-19-84 CC#: 75540 REFERENCE: SO~/~ FINAL ,_DATA - PI{ES. SURE .SURVEY DATA ~,. ~n-~. ,h;,~/q'he, f°ll°wing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- D-6 M-14 R-22 S-9 PBU & Data 7-6-84 Sheet PBU& Data Sheet6.26-84 Static Gradient7-14-84 · PBU & DATA 7-7-84 SHEET Otis GO Camco Camco (4/82) RECEIVED DAT( .__ Ca~oi~ ~±shop AlasKa Oil & G~s ~-:,3ns. Co~?.jnts,~m, ~ 'Development Geology ~ 9'~:~: ~°~a~ Well Records SOHIO ALASKA PETROLEUM COMPANY 3111 ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 20, 1984 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attnetion: Mr. C. V. Chatterton Well S-9 (44-34-12-12) PBU Enclosed, in duplicate, are the following forms for the above-named well. 1. Form 10-407, Cc~pletion Report; 2. Form 10-403, Sundry Notices and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. GJP/~/pjw Enclosures cc: J. D. Hartz Well File #17 Distr~ct PetrOleum Engineer RECEIVED JUL2 7 !Bg4 Alaska Oil & Gas Cons. Anchorsge STATE OF ALASKA ALASK~.~IL AND GAS CONSERVATION C~ _~":¢IMISSION ~ WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50_029-20771 4. Location of well at surface 9. Unit or Lease Name 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, OPM Prudhoe Bay Unit At Top Producing Interval (top Sag R. SST) 10. Well Number 519' WEL, 481' NSL, Sec. 34, T12N, R12E, UPM S-9 (44-34-12-12) At Total Depth 11. Field and Pool 674' WEL, 330' NSL, Sec. 34, T12N, R12E, OPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe oil Pool KBE = 66.98' AMSL ADL 28258 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 15. Water Depth, if offshore 16. No. of Completions 7/5/82 7/19/82 7/25/82 feet MSL one 17. TotalDepth(MD+TVD) 18. Plug Back Depth (MD+TVD) 19. DirectionalSurve¥ I 20. Depth where SSSV set I 21. Thickness of Permafrost 10480'MD 9218'TVD 10436'MD 9178'TVD YES[~] NO~] 1955 feetMD 1870' 22. Type Electric or Other Logs Run DIL/FDC/CNL/SP/GR/CAL, DIL/BHCS/GR/SP, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulate~Conductoz Surface 110' 36" 8 cu._yds, concrete 13 3/8" 72# L--80 Surface 2678' 17 1/2" 3720 cu.ft. Arctics~t II 9 5/8" 47# L-80 Surface 10480' 12 1/4" 20.58 cu.ft. Class G (!st stage)_ 700 cu,ft, Class G (_2nd stage) 130 cu,ft, A_rctics~t I (3rd stage) 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) MD TVDss --~' 4 1/2" 9874' 9732' Prudhoe Oil Pool - Top: 10067' 8772'. Bottom: 10250" 8939_' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10067' - 10250'BKB (.8772' - 8939'TVDss)_ 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) January 19, 19 84I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD I~ I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITy-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED JUL2 lcJ 4 Alask~ Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. . . · GEOLOGIC MARKERS " FORMATION TESTS NAME Include interval tested, pressure data, all fl.uids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. BKB Subsea Sag River SST. 9941' 8658' Shublik 9976 ' 8689 ' Ivishak 10062 ' 8768' ./_./.', . ' I hereby ce~tif~at the foreTng is true and correct to the best of my knowledge . Sign~ // ~ ~-~ / G. J. ~lisga ~l - Enqineer INSTRUCTIONS General' This form is designed for Submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water.disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not Otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23' Attached supplemental records for this well should show the details of any multiple stage 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". Fnrm 1 O-407 SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 July 20, 1984 Alaska Oil & Gas Conservation~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Cha%%erton Gent lemen: Well S-9 (44-34-12-12) PBU Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named well. This contains our proposal to convert it from an oil well into a water injection well. GJP/~/pjwr Enclosures cc: J. D. Hartz Well File #17 RECEIVFb STATE OF ALASKA ALASKA ~_~. AND GAS CONSERVATION C,..~IMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum ~y 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 s0-029-20771 4. Location of Well At Surface: 1635' ~qL, 1642' SNL, Sec. 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 12. 35, T12N, R12E, UPM I 6. Lease Designation and Serial No. ADL 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-12-12) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations ~] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other I'-I Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following additional interval was peforated July 4, 1984, using Schlumberger 2 7/8" Hyperdomes at 4 spf. A lubricator was installed and tested to 3500 psi on all work. 10138'-10250' BKB (Ref. BHCS/GR, 7-18-82) An SSSV was set and tested in the ball valve nipple at 1955'. N~st~ 0ii & Gas Cons. C0mmissi0-n A~ch0mge Sig~=d~/,/~J~~~ ~~'"'~/ Title District Petroleum Engineer The spa mission use "' C o n d i t i o~b~ ~°~Vj:r~'vC~l~, i ~ n y: By Order of Approved by. COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1 ~0 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION CO~¥JIlSSION MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS ..,. , I1, Drilling well [] Workover operation [] / 2. Name of operator 7. Permit No. Sohio AlaSka Petroleum Oampany 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20771 4. Location of Well at surface 1635 ' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 6. Lease Designation and Serial No. ADT, 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. S-9 (44-34-12-12) 11. Field and Pool For the Month of. JUly ,19 84 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run REC JUL 3 6. DST data, perforating data, shows of H2S, miscellaneous data See Attached Alaska Oil & Gas Cons, Corr Anchorage I17. I herebylcer~if~regoing is true and correct to the best of my knowledge. ~' ~~ ,, ~/ District Petroleum Engineer;' ' NOTE--~eport on thi~ form is requ~d for each calendar month, regardless of the status of operations, and must be filed in--~u;licate with the Alaska Oil and G~s Conserv~tlZon Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate PERFORATING DATA - Well S-9 (_44-34-12-12) PBU July % 1984: Rigged up Schlumberger and perforated the following additional interval using 2 7/8" Hyperdomes at 4 spf: 10138'-10250' BKB (Ref. BHCS/GR, 7-18-82) Put well on production. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 June 22, 1984 Alaska Oil & Gas Conservation C~ssion 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Wells M-3, M-12, M-13, N-5, N-8, S-9: Gentlemen: Enclosed, in triplicate, is Form 10-403, Sundry Notices and Reports on Wells, for the above-named wells. These contain our proposals to perforate additional intervals in these wells. District Petroleum Company G/P/~/pjw Enclosures J. D. Hartz Geology Well File #17 cc: RECEI\/ ' JUN 2 7 1984 STATE OF ALASKA ALASKA'i:~L A-ND GAS CONSERVATION CONIMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL[] COMPLETED WELL OTHER 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, AK 99502 50- 029-20771 4. Location of Well At Surface: 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-12-12) 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. KBE = 66.98' AMSL I ADL 28258 12. Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 11. Field and Pool Prudhoe Bay Pr udhoe Oil Pool [] [] [] NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~ Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following additional interval will be perforated in July, 1984, using Schlumberger 2-7/8" Hyperdomes at 4 s.p.f. A lubricator will be installed and tested to 3500 psi for all well work. 10138'-10250' BKB (Ref. BHCS/GR, 7-18-82) Subsequent Work Beported on Form An SSSV will be set and tested in the 1955'. · I here rtl regoing is true Signe I ~ The Sl~C; be;ow for ~o~"i"r~ission ;s~ '--. :f ConditionsofAppr~, any: a0d correct to the best of my knowledge. District Petroleum l~gineer Title Approved by BY LI~HHIE C. SlitlTfl Approved Copy Returned By Order of COMMISSIONER the Commission Date Form 10403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 31 I 1 "C" STREET ANCHORAGE, ALASKA TELEPHONE {907! 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 To: SFO/UNIT/STATE: (-Mar a tho n) GETTY MOBIL PHILLIPS STATE OF AK BPAE (Transmittal Only).. CENTRAL FILES(CC#'s-Transmittal only) Date: 4-9-84 CC#: 75195 //0EFERENCE: HIO CASED HOLE FINAL LOGS The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: R- 9 TDT-M S-9 Compl. Record West End Test Well TDT-M " " " dompl. Record " " " EPL .. 2-12-84 #1 1-19-84 #1 3-3-84 #1 3-6-84 #1 9000-9777 Sch 5" 9620-10392 Sch 5'~ 9300-9901 Sch 9300-9876 Sch 2-20-84 #1 Sch 5" (4/82) RECEIVED DATE Carolyn Bishop '~ ' ::!';~:: ::%'-'qD ev elopm en t Geology Well Records SOHIO ALASKA PETROLEUM COMPANY SFO ARCO CHEVRON EXXON 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907l 265-0000 MAIL-: POUCH 6-612 ANCHORAGE, ALASKA 99502 ~o. S FO/UNIT/STATE: (-Marathon) GETTY Date:@ 7-~P7-84 MOBIL Trans. f!: PHILLIPS CCI!: 75076 · ;. ;o. ~t.-~,~ BPAE (Transmittal Only) CENTRAL FILES (CCI!'s - Transmittal Only) REFERENCE: SOHI~O~F-INAL DATA- PRESSURE SURVEY DATA ~/~/'~e ~ollowing material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- E-18 F_2~.'' F_2 G-3 H_8j' N-13 S-2 ~l S-9/ S-ii S-13.~ S-14 Getty St. PBU & PBU Data Sheet PBU Data Sheet Flowing Gradient P'RU & PBU Data Sheet Static Gradient PBU & PBU Data Sheet Static Gradient STatic Gradient Static Gradient Static Gradient Static Gradient #1'~/ Static Gradient 1-12-84 Camco 1-20-84 1-19-84 Otis 1-30-84 GO 1-30-84 Otis 1-25-84 GO 1-28-84 GO 2-1-84 Otis 1-20-84 GO 1-21-84 Camco 1-20-84 GO 1-28-84 Otis n[ C£1VED DATE Carolyn Bishop Development Geology - :?-;"-'~:';T':?~ e 11 Records SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET, ANCHORAGE, ALASKA TELEPHONE (907) 561-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502-0612 February 6, 1984 Alaska Oil & Gas Conservation Commissicn 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Gentlemen: Well S-9 (44-34-12-12) Enclosed, in duplicate, are the follc~ing forms for the above-named ~ell. 1. Form 10-407, Completion Report; 2. Form 10-403, Sundry Notice and Reports on Wells; 3. Form 10-404, Monthly Report of Drilling and Workovers. G/P/~/pjw Enclosures cc: J. D. Hartz We]] File #17 ~DG '[1 J~~ old'Engineer · ~ STATE OF ALASKA WEL '"L ALASK~,...-ClL AND GAS CONSERVATION O...,~MISSION COMPLETION OR RECOMPLETIONREPORT AND LOG 1. Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Ccmpany 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20771 4. Location of well at surface 9. Unit or Lease Name 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM Prudhoe Bay Unit At Top Producing Interval top Sag R. SST 10. Well Number 519' WEL, 481' NSL, Sec. 34, T12N, R12E, UPM S-9 (44-34-12-12). At Total Depth 1 1. Field and Pool 674' WEL, 330' NSL, Sec. 34, T12N, R12Em UPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 66.98' AMSLI ADL 28258 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 7/5/82 7/19/82 7/25/8 2I feet MS LI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10480'MD 9218 'TVD 10436 'MD 9178 'TV~ YES [~ NO []I 1955 feet MD 1870 ' 22. Type Electric or Other Logs Run D IL/FDC/ElqL/SP/GR/CAL, DIL/BHCS/GR/SP, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESIZE CEMENTING RECORD AMOUNT PULLED 20"x30" rnsu!atedConductorI Surface 110 ' 36" 8 cu.yds, concrete 13 3/8" 72# L-80 Surface 2678' 17 1/2" 3720 cu.ft. Arctics_=t II 9 5/8" 47~ L-80 Surface 10480' 12 1/4" 2058 'cu.ft. Class 6 (lst stage) 700 cu..ft. Class 6 (2nd stage) 130 cu. ft. Arotics-=t I (3rd stage) 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) MD r~mv-Dss SIZE DEPTH SET (MD) PACKER SET (MD) -- 4 1/2" 9874' 9732 ' Prudhoe Oil 'Pool Top: 10067' 8772' Bottc~n: 10138' 8837' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 10067'-10138' BKB (8772'- 8837" TVDss) 27. PRODUCTION TEST Date First Production M_e~.hod of Operation (Flowing, gas lift, etc.} ' January 19, 1984 ~'±owLng Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATERoBBL CHOKE SIZE IGAS-OILRATIO TEST PERIOD Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED . A~.sk~ 0ii & Gas Cons, C0rnmissio~ A~choraOo Submit in duplicate Form 10~407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. GEOLOGIC MARKERS NAME Sag River SST. Shublik Ivishak MEAS. DEPTH TRUE VERT. DEPTH BKB 9941' 9976' 10062' Subsea 8658" 8689" 8768' 30. FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, - GOR, and time of each phase. 31. LIST OF ATTACHMENTS 32/ I here t is true and correct to the best of my knowledge )/C District Petroleum Engineer Sig~'~ ~:~ ~'-~J Title Date INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in~situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced,' showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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 ~ ~' STATE OF ALASKA ALASKA'-~,~. L AND GAS CONSERVATION C(.,...~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 2. Nam~ of Operator 7. Permit No. Sohio Alaska Petroleum Cc~pany 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 9_c-502 50- 029-20771 4. Location of Well At Surface: 1635' EWL, 1642' SNL ,Sec. 35, T12~ ,R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) __ KBE = 66.98' AMSL 12. I 6 . Lease Designation and Serial No. ADL 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-12-12) 11. Field and Pool Prudhoe 0il Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data NOTICE OF INTENTION TO: SUBSEQUENT REPORT OF: (Submit in Triplicate) (Submit in Duplicate) Perforate [] Alter Casing [] Perforations [~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulling Tubing [] (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). -. ~.. The following interval were perforated January 19, 1984, using Schlumberger 2 7/8" HyperdGmes at 4 spf. A lubricator was installed and tested to 3500 psi cn all well work. 10067'-10138' BKB (-Ref. BHCS/GR, 7-18-82) An SSSV was set and tested in the ball valve nipple, at 1955'. ~2 ~pa~e be~°n~ i o n s o f ~.of;rrovC.~, i ~ s;~nuse ~ and correct to the best of my knowledge. Approved by. By Order of COMMISSIONER the Commission Date __ Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate · STATE Or: Ai_ASKA i~,~ -*ALASKA'...~ L AND GAS CONSERVATION C~._.IMISSION MO___NTH_LY REPORT OF DRILLING AND WORKOVER OPERATIONS , Drilling well [~ Workove-~r ~ ~ 2. Name of operator 7. Permit No. Sohio Alaska Petroleum Company 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50029-20771 4. Location of Well at surface 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. · KBE = 66.98' AbtqT,I ,ANT, 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well NO. $-9 (44-34-12-12) 11. Field and Pool Prudhoe Oil Pool For the Month of February 84 '12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks 13. Casing or liner run and quantities of cement, results of pressure tests 14. Coring resume and brief description 15. Logs run and depth where run 6. DST data, perforating data, shows of H2S, miscellaneous data See Attached tth,17. I hereby ~ert~y thatt~egoing is true and correct to the best of my knowledge. ~ ~ District Petroleum Engineer ~ SIGNED /~/ %~'~-'~ ~ "' --"/~[ ~ TITLE__ ~ DATE NOTE--R~zl~ort ~n ,his f~rm is required!~'t~or each calendar month, regardless of the status of operations, and must be filed 'in duplicate with the Alaska Oil and Gas Conservati~o-rf~Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 Submit in duplicate PERFORATING DATA - Well S-9 (.44-34-12-12)' 'PBU December 25, 1983: Pressure tested tubing and inner annulus. January 19, 1984: Rigged up Schlumberger and perfcrated the following interval using 2 7/8" Hyper~mes at 4 spf: 10067 '~-10138 ' BKB (Ref. BHCS/GR, 7/18/82) Put well on production. January 30, 1984: Shut well in to prepare for static pressure survey. February 1, 1984: Ran static pressure/temperature survey at 8800'~ TVDss. February 2, 1984: Set and tested SSSV in ball valve nipple at 1955'. Well on production. SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE. ALASKA 99502 November 18, 1983 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attention: Mr. C. V. Chatterton Wells S-] , ~S-9, S-10, S-14 and X-9 Gentlemen: Enclosed, in triplicate, are Forms 10--.403, Sundry Notices and Reports on Wells, for the above-named wells, These contain our proposals to perforate the wells. Y s 1', D~_.qtr~.ct Potroleum Encj~_neer GJP/JLH/pjw Enclosures cc: J. D. Hartz Geology Well File #]7 STATE OF ALASKA ALASKA O~TL AND GAS CONSERVATION cO~ivCM ISSION SUNDRY NOTICES AND REPORTS ON WELLS 1. DRILLING WELL [] COMPLETED WELL ~ OTHER [] / 2. Name of Operator 7. Permit No. Sohio Alaska Petroleum Company 82'-'104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50- 0.29---20771 4. Location of Well At Surface: ]642' SNL, Sec. 35, T12N, R12E, UPM ]635' EWL, I 6. Lease Designation and Serial No. ADL 28258 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number S-9 (44-34-12-12) 11. Field and Pool Prudhoe Bay Prudhoe Oil Pool Check Appropriate Box To Indicate Nature of Notice, Report, or Other Data 5. Elevation in feet (indicate KB, DF, etc.) KBE = 66.98' AMSL 12. SUBSEQUENT REPORT OF: (Submit in Duplicate) [] Altering Casing [] Abandonment [] Other NOTICE OF INTENTION TO: (Submit in Triplicate) Perforate ~: Alter Casing [] Perforations Stimulate [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note: Report multiple completions on Form 10-407 with a submitted Form 10-407 for each completion.) 13. Describe Proposed or Completed Operations (Clearly state all pertinent details and give pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25.105-170). The following intervals will be perforated November/December, ]983, uSing Schlumberger 2 7/8" Hyperdomes at 4 A lubricator will be installed and tested to 3500 psi for all well work. 10067'-10138' BKB (.Ref. BHCS/GR, 7-t8~82) An SSSV will be set and tested in the ball valve nipple at 1955'~. Su,.~ sequel, ~ is true and correct to the best of my knowledge. Title District Petroleum Engineer 14. I here~ertify~e ~)ing The sI:ZNL~ below fo,/r Cc~ m ,ssion use Conditions of Appr'l~r~, if any: COMMISSIONER Approved Copy Returned By Order of the Commission Date Date Approved by Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate Form 10-403 Rev. 7-1-80 SOHIO ALASI;,-':', PETROLEUM COF.'.,PAi'~IY SFO ARCO EXXON 10: PHILLIPS CENTRAL FILES (CCI/' s-Transmittal Only_ 311 I "C': ST.qEET ANCHORAGE. ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE; ALASKA 99502, Date:_ 9~79-82 Trans.#: 2676 CC#: ,. 55676 -. PAGE,'- 1., of.. 2 REFERENCE: **' S-8 SOHIO MAGNETIC LIS TAPES & LISTINGS , The following' material is being submitted herewith.-Please acknowledge receipt by s~gning a . ~ copy of this letter and returning it to this office:-- - Sch OH/DZL/BHC/FDC/CNL/LDT/NGT ** THIS TAPE SHOULD BE DESTROYED. INCLUDED IN THIS' BATCH OF TAPES. Sch *NC-18 / Sch ~"E-17-' Sch * ~'-B-6 --" Sch *"- E-11~ Sch *~--B-6 ---' Sch *'~M-15~ Sch *% R-7 ~ Sch * --G-9-~ Sch *-"N-13-~ Sch * ~-R-3 --' Sch * --R-8 -- Sch * -~M-16 -~' Sch *--'S-9 ~ Sch *---A_ll ~'~Sch *~A-16'--'"Sch *~A-19'~' Sch *~A-25-- Sch *-~N-15~- Sch #1,2 8/15/82 ACC 65510 Tape Pos. A REPLACEMENT TAPE HAS BEEN ISSUED AND IS OH/Replacement Tape #1,2 CH/TDT #1 CH/TDT #1 CH/TDT , #l CH/TDT #1 CH/TDT #4 CH/TDT #1 CH/TDT #1. CH/TDT : #1 R E £ E IV E D CH/TDT #2 CH/TDT #1 C~/T~T OCT 1 1982 CH/TDT CH/T. DT A]a~ka0il~ GasC0~s. Ocmmi~i,'~2 Anclmrage ..... ~'i. CH/TDT #1 CH/TDT #1 OH/DIL/BHC/FDC/CNL #l CH/TDT #1 8/15/82 ACC 655i0 0i948 9/ii/82 ACC 656i0 0i942 9/10/82 ACC 65611 01943 11/9/78 ACC 65576 01944 8/6/82 ACC 65450 01945 9/2/82 ACC 65561 01946 8/15/82. ACC 65463 01947 8/12/82: ACC 65453' 01949 2/9/82 ACC 65B33 01950 7/27/82 ACC 65370 01951 8/6/82 ACC 65451 01952 8/13/82 ACC 65452 01953 8/31/82 ACC 65543 01954 7/18/82 ACC 65424 01955 7/31/82 ACC 65405 01956 7/26/82 ACC 65420 01957 8/28/82 ACC 65545 01958 8/18/82 ACC 65546 0195~ 9/1~/82 ACC 65504 01960 ,~ / 8 ZO *SFO & EXXON: An Asterisk:(*) next to a listing abov. e. means you should have received the Tape(s) and Listing(s) directly from the respective service company. confirm th/i~ ~ -- ~}/L--/ Please aE~--v"~~~~~./-/?~Z~_ ~~--~~ . Development Geology [ ~.~~~ ,~ _ _ Well Records DATE . SOHIO ALASKA PETROLEUM CO.,MPANY 1'0: SFO/UNIT/ STATE: SFO · ARCO CHEVRdN '' ¢.. EXXON '.~ · GETTY .' · MARATHON ~'~' MOBIL PHILLIPS I -- B?AE (Transmittal Only) FILES (CC# ' s-Transmittal Only) 3i 1 ~ "C" ANCHORAGE, ALASKA TELEPHONE (9071 265-0000 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Date: 8-27-82 Trans.#: 2568 55568 cc#: Date to State Via Drilling: 8-27-82 /- SOHIO OPEN HOLEr.FINAL LOGS '. ~"~The following material is being submitted herewith. Please acknowledge receipt by signing a copy of this letter and returning it to this office:-- SFO/UNIT/STATE: S-9 Sch DIL/SFL ~2 7/18/82 2680-10458 5" & 2" S-9 Sch BHCS ~2 7/18/82 9183-10433 5" & 2" S-9 Sch FDC/CNL ~/1 7/15/82 2650-8700 5" & 2" ~/2 7/18/82 9700.~10462 S-9 Sch FDC f/1 7/15/82 2650-8700 5" & 2" ~/2 7/18/82 9700-10462 STATE ONLY: DIRECTIONAL SURVEYS: 7-7-82 to Magnetic Single Shot Directional Survey Date:7-16-82 ~~~j Gyroscopic Directional Survey ~C~!V.~ate: 7~28~82 ~ Karen Mestas .~C,,VEO amska Oil & Gas Cons. Co~rllissior~Tell Records Dept. /~n. rage ' O^T~ ~ -- Development Geology Job#:A0782.016 Job#: 1399 · . SOHIO ALASKA PETROLEUM COMPANY August 30, 1982 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-612 ANCHORAGE, ALASKA 99502 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well S-9 (44-34-12-12) PBU Enclosed, in duplicate, is Form 10-407, Completion Report, for the above-named well together with the Well History, Well Logs, and Directional Surveys. This well has been perforated as an unperforated oil well. RHR: JM Enclosures cc: Well File #17 Geology Yours very trulY, District Dri ll ing Engineer Alaska Oil & Gas Cons. ~chorage .-. STATE OF ALASKA - ALASKA~-~ AND GAS CONSERVATION CO~IlSSION ,WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number Sohio Alaska Petroleum Company 82-104 3. Address 8. APl Number Pouch 6-612, Anchorage, Alaska 99502 50-029-20771 c,~'r',o 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPMILO[vERiFiED Prudhoe Bay Unit At Top Producing Interval top Sag R. SST. 10. Well Number j Sur~. ~ -~ S-9 (44-34-12-12) 519' WEL, 481' NSL, Sec. 34, T12N, R12E, UPM At Total Depth 11. Field and Pool 674' WEL, 330' NSL, Sec. 34, T12N, R12E, gPM Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Oil Pool KBE = 66.98' AMSLI ADL 28258 12. Date Spudded 13. DateT.D. Reached 14. Date Comp.,Susp. orAband. I 15. Water Depth, if offshore 116. ND. of Completions 7/5/82 7/19/82 7/25/82I feet MSLI one 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey I 20. Depth where SSSV set 21. Thickness of Permafrost 10480'MD 9218'TVD 10436'MD 9178'TVD YES~ NO[][ 1955 feetMD 1870' 22. Type Electric or Other Logs Run DIT,/FDC./CNT,/SP/GR/CAT,, DIL/BHCS/GR/SP, CBL/VDL/GR/CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20"x30" Insulated Conducto~ Surface 110' 36" 8 cu.yds, concrete 19 3/8" 72# L-80 Surface 2678' 17 1/2" 3720 cu. ft. Arctics~t II 9 5/8" 47# L-80 Surface 10480' 12 1/4" 2058 cu.ft. Class G (lst stage) 700 cu. ft. Class G (2nd stage) 130 cu. ft. Arctics~t I (3rd stage) 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER sET (MD) 4 1/2" 9874' 9732' None 26~ ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMQUNT& KIND OF MATERIAL USED . 27. PRODUCTION TEST Date First Production Method of OpeFation (Flowing, gas lift, etc.) . Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO TEST PERIOD ~ OIL:BBL GAS-MCF wATER-BBL OIL GRAVITY-APl (corr) FIowTubi,g Casing Pressure CALCULATED ~ . . : Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · Alaska 0ii & Gas Cons. C0mmlssi0. I Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29. NAME Sag River SST. Shublik Ivishak GEOLOGIC MARKERS MEAS. DEPTH TRUE VERT. DEPTH BKB 31. LIST OF ATTACHMENTS Ii Subsea 30. 8658' 8689' 8768' 9941' 9976' 10062' FORMATION TESTS Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Well History~ Well Logs~ Directional Surveys 32. I hereby certify that the foregoing is True and correct to the best of my knowledge Signed Title District Drillinggate ~7~ R Engineer INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24' If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage 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". WELL S-9 (44-34-12-12) PBU , WELL HISTORY Spudded well at 0800 hours, July 5, 1982. Drilled 17 1/2" hole to 2700'. Ran 68 jts. 13 3/8" 72# L-80 Buttress easing to 2678'. Cemented with 3720'cu.ft. Arcticset II cement. Installed and tested BOPE. Cleaned out to 2634'; tested ' casing to 3000 psi, okay. Drilled out to 2720'; ran leak-off test to 0.67 psi/ft. gradient. Directionally drilled 12 1/4" hole to 10480'. Ran 257 its. 9 5/8" 47# L-80 Buttress casing to 10480'. Cemented in three stages: First stage with 2058 cu.ft. Class G cement; second stage through bottom D.V. packer at 7790' with 700 cu. ft. Class G cement; third stage through top D.V. packer at 2614' with 130 cu.ft. Arcticset I cement preceded by Arctic Pack. Cleaned out D.V.'s; tested casing to 3000 psi, okay. Cleaned out float equipment to 10436'; tested casing to 3000 psi, okay. Ran CBL. Changed well over to NaC1. Ran 229 its. 4 1/2" 12.6# L-80 A/B modified Buttress tubing to 9874'. Landed tubing with ball valve at 1955'. In- stalled and tested tree. Displaced tubing to diesel; set packer at 9732'. Tested tubing to 3500 psi, okay. Released rig at 0800 hours, July 25, 1982. SOHIO ALASKA PETROLEUM CO. PAD. S(42-:54-12-12) S.9 Controlled Drilling Consultants LES HENDERSON 349-3114 .'.'---.... '" 7608 Highlander Drive· ". "' . Anchorage,' Alaska 99502 - . (907) 349-31'1'4 - . · , . July 20, 1982 Mr. Brian Rose Sohio Alaska Petroleum Company Pouch. 6-612 Anchorage, AK 99502 -. .. RE: Magnetic Single Shot Survey ' ' Job No. A0782-016 -' Well 5-9 (42-34-12-12) Prudhoe Bay Field North Slope, Alaska . Date of Survey: 7=7-82 to 7-16-82 Dear Mr. Rose: Please find enclosed the "Original'' and six (6) Copies of our Magnetic Single Shot Survey on the above well. The method used in calculating this. survey was Radius of Curvature. The depth of the survey was 2676 to 9910.. .. Thank .you. for giving us this.oPportunity to:be of service. · ... · . . Yours' very truly, ~ controlled Drilling Co--~ultants Terry V. Henderson Dire c't iona 1 Supervi s or t..,_Hp LEe ~ SOHIO ALASKA PETROLEUM ~,,A~NET,,.. SINGLE SHOT SURVEY h:.,.D1U.:~ OF .,, VATU P,E~,,UD OF P'"i'~°i~'rATiON COt~F'UTED FOR CDC B"¢ OCEANTECH<F~d L ZNDSEY 8.: ASSOC, ) K 8 ELEV 66 ";¢'*' ................. OF SU 'VEV btEAS, DRIFT VERTICAL SUB ~' il""' ..... OEP'TH ANGLE OEPTH SEA (,~ tREC DEG, TOTAL COORDINATES O O O ,OO $ 2,05 S .5,72 S 23,89 $ S S :~ 27 $ 'aa'? ~528 ..... ..!~,2 3 4094 4t 88 ....... 46¢2 ..;* i . i 5420 C L 0 S U R E S STANCE ANGLE b i,i , O0 S 90 O 0 t.d , 2 !22 2SI,87 S 32 24 29 275,63 $ ]73 6i S 427 02 S t t77 02 S i 494 S1 'S i 800,24 S 2059,22 S O00 i 5't 274 ~ 58 913 =:'O',? 33:9 20'~ 426 2:3O :3 EC T 2 ON c, s "E T SOHIO {dELL S-9 S ~ NG'LE RECORD OF SURVEY )','tEAS, DRIFT VERTICAL SUB DR~'FT DEPTH ANGL. E DEPTH SEA D~REC: ....... p M REG., TOTAL COORD Ii'4ATEs 7638 z'" '" "~'~ " ~' ~ 4o 6,~,. ~ , ~ 1 6¢54,6,~ 8090 .... ~ 0 717'I,0t 7i04. 8279 ..... 8497 9224 THE FOLLOWING t'S EXTR:APOL. ATED TO T£:,. 80TTON HOLE CLO. gURE ~807',3'7' F:E~T AT $ 3.4 I 36 W C L ;3 "" Lt R :: ...... STANCE £:, I',i . SEVER I T"¢ DEl;,.-': i 00F'T 2946,2~ S 32 40 24 k! 3782,48 S :?;:3 57 13 U E.~ 3-. t':; 7'.q ~-.,i CE 215 '"~'I ,? ¢:, -,5 (~ "'"' t SS ;?82?', 5-t" 5 67 2 'P,4 5,4 0 4S9 3 07~, 86 7'78 ~ ~ ti,... ~ :~'-:" ¢~ ...., o~..' ;~ 048 3782,48 MEASItRED DEPTH AND OTHER ~)ATA FOR F,-"' . . __.,,,_~RY. EVEN i00 FEET OF SUB :SEA DEPTH ......................... _!R_UE. MEASURED VERTICAL SUB DEPTH DEPTH SEA DIFFERENCE VERTI CAL CORRECT .~.6..r .......... 26? ....... ~ O_.D_ .............. (! . 357 ,~67 ~ 00 0 467 467 4 0 56.7 ......... 56_7 ............. * '? ,,,,5,' , t 88 0 0 ~ 467 t '46 ,,¢~,, 1567 , 1580 .0 O 1667 t 687', 1 0 .0 :?~,,?_Z :?,~oe?2,, 25':-.uoo o. o , ~ 0:8 0 0 ~-~ ¢ ~,~,~ ~ , . 2467 2567 25G'7' 25 O0 0 0 ..o :687 :~ t 69 TOTAl UuOXL INA O0 S O0 S O0 S O0 S 08 S O0 $ O0 S ,O0 S ,O0 S ,O0 S ,OOS ,00 S ,00 $ ,00 $ ,,OOS ,00 S ,00 $ ,00 S ,OOS ~O0 S ,OOS ,00 $ ,00 S ,67'o'" 2,92 $ t7,25 S 3t,07 S 48,33 S 59,4'7 S 94,29 9 7 2,4 '7' 0 ~,IE[~oI_,~.b.D D~=., Tld AND I]THER DATA FO',;; E~.~'ER':;' c~Ef4 I00 FEET OF SUD -'" - · ._%._~ ...... r._ __, ......... ~' ~'. ~ , - , _ . SEA DEPTH, TRUE ~'iEAS'ORED VER.r ZOA'i-I -'o,:,LiB ................. MD-TV:.," -- VERTICAL DEF'TH DEPTH SEA DIFFERENCE CORRECTION .'3691 ,366 '?, E:6 00 24 ~80'i S767, ..7.7'00 34 ~'B15 386? ..',,. gO 4? _. 4t5] .... , 4o6_7__,_ 400o 84. 4z,'4 416Z, 4t O0 4,~ ..'¢,' 4~6,', ~.~.00 ! .:, 0 46'16 446? , 4400 I 79 4772 4~" 7, ~, ~ 450 O 2 O 5 48~9 4667, 46.08 271 5~)26 4787, 4700 259 5154 4867., 480 ,.,~o~ ?)e, 7', 4900 ~t4. 5:548 .5t67, 5 t00 372 56369 526?,, 52:00 ,4 01 5925 =' ' '~ ,~4e,,., 5400 4 6 o=;'~ 5567 , .:~ O O 486 6'i e.O 5667, ~,.4,~ 1 ,..~.e ~' , ,. 80.0 564 ................................... 668i 6~, , 6800 6i4 ;'t85 ...... *' '''~ " '"~,'o 1 I 656'?' , Gt~.. O O 744 ,' 4..,'¢ 66.6 ,,', 6600 77 i ,' '567 ....... 6' O 0 8 0 O ,, o.:~ ,. 696';" 8 1.'3 i7 ~0 2.6 . 29 29 TO TA L. i5.3, 191, 2~4 282 3.3,7 4.5 F 582 646: 775, 840, 906, 97.3, 1 040, 1~07, i 173, I ;;.~t 4. O, 14~6, '1 '4'~, 9, i 628, '1694, t827, t 961, 2028, 2097, 2t67, 222]7, COORDINATES 94 S 49 S 76 S 47 S 77 S 40 S 17 S lOS OO $ 44, S 8t S 78 S T~7 S 24 S '72 S :30 S ~? S 45 S 68 S 58 $ 9.::-:, 't 2 ! , i87..42 ;26,4 ~ 25 .?,03, 343 , 7'~ 384., 6 0 426 ,. 469 .. 558,56 604,7?:3 697', 99 744, 879, 06 921, $5 963,29 'i 042 ,. 54 1155 59 12.32 06 127' 'l 5 1354 i :2498 t 484,27 SOH. ZO WELL '" "' M EA SURED DEPTH ._ A. ND. 0 ?'~ER__ O!~ .]_7..8.. !'.-'.C).~..___E.'x'E R ¥ EVEN FEET OF . SUE: SEA bEPTH, j Lf L Y TRUE MEASURED VERTICAL SUE: MD-TVD VERTICAL DEPTH [ ~.P rH ~:~~ DIFFERENCE C:ORRECT I ON 8085 7~.~;37, 7! O0 8:2 J 3 .......... :Z ~.6__7_ ? ......... ;'7_2.EE z40 7 ''? '" 846'7 7467, 7400 I ,..,' 16 766,', ," ;~:, 00 9079 ,'~¢ , 7900 9~ 97 80:67, 8000 9p.t..4 ............81.67, 9,429 8267, 8200 '~544. ,.., .... v 965~9 8467, 84 O 0 ....... 29 29 ':27 26 t9 I4 13 TOTAL 2J77.. 1E, S 'i526: 2445,55 S 1560,43 25ti,75 S 16i! ,24 ~6.L3,8~5 S i696, · ~ ¢;;o ? ,c_: 0 "',' .~>,=< 2754,47 ~3 ~7S~, 0~-.', 46 :S 2859 , 76 S I ~BE',~, ,, 49 2988,45 S 't903,52 29,~4,60 S '~942, 30J¢8 , 85 S 20t7,50 ~I~2,68 $ 2087,76 3'I.46,07 $ 2J2i,14 :_--:OHIO I.¢ELL ~9 IftT£RPOL~TED './I~LUES FOP, r:~,'EN :~'"~-'d'i~-'~:~T oK MEC~SURED DEPTH, TRUE N E ASLi'R-~[~- ................ ;¢ER T I Ct:~L SUB DEPTH DEPTH '~" TOTAL COORDZH~TES I000 1OhO 9';:~, , O0 2000 2000 ! 9.S3, ,00 ............. ~ : ................. ~%.~ ~.~ .- i¢ 4OOO ~94 ~ 3874, 269,54 5000 4747 4680, 762,;22 6OOO 5~25 54~R ~ 278 90 FOOO 6S2~ ~254, 1 796,4~ 800 n 7 't 0 'i. 70 $ 4, ,:. ~ S ~ ~ 9 ,~' ; '!*l i , i t ii ........~,.,., +~' ~ * ~-=. ' ,~c ,~ .__~_~_~+ ~,.~ ;.~.+_~ ~ i i. ~ i'ii ~--~l' ~ *'~ ;~ _~:~:~:_~_~m~a.m:..,,_~.~- . , , , - ~ , ; - : , . , .... ~ . · ' , ~ * ~ ~ - ~ ;-~ :~ '~ ~ · ~ '~-~ ~ ~ ;~ .?T ': =-F"~ F=~ ~ ~ ' '~, · r } · '~ ' ' ~ ' ' ~ ' -t ~-~'~'~~-~'- '~~'~ .... ~-~~-~ ~'-~~-- 'I~ - = ~-~ v , i=' .... -~- ~.--4- · ~- ...... ~-~-+ ..... ?-'~ · ~ , , · · ~ +T .... 4~ ~' ....... 4--, , ' ' ' ' ' ' i ' - , ~ ...... ] ' i .... , , * ' ...... t t -, · - ~ T ~ ':'i i i ~ '.-~i imf j' : ; : 'L: ': ; '" i_L. ~i IL;;4-1..~..i.2.- 4---'- - ~ Ai4-,[ V~41-15~--S--i--~~;-.~--iA-~-~ i-4-~-.¢.-1 ~ ~ , , - ; . I ......... '~_~F_.~_: .......... t ...... I.~-~'-4-* .... ~ .......... .-, ~ ~ .... * :t * ~ r- . - ~ ........ [, · _~ ..... ': :.~ .... ~- -4 - --i eo": '~ ....... := '-~"i-- ~ : '=-':'*~ ~='' ...... ~ ~ ........ !- '~ -"' L- :': .: ~ ~-: ~ -' ,' ~ .... ~ .... ~: - '-: .... ~ ": ~ :T :-::-- '~'~~i-1-7t.~ ~ : i:-. : ~ _.:: i .: .... l-,~:~ ] ~-~.~ ~ : ;. .... ~- ' t .... ! ..... ~ ':' ~''' :I ' ~~-~iLt : ...... ~ ...' ~ ~ .... :]S~. ~J :-.:-.~ ~--~- .... ~ ..... i : .... ~ -~ ' ee~ - ' '} ......... ; i : : · , .... : ' ~ ..... 4 ..... i ............ i~-' = ..... i : : : ' ' ' - {' · ' : ~ t _ . i i~ ' ; ' ~ .....I /~ i ~O~ ~ ~ ~ ~ -~ ~~ ~O ' -- ; .... i ............ ~ ........ ~- .-> ..... ~ ...... ~ ....... ~ > r-, .....I :-~ :--* i4 .... ;" t .... ~" '. ...... : -*! .... * .... 7'"- ~? .... :-'1T'Ti":i':~td"T~'T'~ ~-~-~'-'-T'i~-: !"--: : ~ i ~ : : ~ ~ :;: ~i~_:t.~ -7'; ~ ~ -: '- ' ~ ' " ~ , ~ , i : 5 : ~ ' j ? ; - ' : t * _~ . __i~.~.i_: ~. ~ ..:-2.- J_~2..~ ~_~ .C._~-.~ ~ I-~ 5 ~:~r-~ '---:i :-:--: ..... :':!:'~ :'" -:: .... ~;' .... ?;]-~'~ :'~':-;iq-'--:'~'7-'~i~ '} :~iL:;.~ ...... , .............. ~.+~.'~--i'~'" r~-c-~-'?'t~ ...... : .... 77 -'T'-~-~-'~ ~'~ ~T~'IT'S'm~' ~'~ '~ ~ . T I : ~ : I ~ : ~ :: SCIENTIFIC DRILLING INTERNATIONAL 1111 Eas180Ih Slreel, Anchorage, Alaska 99502 · 907/349-3541 · Telex: 09025364 (SDC AHG) Subsidiary o! AMF INCORPORATED ATTN: SOHIO Drilling Department Please find enclosed our completion copy of the gyroscopic survey on Well S-9. If there are any questions concerning this report please do not hesitate to call our survey department. We at AMF/ Scientific Drilling Int'l. thank you for~the oppor- tunity to provide this service and 16ok forward to serving yOu again. Thank you, ~ Allan Voshall Manager, Alaska District ~aska Oil & Gas Cons. Anchorage '. 8OHIO ALA GYRO$COPI RADIUS OF SURVEY RA COMPUTED SKA PETROLEUM CO C DIRECTIONAL SURVEY CURYATURE METHOD OF CALCULATION N BY CHAPPELL/PERRY FOR SD1 BY OCEANTECH(FM LINDSEY ASSOC. ) JOB % 1398 WELL $-9,SEC.35,T12N,R12E KB 5LEY, 66.98 FT. SURVEY DATE 28 dULY 82 PROPOSED DIRECTION S36-57W RECORD OF SURVEY MEAS, DRIFT DEPTH ANGLE D M 0 0 0 100 0 36 200 0 32 300 0 40 4~00 0 44 500 0 49 600 0 50 700 0 46 8 0:0 0 49 900 0 39 1 0:00 0 28 1100 0 26 1~.00 0 t8 1300 0 22 1400 0 11 1 SO0 0 8 1600 0 12 1700 0 14 18'00 0 11 1900 0 10 2000 0 I 1 2100 0 10 2200 0 11 2300 0 7 240~0 0 26 TRUE VERTICAL SUB DEPTH SEA ,00 -66,98 lO0.O0 33.02 199,99 I33,01 299,99 233.01 399,98 333,00 499.97 432.99 599.96 532.98 699,95 632,97 799.94 732,96 899,93 832.95 999,93 932,95 1099.93 I032.95 1199,92 1132,94 1299,92 1232,94 1399,92 ~332,94 1499.92 1432,94 1599,92 1532,94 1699.92 1632,94 t799,92 1732,94 1999,92 1932.94 2099,92 2032,94 2199,92 2132.94 2299.92 2232.94 2399.91 2332.93 DRIFT DIREC DEG, S , OOE 813,82E $ 7. OSE 815,47E S 14,45E Slg.77E 825.07E 843.57E 858,22E 875,28E $75,92E N73.20E NS I , 12E NS 1,12E N40,,32E N68,07E N69,50E N17,22E N32 ,SOW S81, t 2W 877. 859,65W 856.17W N82,37E N67,43E TOTAL COORDINATES CLOSURES D I STANCE ANGLE D M ."00 S . O0 W -,52 S .06 E 1,49 8 ,24 E 2,52r'$.~,. ,45.. E 3.70'.S"~i""~" "76 E 4.99 '" I' 'i()~,: El 6,32 S ; I,',7.1:~E~ , .' 7,4'7 S '.."' 2,.~49. E.:~.. .... 8,34'9 ... 3756'E e,e4 s 4,73 E 9,08 8 5,68 E 9.06 S 6.45 E 8,77 S 7.0~ E 8.40 S 7.47 E ~.07 S 7.81 E 7,91 8 8.03 E 7,80 S 8,30 E 7,54 S 0,55 E 7.19 S 8,51 E 7,07 S 8,24 E 7,12 S 7,94 E 7.24 S 7,66 E 7,40 S 7.40 E 7,58 S 7.47 E 7,45 S 7,93 E .00 S 90 0 0 W ,52 S 6 54 30 E 1,51 S 9 12 53 E 2,56 S iO 3 4 E 3,77 S 11 38 15 E 5,12 S 13 4 46 E 6,55 S 15 7 26 E 7.87 S 18 27 $ E 9,07 S 23 7 41 E 10,03 S 28 9 40 E 10,71 S 32 0 12 E 11.13 8 35 26 35 E 11,23 S 38 39 42 E 11,24 S 41 37 42 E 11 .23 S 44 4 19 E 11.27 S 45 26 55 E I1 .39 S 46 46 57 E 11.40 S 48 37 5 E 11,14 S 49 48 24 E 10,86 S 49. 23 23 E 10.67 S 48 6 45 E 10.54 S 46 38 11 E 10,46 S 45 I 4 E 10,64 S 44 35 49 E 10,88 S 46 47 27 E DOG LEG SEVERITY DEG/I 0 OFT ,000 ,600 ,067 .133 ,067 ,083 .017 ,067 ,050 ,167 .183 ,0~3 ,133 , 067 ,183 ,050 , 067 ,033 · 050 .017 .017 .017 ,017 .067 ,317 SECT;[(' DISTAN&~ ,00 .39 I , 08 1 ,81 2.60 3.43 4.21 4,70 4.80 4.54 4 .'20 3.74 2.. 2.15 1 ,89 1 .65 1 ,29 1 , 03 1 .08 1 ,30 I .55 1 ,83 1 1 .57 SOHIO WELL SEC.35, Ti2N, R12E GYROSCOPIC SURVEY SURFACE LOCATION 1642 SNL, JOB W 1398 1635 EWL 6 AUG 82 KB ELEV 66.98 FT. RECORD OF SURVEY HERS. DRIFT DEPTH ANGLE D H TRUE VERTICAL DEPTH 25.00 0 28 2499.91 2600 0 25 2599.91 27'00 0 22 2699.91 2800 0 29 2799.90 29.00 3 11 2899,84 3000 5 47 2999.53 3100 8 42 3098.72 3200 11 S 3197.23 ..3300 !3 22 ;~294.95 34.00 t5 56 339J.69 3300 J8 25 3487.23 3600 20 55 358J.39 3700 23 59 3673.80 3800 26 58 3764.06 3900 29 30 3852.16 4000 31 28 3938.33 4100 33 49 4022.53 4200 35 49 4J0,4.63 43'0:0 37 6 4185.05 440'0 37 28 4264.62 450'0 37 17 4344.09 4600 37 20 4423.62 4700 37 4 4503.28 4800 36 59 4583.12 4900 37 27 4662.75 5000 38 2 4741.83 510'0 38 38 4820.27 52'00 38 56 4898.22 53:00 39 28 4975.72 SUB SEA 2432.93 2532.93 2632.93 2732.92 2832 2932.55 3031.74 3130.25 3227.97 3324,71 3420.25 3514,41 3606.82 3697.08 3785.18 3871 .35 3955,55 4037.65 4118,07 4197.64 4277.11 4356.64 4436.30 4516, 14 4595.77 4674.85 4753,29 4831.24 4908.74 DRIFT DIREC DEG. N60.73E NST.60E N64.65E S 3.87W 825.87W 829.00W $26.98W S29.72W 83J,48W 832.35W S34.50W S34.97W 835.40~ S35.65~ 835,40W S35.25W 834.67~ 833.30~ S32.97~ 832.70~ S32.72~ S32.55W 833.03~ 832.65~ S32.82W 833.33~ 833.72~ 835.12~ 835.18~ TOTAL COORDINATES 7,11 6,71 6.:38 6,73 9.'80 16.74 27,87 42,90 61.21, 82.6~ , , 1 07,31 134.97 166,18 201 . 18 239,68 281.06 325.27 372,61 422.37 473.27 524.34 575.39 626.21 676,80 727.68 77~. 97 83 O, 68 882,35 934. O3 8.64 E 9.30 E 9,90 E 1 0.41 E 9.59 E 5,99 E -,., . 07..E.. ' ??,., , , , ,,.:'~,',", 8,08 tJ , .' ! 8:; 8~; ' 32;2~' W, 67.67 W 89.67 W 114.66 W 142.14 171 .47 W 202.38 234.29 266.77 W 299.61 3~2.41 W 365.10 397.04 W 430.50 W 463.20 496.61 W 530. ~6 W 566.27 602.65 W CLOSURES DISTANCE ANGLE D H DOG LEG SEVERITY DEG/IOOFT 11.19 S 50 33 11 .47 S 54 11 .78 S 57 12.39 S 57 13.71 S 44 17.78 S 19 27.87 S 0 43.74 S 1 0 64.05 S 17 88.73 S 21 117.76 S 24 2 E 10 40 E 11 2 E 6 44 E 22 30 E 41 19 E 9 7 E 38 56 W 7 32 W 17 53 W 19 2 bJ 150.98 S 26 37 36 W 188.83 S 28 21 3 W 231.56 S 29 40 47 W 278.66 S 30 40 13 W 329.24 S 31 23 12 W 383.09 S 31 53 21 W 440.14 S 32 9 39 W 499.56 S 32 16 35 W 560.13 S 32 20 12 W 620.83 S 32 22 2~ W 681,44 S 32 23 46 W 741.90 S 32 25 42 W 802.~2 S 32 27 34 W 862.60 S 32 28 43 W 923,81 S 32 31 5 W 985,82 S 32 34 53 W 048.43 S 32 41 28 W 11~1.57 S 32 49 51 W ,033 .050 .050 ,117 2.701 2.600 2.917 2.3~5 2.285 2.567 2.493. 2.501 3. 067 2.984 2.534 I .967 2,357 2. 054 1 .289 ,380 , 184 .079 ,319 .162 ,471 ,615 .618 ,629 .534 SECTION DISTANCE ,18 -.43 -.44 2.55 10.30 22.81 39.87 60.99 86.24 115.76 149.41 187.59 230.60 277.89 382.~ 439.64 499.03 559.57 620.23 680.79 741,21 801.38 861,82 '923,00 985.01 1047.64 1110.84 SOHIO WELL S-9 SEC .,35, TI 2N, R1AE GYROSCOPIC SURVEY SURFACE LOCATION 1642 SNL, JOB # 1398 1635 EWL 6 AUG 82 KB ELEV 66.98 ET , RECORD OF SURVEY MEAS, DRIFT DEPTH ANGLE D H 540.0 39 20 5500 39 33 5600 39 29 5700 39 26 5800 38 56 590'0 38 34 600.0 38 7 6300 37 50 6200 37 6300 36 58 640.0 36 40 650.0 6600 36 22 6700 36 40 6800 37 13 6900 37 31 7000 37 44 7100 37 34 72'0,0 38 4 7300 38 1 7400 38 37 7500 38 38 7600 39 29 7700 40 7800 39 33 7900 39 50 8000 39 5 8100 38 55 82o.o 38 11 TRUE VERTICAL DEPTH SU8 SEA DRIFT TOTAL DIREC DEG. 5052.99 4986,0I S34,90W 985,99 S 5130,22 5063,24 534,83W I 038, 12 S 52 07,36 5140.38 834,73W I 090.38 S 5284.57 5217,59 S34,67W 1142/63 $ 5362,08 5295,10 834.63W I194.,.60 S 5440.07 5373,09 S34.55W 1246,13 S 5518,50 5451.52 834,28W 1297, 5597.33 5530,35 833,92W 1348, 5676,63 5609,65 933,73W 1398.' 5756,39 5689,41 933,50W 1449. 5836,44 5769.46 833,17W 1499, 5916,72 5849,74 933,038 3549, 5997.14 5930,16 832,18W 1599, 6077,51 6010,53 831,87W 1649, 6157,44 6090,46 S31.52W 1700, 6236,91 61'69.93 931,10W t752. 6316,12 6249.14 S30,87W }804, 6395,29 6328,31 830,83~ 1857, 6474,29 6407,31 83t,38W 1909, 6553,05 6486,07 932,03W 1962, 663I .50 6564.52 $~2,45W 20i4, 6709.63 6642,65 S33,40W 2067, 6787.28 6720,30 S33,35~ 2119, 6864,t2 6797,14 S32.60W 217~, 6940,92 6873.94 S32,13W 2227, 7017.87 6950,89 S32,27~ 2281, 7095,07 7028,89 S32.62~ 2335, 7172.79 7105.81 833,18~ 2388. 7250,99 7184,01 834.10~. 2439. COORDINATES 639,10 675,4i 711,71 747,89 783,81 819,35 30'S...~. 854,4.! 2'6""S 87""8~' 922i82; '1 o s 956:; 1 '7 S ;!i 989,., 15.. 12"S,,.023~,¢71 18 S 1 053,74 63 S 1085.29 77 S 1116.86 62 S 1148,40 96 S 1179,83 40 S 1211,15 90 S 1242,83 32 S 1275,22 76 S 1308,30 36 S 1342.22 78 S 1376.89 47 S 1411,72 56 S 1446,01 60 S '1480',04 24 S 1514.13 07 S 1548,31 96 S 1582.84 CLOSURES DISTANCE ANGLE D H DOG LEG SEVERITY DEG/IOOFT 1175.00 S 32 57 I W 1238.50 S 33 2 54 W 1302.10 $ 33 8 0 W 1365,63 S 33 12 22 W 1428.79 S 33 16 12 W 1491,37 S 33 19 31 W 1553,39 S 33 22 8 W 1614.92 $ 33 23 49 W 1675,84 S 33 24 45 W 1736.16 S 33 25 10 W 1796,08 S 33 25 0 W 1855 72 ~ , o 33 24 23 W 1915.13 S 33 22 54 W t974.62 S 33 20 27 W 2034,70 S 33 17 31 W 2095.35 S 33 14 5 W 2156,36 S 33 10 15 W 2217.39 S 33 6 25 W 2278,67 S 33 3 12 W 2340,28 S 33 I 4 W 2402,27 S 32 59 52 W 2464,69 S 32 59 45 W 2527,70 S 33 0 19 W 2591 ,70 S 33 0 17 W 2655,74 $ 32 59 21 W 2719,60 S 32 58 14 W 2783,15 8 32 57 31 W 2846,08 S 32 57 26 W 2908,~9 S 32 58 19 W .175 ,218 ,078 ,057 ,500 ,368 ,461 ,3t5 ,604 ,280 ,323 ,126 .351 ,321 .565 ,337 .234 ,167 ,542 ,252 ,622 ,371 ,850 ,691 ,582 .289 .763 ,279 .813 SECTION DISTANCE 1174, ~2 1237.84 1301 .47 1365. 03 1428.21 1490.80 1552.83 1614,35 1675,27 1735,57 1 795,4-7 1855,08 I914,45 1973.88 2033,89 2094 ,( ' 2216,30 2277,47 2339,00 2400,94 2463,32 2526,31 2590.27 2654.25 2718. O4 2781 ,54 2844.43 29 06.73 SOHIO WELL S-9 SEC. 35, TI 2N, R12E GYROSCOPIC SURVEY SURFACE LOCATION 1642 SNL, dO8 % 13.98 6 AUG 82 KB ELEV 66.98 FT. RECORD OF SURVEY TRUE MEAS, DRIFT VERTICAL SUB DRIFT DEPTH ANGLE DEPTH SEA DIREC D M DEG. 8300 37 56 7J29.73 7262,75 8400 37 29 74 08,85 7341.87 8500 36 49 7488,55 7421,57 8600 35 40 7569,20 7502,22 8700 34 50 7650,87 7583,89 8900 ~ ~9 78~5,9~ 7748.95 9000 3~ 8 7899,42 7832.44 9200 30 ~2 8068,85 8001.87 9300 29 55 S155.11 8088.13 9400 29 30 8241 ,96 8174,98 9500 28 54 8329.25 8262.27 9600 27 19 8417,46 ~50,48 9800 25 9 8596,73 8529.75 9900 24 55 86~7,~4 8620,~6 10000 24 ~9 8778, ~ 8711, ~5 I0~00 24 23 8~69,1~ 8802,~3 10200 23 40 8960,45 8893,47 tO30'O 23 i 9052.26 8985.28 10400 22 40 9144,42 9077,44 THE FOLLOWING IS EXTRAPOLATED 10480 22 40 9218,24 9151 S34.42W S34,13W S3.5. I OW S35,45W S36,50W S37,37W S3.7,33W S37.83W SJ8.70W S40. 18W $40.95W S41,02W S41 ,48W S41,48W S42,35W S44,33W 945,92W S46,02W 945.55B 945.75W S45.60W S45,68W TO 'TD S45.68W TOTAL COORDINATES CLOSURES DISTANCE ANGLE D H 2490.91 S 1617,54 W 2970.03 S 32 59 55 W 2541.45 S 1651 ,98 W 3031 .17 S 33 I 28 W 2591,15 S 1686,29 t,-t 3091,54 S 33 3 20 W 2639,41 S 1720.43 W 3150,62 S 33 5 50 W 2686.,.12 S 1754,33 W 3208.26 S 33 8 56 W 2731,59 S 1788,52 W 32~5,03 S 33 12 53 W 2776.14'.¢S ......1822,.52..W.. 3320.92 S 33 17 28'iS,.75'..Si...";'"'iS'56'J'OS':':Wi' 3375,81 S 33 21 2862,12 S' '1'889::;.'50;I.,~':I' 3429.57 S 33 25 2902.50 $ .1922j';7.2'iW~ 3481,57 S 33 31 2940.93 S '~:1'955~,~62~W.'!i;.,.3531,79 S 33 37 2978,34 S.-1988,12 W 3580.94 o ~ 33 43 3015,02 S 2020,29 W ~050,32 S 2051 .50 W 3.083,92 S 2081 ,67 W 3115.54 S 2111,50 W 3145,39 S 2141.49 W 3174.53 S 2171 ,62 W 32 03.47 S 22 01 , 37 W 3231.93 S 2230.48 W 3259.61 $ 2258,82 W 3286.75 $ 2286,58 W 4 W 54 W 18 W 21 W 3629,31 S 33 49 30 W 3676.01 S 33. 55 22 W 3720.74 S 37.4 I 10 W ~763.64 S ~4 7 3805; 19 S 34 14 54 3846.24 S 34 22 30 W 3886,93 S 34 29 46 hi 3926.88 S 34 36 39 W 3965.77 S 34 43 15 W 4003,89 S 34 49 34 W 3308.29 S 2308,64 W 4034,18 S .34 54 31 W DOG LEG SEVERITY DEG?IOOFT .277 ,462 ,752 1,156 ,901 ,422 .867 ,538 ,981 1,373 ,969 .4~7 ,610 1.583 .949 1,284 .365 .267 ,278 ,717 .650 ,350 .000 SECTION DISTANCE 2968,06 3029,54 3089,92 3149.04 3206,74 3263.60 3319.59 3374,56 3428.43 3480,55 3530.90 3580.18 ~628,67 3675.47 3720,30 3763,~' 3804.~.~ 3846.08 3886.83 3926.83 3965.75 4003.89 4034.18 80TTO~I HOLE CLOSURE 4034,18 FEET AT S 34 54 31 W WELL S-9 6YROSCOPIC SURVEY dOB # 1398 SEC.35,TI2N,R12E SURFACE LOCATION 1642 SNL, 1635 EWL HE~SURED DEPTH AND OTHER DATA FOR EVERY EVEN lO0 FEET OF SUB SEA DEPTH. K8 ELEV 66.98 FT. TRUE MEASURED VERTICAL ,SUB HD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 0 167 267 367 467 567 767 867 967 1067 1167 1267 1467 1767 1967 2067 2167 2267 2367 2467 2567 2667 2767 2867 3068 3271 3479 O, -67 0 0 l&7. iO0 0 0 267, 200 0 0 367. 300 O 0 4&7. 400 0 0 567. 500 0 0 667. 600 0 0 767, 700 0 0 867, 800 O : 0 967. 900 0 0 ~067. JOOO 0 .0.. 1167. I100 O' '",0 , 1267. 1200 O .. 0 1367. 1300 O ,., 1467. ~ 400 0 1567, 1500 O 1667. 1600 0 1767, 1700 0 1867, 1800 0 1967. 1900 0 2067. 2000 0 2167. 2100 0 ~7. 2200 0 2~67 2300 0 2467, 2400 0 2567. ~SOO 0 2667. 2600 0 2767. 2700 0 2867. 2800 O 2967. 2900 O 3067. 3000 O 3167. 3100 2 3267. 3200 4 3367. 3300 7 3467, 3400 1t 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 2 2 3 , ,. · , 1 2 3 4 5 7 8 8 9 '.9 8 7 7 7 7 7 7 7 7 7 7 7 6 6 8 14 23 37 55 76 10I ,00 ,18 .16 .29 .55 .73 ,12 ,16 o07 .t0 ,19 ,52 ,23 ,84 ,48 ,32 ,05 .79 S S S S S S S S S S S S $ S S $ S S S S S S S S S S S S S S S S ,00 ,20 ,36 1 1 .51 2.20 4 5 6.21 6.87 7,31 7.73 7.96 8.20 8,50 8.69 8.34 8,05 7,75 7,49 7.39 7,72 8.40 9.09 9,70 10.32 10.09 7.43 2.t9 5.29 15.51 28.5,5 44.76 W E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E W W W W SOHIO WELL S-9 SEC,35,TI2N,Ri2E hlEASURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY dOB ~ 1395 SURFACE LOCATION 1642 SNL, 1635 EWL FOR EVERY EVEN 100 FEET OF SUB SEA DEPTH, 6 AUG 82 KB ELEV 66,98 FT, MEASURED DEPTH TRUE VERTICAL SUB MD-TVD DEPTH SER DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 3585 3693 3803 4034 4154 42?? 4403 4529 4654 4905 5032 5160 5289 5548 5806 5934 606t 6158 6562 6687 6812 7064 7191 7318 7445 7574 7704 7834 3567, 3500 17 3667, 3600 25 3767, 3700 36 3867. 3800 50 3967. 3900 4067. 4000 86 4167, 4100 110 4267, 4200 4367, 4300 161 4467. 4400 4567. 4500 ,1667, 4600 238 4767. 4700 264 4867, 4800 292 4967, 4900 321 5067. 5000 351 5167 , 51 O0 380 5267. 5200 410 5367, 5300 439 5467, 5400 4G7 5567, 5500 494 5667, 5600 520 57~7, 5700 546 5867, 5800 57I 5967, 5900 595 6067, 6000 619 6167. 6100 645 6267. 6200 670 6367. 6300 697 6467, 6400 723 6567, 6500 750 6667. 6600 778 6767. 6700 S06 6867. 6800 836 6967, 6900 866 130,50 163,72 202,40 246.56 S 295,62 S 350.37 S 410.97 S 474,79 S 539.02 S 603.12 $ .... 6&&. 57 . S '730,4~ S .... ~795,45 S :':::: ~!!:t ;;'i 861 ,70 S !: ~,,:',~., ,,928,1 7 S 995,42 S 1 063.03 S I i30.73 S 1197.85 $ 1263,76 S 1328,65 S 1392,74 S i 455.73 S 1580.38 S t642o99 S 1706.96 S J 772,44 S 1838,67 $ 1905,03 $ 1971,60 S 2038,62 S 21 05.86 S 2175.49 S 2245,84 S 64.55 W 87,92 W 115,53 W J47.03 W 18t .73 W 219.50 W 259...'36 Id 300', 59 W 382,89 W 423,93 W 464.97 ~ 507,47' W 551 ,90 W 598.53 W 645,67 W 692,73 W ?~9.66 W 786, 06 W 831,47 W 875.69 W 918.73 W 960,60 W 1001,56 W I 041 ,83 W 1081,16 W 1120.66 W 1160,34 W 1199,97 W 1239,86 W 1281,03 W 1323,59 W 1367,73 [4 1413,01 W 1457,50 W SOHIO WELL S 9 GYROSCOPIC SLRVEY J08 ~ 3398 SEC,35,TI2N,R1'2E SURFACE LOCATION 1642 SNL, 1635 EWL ~IERSURED DEPTH AND OTHER DATA FOR EVER'/ EVEN 100 FEET OF SUB SEA DEPTH, ~ AUG 82 KB ELEV 66,98 FT. TRUE HEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 7964 7067, 7000 896 8093 7167, 71 O0 925 8220 7267, 7200 953 8347 7367. 7300 980 8473 7467, 74-00 1006 8597 7567. 7500 1030 8728 7667. 7600 1052 8841 7767, 7700 I074 896I 7867 , 7800 1094 9088 7967. 7900 I11 ~ 9198 8067. 8000 t130 9314 8167. 8I O0 1146 9429 8267, 8200 ~ 161 9543 8367, 8300 I 175 9656 8467, 8400 1188 9767 8567, 8500 ~ 200 9878 8667, 8600 121 0 9988 87¢~7, 8700 1 220 0098 8867, 8800 1230 0207 8967. 8900 1240 0316 9067. 9000 1249 '0424 9167, 91 O0 1257 30 29 28 27 26 24 22 22 20 19 17 "16 ,14 10 9 8 23~5 2384 2450 2514 2577 2638 2695 2749 2802 2853 2901 "":'"'" 2946 :" ~"" 2988 .;';iii:,; ~,~o30 ,,!: .... t , 31 05 3138 3170 3202 3233 3263 3293 ,91 S 1501.79 .14 S 1545.74 :34 S i589.87 78 S 1633.86 87 S 1677. O O i O S 1719,58 ,10 S 'f76I . 00 · 99 S 1802,56 95 S ~ 843,08 ,92'S 1882.95 ,64 S 1921 .99 08 S 1960,09 97 S 1997,39 41 S 203:3,89 ,.20 S 2068,33 ,40 S 21 0t ,78 S 2134,70 ,97 S 2167.94 7'3 S 2200.67 92 S 2232,52 97 S 2263,28 ~3 S 2293,32 SOHIO WELL S-9 S~C.3$,TI2N,Ri2~ GYROSCOPIC SURVEY SURFACE LOCATION 1642 1675 E~L 6 AUG 82 KB ELEV 66.98 FT, INTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 0 O, I OOO 1 000, 2.000 2000, JO00 3000, 4000 39~8, 5000 4.'742. 6000 5519. ?000 6316. 8000 7095, 9000 78'99, 0000 8778, 1000 ~EET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES -67, ,00 S ,00 933, 9,08 S 5.68 1933, ?',12 S ?,94 2933, 16,74 S 5,99 387i. 281.06 S 171,47 4675, 778.97 S 496,6i 5452. 1297,:30 S 854.4 6249, 1804,96 S 1179,83 7020, 2~:35,24 S 1514, 78.7,2, 2819.7'5 S i856.08 8711, :3174 53.S 171 ~ . , ',? "";,~ ";' ,, ,,,'"",,' ,, ,,. c.' " ~"" '/ ";: ':'i; ''" · ,, '~..?, i I ?i';., ,, , ................... HORIZONTAL VIEW . . SOHIO ALASKA PETROLEUM · . WELL S - 9 ...... RADIUS OF cURVATURE .... '-" ' , . GYROSCOPIC SURVEY ' ' : .... . SURFACE 'LOCATION IS ........ ~ ..... i ................... S'EC.-35, T 12N, R 12 E, U.M. SCALE! '. . . AUGUST 9~ 1982- ~ ...... _ ~ .... . .. ~ 0 :. ' ' ~ . ' '. · ~ .....; !, ,,~ ,~:¢..~~ . . _ ~ ! ................ i : .......... i ....... . · . . ~ . o -Ooo · . .; . [ . ......... = ............................................... cO e~'O0 . _ :_~ ..... AALLRE DEpTHSTvD . 'SHOWN. I ...... - ,. *OOo ................ i ~ " ! . : . · TMD = 10481~' e¢ .... ...., ~ O0 .... ...... ~ - .. : : _.. : ...... ~ ................. ........................ i '. ; i - . !.. : .... ~ - · ! . · ) . _ . ) . . . :- , . ; - ! - ; ) ! - ~ , ....... ., _ . . ; ; · ¢ ..... : ....... ...... ~ : ' i .... : : " .... : ' ' ~ Suggested 'form to be inserted in each "Active" well folder to c>~eck for timely compliance with our regulations. Operator, Well Name and N Reports and Materials to be received by: ~ ~? ~L ~ ~2~ "~' Date Required Date Received Remarks Cc~pletion Report Yes -~. Wel 1 History Yes Samples ,.~, Mud Log ,)/~ ..../.? Core Chips _.~-- · Core Description .... ~ .~ :--/\ -, · Registered Survey Platx:~,.-. :>-', . Inclination Su~ey ~ ~,::?~: ~" Dril 1 St~ Test Re~s ~ :/,. / ' Pr~u~ion T~t Re~s ~_ /~ MEMORANDUM Staz'e of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO:c, V .~~t~er ton C h a i r~aYn~' THRU: Lonnie C. Smith ( ~ / Commi s s ioner~v TELEPHONE NO: FmOM:Ben LeNorman Petroleum Inspector DATE: July 12, 1982 F~LE NO: i08A/O SUBJECT:Witness BOPE Test on Sohio's S-9 Sec. 35, Tt2N, R12E, UM Prudhoe_ ~Bay ~Unit W,ed.~n'esd~ay~ July 7, 1982 - I departed my home at 7:30 a.m. for an 8:00 a.m. showup and 9:00 a.m. departure via the Sohio charter for Deadhorse arriving at 10:30 a.m. Weather: +55°F, light wind, high overcast. BOPE tests on Sohio's S-9 began at 2:00 p.m. and were completed at 6:00 p.m. BOPE inspection report is attached. .T..hursdaY, July 8, 1982- BOPE tests on ARCO's DS 6-18 were completed, the subject of a separate report. F.rid.aff, July 9, 1982 - BOPE tests on ARCO's DS 13-30 were completed, the subject of a separate report. I departed Deadhorse via Alaska Airlines flight #54 at 9:50 a.m. arriving in Anchorage at 11:30 a.m. and at my home at 12:00 noon. In summary, I witnessed successful BOPE tests on Sohio's 02-00113,(Rev.10/79) 4/8i. Inspector STATE OF ALASKA ALASKA OIL ~'CAS CONSERVATION COMMISSION B .O. ? .E. Inspection Report Ope rator Date Representative Location: Sec Prillinq Contractor ~/~9_ _~ ~' -' /a~asing Set @ ~~F Rig #~'~epresentative /~ C~/~ _~ ft. location, General .Well Sign~ Ceneral Housekeeping ~P/~ Reserve pit ~/~_ Rig ~/~ . BOPE Stack Test Pressure ACCUML~ATOR -SYSTEM Full Charge Pressure ~ ?~-~3 psig Pressure After Closure /~ ~ dP psig Pump incr. clos. pres. 200 psig.~ min/~sec. Full Charge Pressure Attained: -~- rain / sec. N2 ~--D~ ~ao~ -~~ ~,~ d0sig Controls: Master dP~i Remote ~P/~_ Blinds switch cover ~j- ~ Kelly and Floor Safety Valves Annular Preventer Pipe Rams Blind Rams Choke Line Valves__ Upper Kelly Lower Kelly Ball Type Ins ide BOP ~est Pressure Test Pressure ~/~ Test Pressure ~/~- Test Pressure H.C.R. Valve Kil 1 Line Valves Check Valve. Choke ManifOld No. Valves _ /F No. flanges ~D Adjustable Chokes --% Hydrauically operated choke Test Pressure Test Results: Failures <%~ Repair or Replacement of failed equipment to be made within Inspector/Ccmmission office notified. I Test Time' ~-/ ~ hrs days and Distribution orig. - AO&CCC cc - Operator cc - Supervisor Inspector July 2, 1982 Mr. R. H. Reiley District Drilling Engineer Sohio Alaska Petroleum Company Pouch 6-612 Anchorage, Alaska 99502 Prudhoe Bay Unit' S-9 Sohio Alaska Petroleum Company Permit No. 82-104 Sur. Loc. 1635'EwL, 1642'SNL, Sec. 35, T12N, RI2E, UPM. Btmhole Loc. 1059'WEL, 55'NSL, Sec. 34, T12N, R12E, UPM, Dear· Mr. Reiley: Enclosed is the approved application for permit to drill the above referenced well. Well samples and a mud log are not required. A continuous directional survey is required as per 20 AAC 25.050(b)(5). If available, a tape containing the digitized log information shall be submitted on all logs for copying except experimental logs. velocity surveys and dipmeter surveys. Many rivers in Alaska and their drainage systems have been classified as important for the spawning or mlgratiom of anadromous fish. Operations in th~se areas are subject to AS 16.05.870 and the regulations promulgated thereunder (Title 5, Alaska Administrative Code). Prior to commencing operations you may be contacted by ~he Rabitat Coordinator's Office, Department of Fish and Game, Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the r~gula~i~ns promulgated thereunder (Titl~ 18, Alaska Administrativ~ Code, Chapter 70) and'by ~he Federal Water Pollution Control Act, as amended, Prior to commencing operations you may be contacted by a r~presentative of the Department of Environmental Conservatiom, To aid ua in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so Zhat a representative of the Commission may be present, to witness Mr, R. ~{, Refley Prudhoe Bay Unit -2- July 2, 1982 testing of blowout preventer equipment before surface casing ~hoe Is drilled. In the event of ~u~peu$ion or abandonment, please give this office adequat~ advanae notification so that we may have a wftne~ present, Very truly yours, C. V. Chattert°n Alamka 0tl amd Gas Com~ervation Commisaiom ' Enclosur~ Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Co~ervation w/o eucl. CVC~be SOHIO ALASKA PETROLEUM COMPANY 3111 "C" STREET ANCHORAGE, ALASKA TELEPHONE (907) 276-5111 MAIL: POUCH 6-6i2 ANCHORAGE, ALASKA 99502 June 28, 1982 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Attn: Mr. C. V. Chatterton Gentlemen: Well S-9 (44-34-12-12) PBU Enclosed are the following documents, in triplicate, for the above-named well together with our check for $100.00 to cover the permit filing fee. 1. Application for Permit to Drill, 2. Proposed Drilling Program O~tline, 3. Blowout Prevention Equipment diagram, 4. Surveyor's plat showing well location, 5. Directional map. If you have any questions, please contact either R. H. Reiley at 263-5183 or K. W. Kolthoff at 263~5176. Yours very truly, ~D~lin Eg ngineer RHR:JM Enclosures cc: Well File #17 RECEIVED - UN 2 i982 Alaska 0il & Gas Cons. Commissio. Anchorage la. Type of work. STATE OF ALASKA ALASKA O~[. AND GAS CONSERVATION CO~,,~IlSSION PERMIT TO DRILL 20 AAC 25.005 . DRILL ]~[]K lb. Type of well EXPLORATORY [] SERVICE [] STRATIGRAPHIC [] REDRILL [] DEVELOPMENT OIL r~ SINGLE ZONE '[~ DEEPEN [] DEVELOPMENT GAS [] MULTIPLE ZONE [] 2. Name of operator Sohio Alaska petroleum Company 3. Address Pouch 6-612, Anchorage, Alaska 99502 4. Location of well at surface 1635' EWL, 1642' SNL, Sec. 35, T12N, R12E, UPM At top of proposed producing interval (target) 800' WEL, 400' NSL, Sec. 34, T12N, R12E, gPM At total depth 1059' WEL, 55' NSL, Sec. 34, T12N, R12E, gPM 5. Elevation in feet (indicate KB, DF etc.) Est. KBE = 70' AMSL I 6 . Lease designation and serial no. ADL 28258 9. Unit or lease name Prudhoe Bay. Unit 10. Well number S'-9 (44-34-12-12) 11. Field and pool Prudh_oe Bay- Prudhoe Oil Pool 12. Bond information (see 20 AAC 25.025) Type Blanket Surety and/or number Safeco Tns. 2975387 13. Distance and direction from nearest town NW of Deadhorse 15 miles 16. Proposed depth (MD & TVD) 10897 'MD 9364 'TVD 19. If deviated (see 20 AAC 25.050) KICK OFF POINT 2800 feet. 21 feet 14.' Distance to nearest property o~ lease line N. of ADL 28261 400 feet 17. Number of acres in lease 2560 20. Anticipated pressures MAXIMUM HOLE ANGLE 37 Ql (see 20.AAC 25-035 (c) (2) Proposed Casing, Liner and Cementing Program Amount $200,000.00 15. Distance to nearest drilling or completed well S-2 2500 feet 18. Approximate spud date July- 10, 1982 ~30 psig@ . Surface . _4_2~j~__ psig@ ~ft: :~ (TVD~ SIZE Hole 36" 17 1/~ il2 1/~ 8 1/2 Casing Weight 20x30 Insulat 13 3/[ 72# 9 5/[ 47# 26# CASING AND LINER Grade Coupling ~_d Condl ctor L-80 BUtt L-80 Butt L-80 IJ4S 22. Describe proposed program: Length 80 2680 9811 1586 SETTING DEPTH MD TOP TVD Surface .Surface Surface I I 9311'1 8175 ! MD BOTTOM TVD 110 ' ' 110 ' 26 o", 26s0, 9811'1 8572 I 10897'1I' 9434' QUANTITY OF CEMENT (include stage data) 8 cu.yds, cOncrete 3720 cu.ft. Arcticset 1390' cu.ft. Class' G; 130 cu.ft. Arcticset' 380' cu.ft. Class G ~/18% salt See attached proposed drilling program outline. JUN 2 8 i982 23. I hereby certify th,~e foreg~ng is truj~l~co~rrect to t~:)est of my knowledge -15 ~>~ ¢' I ~ I ~ / ,-' a Oil & Gas Cons. Commissio. ,,GNED T,TLE D~g'~ict ~~ Engine~TE g' Z ¢ ~ The space below fo~ommission use ~, ~. ~eLZey - ~ ' ' -' CONDITIONS OF APPROVAL Directional Survey required APl number [~,..YES []NO 50-- O ~,~' Samples required Mud Icg required []YES [~10 []]YES Permit number Approval date APPROVED BY_ ~ Form 10-401 Rev. 7-1-80 SEE COVER LETTER FOR OTHER REQUIREMENTS . . ,COMM ISS I ON ER DATE by order of the Commission July 2~ 1982~' Submit in triplicate WELL S-9 (44-34-12-12) PBU PROPOSED DRILLING AND COFfPLETION PROGRAM Dry bucket 36" hole to 80' below ground level and cement 20"t x 30t+ insulated conductor to surface using 8 cu.yds, concrete. Drill 17 1/2" hole to 2700' and cement 13 3/8" 72# L-.80 ~uttress casing to surface using 3720 cu. ft. Arcticset II cement. Blowout prevention equipment consists of 5000 psi W'.P. pipe rams, Blind rams, and annular preventer from 13 3/8" casing point to T.D. Maximum possible bottomhole pressure is 4390 psi at 8800t TVDs-s Based on original reservoir pressure. Maximum possible surface pressure i.s 3330 psi Based on a gas column to surface from 8600' TVDss and an oil column to 8800' TVDss. Directionally drill 12 1/4" hole to 8576' TVD. Run 9 5/8'" 47#-L-80 Buttress casing to 8572' TVD and cement first stage wit~ 1390 cu.ft. Class-G cement. Cement second stage through D.V. packer collar at 2600' with. 130 cu.ft. Arcticset I cement. The 9 5/8" casing will Be-hung at surface; the 9 5/8" x 13 3/8" annulus will be ArcticPacked.. Directionally drill 8 1/2" hole to T.D. at 9434' TVD.. Cement 7" liner to 500' inside 9 5/8" casing Shoe with 380 cu.ft. Class G cement with 18% salt. Run 4 1/2" 12.6# L-80 A/B mod. Buttress IPC tubing withl3 gas, lift mandrels and a production packer assembly at 8135': TVD. A subsurface safety valve with dual control lines will be placed at 1950t'. Displace tubing to diesel, Install and test Xmas tree. Suspend well for perforating subsequent to rig release. Details of proposed perforations to be submitted on Sundry Notice to follow. ~ ~chu. ag~ B.O.P. STACK CONFIGUR/'TION 13 5/8" TRIPLE RAM STACK i i 5000 PS1 WP DRILLING ANNULAR PREVENTER PIPE RAMS BLIND RAMS 2" KILL LINE CHECK GATE GATE DRILLING SPOOL PIPE RAMS 4" CHOKE LINE GATE HYDR. ASST. GATE _ .. ,Ur',J ~ i982 OI 32 DS 04 OI 02 WELLS '° ,o_ IIH !1 T' !! ~11 II ~ PAD DETAIL PORTION OF T II & 12 N,R 12E,U.M. SCALE I": I/2 MILE SCALE I": 400' CERTIFICATE OF SURVEYOR I hereby certify that lam properly registered to practice land surveying in the State of Alaska and that this plat represents a location survey of the wellpad shown and the wells thereon. This survey was made bY me or under my supervision and all dimensions and other details are correct. Bottom hole locations are furnished by others. Date Surveyor REVISED BHL S.IO R, I1 i DELETED BHL S.7,8,~,9. ADDED PROPOSED BHL S-7,e,9,& I0. Gas 6OHS. 6omrni 5/24/82 PAD "S" Lo coted in PROTRACTED SEC.35.T. IZN.,R. IZE.,UMIAT MERIDIAN, Al(. Surveyed for SOHIO ALASKA PETROLEUM CO. Surveyed by F. M. LINDSEY 8~ ASSOC. LAND I~ HYDROGRAPHIC SURVEYORS 2_502 West Northern Lights Boulevord Box 4-081 Anchorage, Alaska A- !z588- 81 FOR PR090~I) I/rr_LL ~-9 COURS~ LII~ CALCLIL~TIOH FGR UELL S-9 ~OT?I~ 6t7193,39 5976~?Bo53 ~.t5 tWTE - flt,L DEPT~ 1H FEET 8ELOU KL-LLY IRtSHIi~ (ig(~) UERTI C~I, INTERI;ECT I(~i /PROPOSEDx ..'XEN~ B'Y% UF.~TICA~ TL,'D oEpi:~r TUO ~P~T DI~'Tla~iCE VE~IO~ ~.3 ? DEGREE LEAD LIKE ¢;tLCU~,;JTIO~J FOR 5-9 TOP 619797.88 BOTTOR 617648,8D E~TG927,76 ALL DE:PTH6: 'ZI~t FEET ~i~LOU KELLY ~'USHZHG {BLOB) I, IE:LL IDEHT ~PROPOSED~ R 3 !~"/~,, T 4383,e H ~ ~J49,5 E:Se4. ! ~ 8 4783,6 9~3,9 S 3 t~2.9 ..... -r- .... :-;'~ 'l-; -FT~ -i "i-T~-I-" ~¥ i i -i --~-i-I--?- -q -ri--i- T-i , ~ :-i--"--I-.. :T-;,--'"i-~i..~ ~--i-i i /_1 ~ ! 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I i I I I I I I I i j I j I I i I I t I i t/I ~ ii~ i it i i IIIt II1~ It I ~ tlii ill I ~1i II i I I vii tlli ttlt ~tl ~111 It it il It iti~ ~,,i'i~ '~itll~i~i itil '~l~ ~,~ i,~l i ~l~ll~ iiiiiJi i!lllllll Iltt I~ Iltl ttt~ I !il,~/~i.:iili itti i ti t!!! tl!t J!!! ii! i~,!~ti ~l~ll!ltl tilt ii !itl '1t!i ! !ili/!!i ]~. i~tl Itilllltt Iitl ii Ii i J t i II I itltill CHECK LIST FOR NEW WELL PERMITS Company Lease & Well No. ITeM APPROVE DATE 2.3. 4. 5. 6. 7. 8. (3) Admin ,.<~:~/..-- ~' ~ % X"~ 9. (9 thru 11) 10. 11. (4) Casg ~~ ~'~f-Z~ 12. (i2 thru 20) 13. 14. 15. 16. 17. 18. 19. 2O, (1) Fee (2) ~.oc YES NO Is the permit fee attached .......................................... Is well to be located in a defined pool ............................. Is well located proper distance from property line ................. Is well located Proper distance from other wells .................... Is sufficient undedicated acreage available in this pool ........... ,,,.-~ ~_, Is well to be deviated and is well bore plat included ............... Is operator the only affected party ................................ Can permit be approved before ten-day wait .......................... ~_~._~ Does operator have a bond in force ........................... Is a conservation order needed ... ...... !!] ii ' i .... i'i~-" Is administrative approval needed ....... "' Is conductor string provided ........................................ Is enough cement used to circulate on conductor and surface .......... Will cement tie in surface and intermediate or production strings ... ~_~ Will cement cover all known productive horizons ..................... /;~... Will surface casing protect fresh water zones ....................... Will all casing give adequate safety in collapse, tension and burst.. Is this well to be kicked off from an existing wellbore ............. Is old wellbore abandonment procedure included on 10-403 ............ 'Is adequate well bore separation proposed ....... ' .................... (5) (21 thru 24) 21. 22. 23. 24. Is a diVerter system required ....................................... Are necessary diagrams of divcrtcr and BOP equipment attached ....... ~a- Does BOPE have sufficient pressure rating - Test to ~-'~ psig~.. ~ Does the choke manifold comply w/API RP-53 (Feb.78) .................. (6) Add: 25. Additional requirements ............................................. ~ REMARKS Additional Remarks: Geology: Engin~er(ing: rev: 01/13/82 INITIAL GEO. UNIT ON/OFF POOL CLASS STATUS AREA NO. SHORE 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 APPENDIXi .. No special'effort has been made to chronologically organize this category of information. bis T~PC VERIFICATION LISTING LVP O,IO,HO1 VERIFICATIO~,~ LISTING PAGEi I ** REEL HEADER ** SMRVICE NAMM :SERVIC DATE :8~f08/26 ORIGIN : REEL NAME :REEL ID CONTINUATION ~ :Ol. COMMENTS :R~EL COn, MEETS ** TAPE HEADER ** SERVICE NAME :SERVIC DATE ~08/26 ORIG! 070 TAPE NARE :65424 CONTINUATION PREVIOUS TAPE ~OMMENTS COMMENTS :TAPE EOF ***$****~* ** FILE HEADER ** FILE NA~E :$ERVIC,O0~ SERVICE NAME : VERSION # : DATE ; MAXIMUM LENGTH : 1024 FILE TYPE PREVIOUS FILE : ** INFORmaTION RECORDS ** MNEM CONTENTS CN : SOHIO WN : FN : PRUDHOE B~Y RANG: ~E TOWN: SECT: 35 COUN: NORTH SLOPE STAT: ALASKA CTRY: U,S,A, ~NE~ CONTENTS PRES: DILOO1E ** RECORD TYPF, 047 ** UNIT TYPE CATE SIZE (.0 E, 000 000 O06 065 000 000 004 065 000 000 012 065 000 000 003 (!65 000 000 003 065 000 000 002 065 000 000 012 065 000 000 006 065 000 000 006 065 UNIT ~YPE CAT~, SIZE CODE 000 000 007 0 b 5 'R , LVP 01. O,HOI VE, IFICATION LISTING PAGe1 2 ** RECtRD TYP 04,7 ** ** RECORD rYP .... 04:7 ** ** COMPENTS ** SCHLU ALASKA COMPUTI G COMPAMY WELL FIELD COUNTY STATE SOHIO ALASKA PETR[)LEUM C['~MPANY 8-9 PRUDHOE BAY NOR:TM SbOPE BOROUGH ALASKA JOB NUMBER AT ACC; 10707,65424 RUN #~, DATE bOGG.~.sD: ~8 JULY 8~ [,DP: BOTTOM DEPTH TOP DEPTH CASING BIT SIZE TYPE FLUID = 104~2 = : 1,3 3/8 I~, X FT, = DURENEX bVP OIO,HO1 VERIFICATION bI~ItING P,AGE 3 DENSITY = 9,8 LB/G VISCOSITY -- 4,5 S PH -- FLUID LOSS = 4,0 C3 RMC =2'340 AT ~0,0 R~ AT BHT : 1,~99 AT 165 MATRIX LIMESTONE TNIS LISTING REP.RE$~]~TS A MERGED PRODUCT, RUN #I, AND RI1N JOB NUMBER AT ,ACC: 1t~707,65423 RUN #1, DATE LOGGED: 1,5 JI]L,Y 1982 LDP~ HGH BOTTO~ DEPTH TOP DEPTH CASING BIT SIZE TYPE FLUID DENSITY VISCOSITY 870o 2650 13 3/8 IN, SURF, ~2 1/4 IN, DURENEX 9,7 LO/G 36,0 S LVP OIO,HO1 VERIFICATION LISTING PAGg 4 PH FLUID LOSS RMF R~C R~ AT BHT MATRIX LIMESTONE 9,5 4,2 C3 2,650 8 72,0 DF 3.050 s 72,0 DF 2,220 ~ 72 0 DF ** DATA FORPAT RECORD EMTRY BLOCKS TYPE SIZE RMPR CODE ENTRY 8 '73 9 4 ~5 0 ~ 66 0 DATUm SPECIFICATION BLOCKS MNEM SERVICE SERVICE UNIT API .APl APl APl FILE SIZE PROCESS SAMPLE RMFR ID O~DF;R # hOG TYPE CLASS MOD a~O, DEPT FT 0 0 0 0 0 4 SFLU D IL OH~ 7 0 0 0 0 4 ILN DIL ON~ 7 0 0 0 0 4 I[,D DIb DHM~ 7 ~.~ 46 o 0 4 SP DIL ~V 7 1 0 0 0 4 GR DIL GAPI 7 31 32 0 0 4 NPHI FDN PU 42 68 2 0 0 4 GR FDN GAPI 42 31 32 0 0 4 CAbI FDN IN 42 28 3 0 0 4 DRHO FDN G/C3 42 44 0 0 0 4 NRAT FON 42 42 ~ 0 0 4 NCN[, FDN 42 34 92 0 0 4 FCNL FDN 42 34 93 n 0 4 DT BHC US/I;' 60 52 32 0 0 4 GR BNC GAPi 60 31 32 0 0 4 L E v E [., C (3 O F, 0 I 68 0 1 68 0 1 68 0 1 68 0 1 68 0 1, 68 0 1 0 ~.. 0 1 6~ 0 1 0 1 .68 0 1 6 ~ DATA LVP 010.H01 VERIFICATION LISTING DEPT 10488 0000 SF~LtJ SP -999,2500 GR GR -350,~000 CALl NCNL -5624, 000 FCNL DEPT 10400 0000 SFI,,U SP -38,84.55 ¢;~ GR 51,84237 CALI NCNL 3098.0000 FCNL DEPT 10300 0000 SFLU SP -85,1:208 GR GR 27.,0625 CAbI NCNL 2940.000o FCNb DEPT I0200,00OO SFLU SP '72,6812 GR 6R 31.2813 NCNL 2794,0000 FCNL DEPT 10100 0000 s...LI]F SP -68,7005 GR R 34,2187 C~LI ~CNL ~808.0000 FCNL DEPT 10000 0000 SFLU SP -15:4590 GR R 91,0000 C~,LI ~CNL 2418,0000 FCNL DEPT 9900,0000 SFLU SP -11,4783 GR GR 88,8750 CALl NCNL 1811,0000 FC [, DEPT 9800,0000 SFLU SP -7,4976 GR. G~ 102.6875 CALl NCN~ 1910,0000 FCNL DEPT 9700,0000 SFLU SP '14.4638 GR GR 94 7500 CALl NCNL 1833:0000 FCNL OEPT 9600,0000 SFLU SP -7,0000 GR GR 999.2500 C~£,I NCNb :999.2500 FCNL DEPT 1500.0000 SFL[{ SP -30,8~41 GR GR 999.2500 C~LI -999,2500 IbM -999,2500 NPHI 4,4297 13R80 '4896.OO00 DT 7,7148 38,0625 N.PHI 11 9141 I)RNO 1256:000o DT 6,2734 IL~ ,2187 N P H I ,9141 DRHO 115b,0000 DT 5,4688 II.,M 40,5000 11~7891 DRHO 964,5000 DT I,7656 ,9375 11,9844 DI~HO 996.5000 12 6797 87,6875 13,6094 8.]0,5000 DT 2,2656 ILM 84.6875 NPHi 17,8281 DRM[') 452,7500 PT 3,1.348 IL, a 103,4375 aPHI 18,9844 DRH~ 450,2500 DT 2 1035 Ih~ 88i5625 18 9687 DR~'JU 412,O000 3,7109 73,0000 ~.iPHI -999,2500 DRHO -999,2500 4 0000 iI,,a 73:1875 ~PMI -999.2500 DRHO -999,2500 4.6~75 2 '16 8, o () 0 o -999.25OO 6. 1562 ILD 17.2363 R H.O~.~, 0,023q aRAT 71. 5625 GR 90213 ~LD :0430 R~OB o,0542 NWAT ~5,1875 G~ 5,3555 ILD 21,4355 RHOB 0,050~ N~AT 87.5625 GR 10.8984 IL, D 22.3633 RHO~ 'O.0039 N~AT 84.5625 G~ 1,9434 I!,,,D 36,3281 BHOS (i),0298 NR.~T 1.09.3750 '' 3,1699 IbP 33.39B4 0.0317 107,1875 1,8535 ILD 39.4043 0.1494 NRA]' ~02.3750 3,3301 ILO -999.2590 R}.!c~ -999.2500 NR~q' 85.7500 G~ 3,5410 ILO -999. 2500 RHOL~ -999,2500 {J ~ ~T !9998, 250u -3 76 .0C)00 1., o~15 999. 2500 680 77 0 38.0625 3,554'7 2,3105 2.~980 23, ~'1 6 2773 2,~242 2,..563 40.5000 12,5391 2,3535 2,65~3 3~.9375 10,3750 2.7656 87,6{~75 1.,7998 2,3516 3,8008 84,6875 3.1309 2.4785 3,6~06 103.4375 1.7910 2,3066 4.0273 88.5625 2,9941 -999.25O0 -999.2500 73,0000 3.3379 -999.25O0 -999.250() bVP 010,H01 VERIFICATION bISTING PAGE 6 NCNb -gg9.2500 FCNL DEPT 9~00.0000 SFL{1 SP . 33,3'720 GR GR -999,2500 CALl NCNb -999,2500 FCNI.~ DEPT 9300,0000 SFLU SP -36,3575 GR GR -99.9,2500 CALl NCNb -999.2500 FCNL DEPT 9200 0000 SFLU SP .,31 3817 G~ GR -999 2560 CALI NCNb -999 2500 FCNL -999 3 69 -999 -999 61 -99g -999 -999 -999 DEPT 9100,0000 SFLU 1 SP '2'7,4010 GR 87 GR -999,2500 CALI -999 NCNb -999.~500 FCNL -999 DEPT 9000 0000 SFLU SP -35~$599 GR GR -999,2500 CALI NCNb -999.2500 FCNL DEPT $.900,0000 SFLU SP , 34,8647 GR G~ .99.~,2500 CALl NCNb ,2500 FCN[,, DEPT 8800 0000 SFLU SP -32,3768 GR ON -999,2500 CALI NCNb -999.2500 FCNL DEPT 8Z00.0000 SFL, U SP 26.4058 GR G~ 81 0625 CALI NCNb 1760:0000 FCNL DEPT 8600 0000 SFLU SP -27i8986 GR GR 93 8750 CALI NCNb ~973 0000 FC~L DEPT 8500,0000 SFLU BP -29.3913 GR GR 90 5000 C~LI NCNb 2054~0000 FCNb DEPT 8400,0000 SFLU SP -31,8793 OR 2 83 -999 -999 3 60 -999 -999 2 73 -999 -999 , 91 13 384 2 84 15 545 2 84 15 562 62 . ( ,25 )0 3926 6875 25OO 25O0 ,B086 ,6~50 ,2500 ,2500 5625 ,375o ,2500 ,2500 6973 '3125 O0 .2227 ,4375 ,2500 ,2500 ,74.22 .1875 ,2500 ,2500 7500 ,2500 ,2500 ,2500 6582 '6875 ,8750 .0000 ,7871 ,5625 .3047 .5000 7539 i8750 1172 5000 ,9531. ,6875 D T L M PHI DRHO i LM NPHI DRHO D T I bM NPMI PRblO DT Ib~ DRHO DT I L M NPHI D R H O UT ILM NPH I DR}~O DT .NPHI DT IbM DRHO ILM NPHI ORHC DT I NPHI ORHO DT I NPH I ~1.3750 GR 3.51.56 -999,2500 -999.250o 82.5625 GR 2 9(509 .-999' 999' ~500 RHOR .2500 N R A T 87,7500 GR 1.391,6 IL, D -999,2500 RHOB -999,2500 NRAT 110,5625 GR 6055 '99 2500 -999 ~500 -9q9 500 ILD R~40~ NRAT ~,2734 ILD -999,2500 -999,25()0 -999,2500 4,3359 I, bD -999.25{)0 RHOB -999,25U0 NRAT -999,~500 G~ 1.5293 II,I) 4.1.7969 RHOB 0.0146 NRAT -999,2500 GR 2.7988 ILD 31,7871 RHOB 0.0200 NRAT -999.2500 GR 2.7402 ILD 29.2480 RHOb 0.0352 NR~T -9g9.2500 GR 3,3613 II, P 27.0996 R~Oi~ '13. :1. ~? 75 3.3027 999.25 )0 - 250 n 99~, 69.~75 1,2803 -999,2500 -999,2500 91.3750 '.3~ 1,53. 2 -999,2500 '999,2500 'gg~9 ~ 2500 2.1777 -999,2500 -999,2500 -999.2500 4 0820 -999,~500 -999,2500 -999.2500 2.9160 999 , 2500 :999.250o -999,250o 1,3760 2.4102 4,0508 -9q9,2500 2.7539 2.5215 3.4355 -999.2500 2,6563 2.4512 3.2676 -g99,2500 3.2F91 2. 500 (.~ bVP 010 HO1 VE..RIFICATION LIolYlNG PAGE 7 GR NCNb DEPT GR NCNb DEPT NCNb DEPT NCNb SP NCNb 73,31.25 CALI 225@,0000 FCNb 8300,0000 SFLU -32,376B GR 82,0625 CALl 2042,0000 FCNL 8200 0000 SFLU -30~3865 GR 87,2500 C~LI 1838.0000 FCNL 8100,0000 SFLU 32.8744 UR 87,1250 CALl 1809.0000 FCNL 8000 0000 S~LJ -32~3768 GR 90,7500 CALl t934.0000 FCNL DEPT 7900 0000 GR 87.02500 ~AC, I ooo DEPT SP Ge NCNb DEPT NCNb 14.9609 661,5000 DEPT SP GR NCNb : 8555 8 0000 0000 DEPT SP GR NCNb 1,9766 93~2500 15,5625 457~5000 7800.0000 SFI,,U -31.8793 GR 59,0625 CALI 2700,0oo0 FCNL 2,01.37 ~4'5000 1.5,~750 456..000 7703010000 SFLU - 5 3624 GR 77 9375 CAb[ 2228 0000 FCNL, 2,5508 :l 5, 75 48 i. 5000 902 750 '9297 '7500 7600.0000 SFLU 49,7923 GR 58,1250 CALI 2 60.0000 FCN[. 2 351.6 56,2500 14,0156 902.5000 7500,0000 SFLU -40,8358 GR 195.3750 CALl 1913,0000 FCNL 6,9727 71,6250 1.5,9609 698.0000 DEPT 7400.0000 SFLU SP -42,8261 GR GR 201.3750 CALI NCNb 1704,0000 FCNL 9.5156 55 9375 15:9297 788,0000 DEPT 5,1367 180,3750 15,8906 474,0000 4,2891 172,0000 15,4141 402,5000 7300.0000 SFLU 2,3066 DRNO DT NPH I DT NPHI D~.HO DT NPHI DRMO OT Ib~ NPHI DRHO IL~ MPHI DRHO DT NPH.I DRHO DT NPHi DRH(] DT Ib~ NPHI DT IbM NPHI DRHO DT I!,M NPHI DRHO DT , O361 hRA'P -99'. 2500 GR 3,0078 31,494:1 0,0254 -999,2500 2,0859 33,7891 RHOB 0,0571 NRAT -999'~500 8055 ILD ,0~64 NWAT -999.2500 GR i .494' 1 I L D 3 ~8145 RHOR ~:0142 NRAT -99 2500 GR 2,9t)2] lb[) 24.1.699 RHO8 0.2222 NR.IT -999,2500 GR 5.5'78l IbD 26.7090 RHOB 0.0762 NRAT -999.2500 GR 8,1.406 21.6309 0,0537 N~AT -999.2500 GR 3.2480 IbD 34.4~3~ RHOB 0,0371 ~JRAT -999.2500 GR 3,5352 I[.,D 39,1.1,13 RhOB 0.0596 ~.AT -999.2500 GR 2.3065 lb0 3,1191 '999,2500 2,97~6 2,4:395 3,4199 '999,2500 1,9951 2,.4219 3,~379 -999,2500 4'13 3,5684' -999.2500 2.6504 1,3926 ,8047 -999,2500 2.4355 2,4102 3,6504 '999,2500 3,5020 2,7012 2,8965 -999.2500 5.5547 2,4902 3,1191 -999'2500 B.7969 2,359a 2. 7777~ -999,2500 3 298~ 3,6270 -999,2500 3.5077 2.3457 3,918n -999,250C 2.3~09 LVP O10.M01 VERIFICATION LIoI'ING PAGE SP -38.3478 GR GR 86,~000 CALI NCNb 2052. 000 FCNL DEPT 7900,0000 MFLU SP -3~, 86~7 GR DR 8 , 43 5 CALI NCNb 2112,0000 FCNL DEPT 7100,0000 SFLU SP -39,8406, GR 9375 CALl GR NCNb 2326.0000 FCNL DEPT 7000,0000 SFI,;U SP -38,3478 GR GR 83,1250 CALI NCNb 1696,0000 FCNL 73 15 545 2 80 15 667 3 83 14 649 13 421 DEPT 6900,0000 8F b J 2 SP -42.3286 GR 94 GR 102,02500 CALl ~. ~CNL 2043, 000 FCNL 5 DEPT 6800 000o SFLU SP -41,3334 GR GR 87,8125 CALI NCNb 1924,0000 FCNb DEPT 6700 0000 SFbU SP -41i8309 GR G~ 87 0000 CAbi NCNL 2108 0000 FCNL DEPT 6600 0000 SFLU SP -41,3334 GR OR 75,0000 CAbI NCNb 2434,0000 FCNL DEPT 6500.0000 SFLU SP -44,3188 GR GR 80,3750 CAbI NCNL 2108,0000 FCNL DEPT 6400,O000 $FLU SP -43,3237 GR GR 79,0000 CALl NCNb 9056,0000 FCNL DEPT 6300,0000 SFLU SP -38,3478 GR GR 74,1875 CALl NCNb ~196,0000 FCNL 2 75 16 531 2 82 15 597 4 68 14 723 3 73 15 606 3 67 15 562 4 69 14 6]6 ,3125 ,3438 , 0000 8145 3'150 0000 , 125 ,0000 ,1914 ,5625 ,8203 ,7500 ,9863 ,6250 ,~a75 . 0 () 0 4863 ,3750 ,6875 .5000 ,8574 ,9.]75 3281 '5000 ,2773 ,6250 .3125 .0000 .3574 ,3750 ,6875 ,5000 ,6074 ,187b .9297 .5000 .9453 ,5000 ,7031 ,0000 N P [~ I l') R H O DT N P H I: DRHO DT lb~ DRHO DT .I [,,~ N. NPHI P R HO I bM N P N I DRHO DT N PHI DRHO DT NP}~I D T IL~ NPHI DRHO DT I NPN]. DRNO DT IL~ NPHI DRHO DT NPH I DRHC DT 31,2500 O, 298 ~ RA'I ,,,999, ,500 '2 9277 ILO "26 ,318.4 0. 0605 -999,2500 3,4453 28,7109 0,0 ,] 9 I, -999,2, 500 2,35120 38,134.8 0.1201. -999. 2500 GR 3,2520 29.9~()5 0 ~47q NRAT -ggg: 500 2.80~6 II..,[') 30,1~70 ~0~ 0,0933 N~hT -999,2500 gk 3,2031 IL.D 31,0()50 0 0498 -999:2500 GR ,4,4453 I!,D 31,2500 -999,2500 Ga 3,5156 II, D 31,445] RHOB 0,0830 ~OFAT -999,2500 GR 4,2305 I[.D 30,2246 R~OB 0,0'361 NRAT -999.2500 (;R 4.5352 ILD 28,759~ R~OB 0,0942 N~AT -999,2500 GR 2.4:043 3,4043 -999,~500 3,0337 2,425~ 3.0723 '999,2500 3,~023 2, 57~ 3,21C9 -999,2500 4316 2.3672 2. '-t, 814'5 -999,2500 2, 84. 3,3555 -999,2500 2,87,30 2,4238 3.3633 -999,250o 3,2324 2.44:14 3.3867 -999,2500 4,257~ 2,3848 3,3750 -999,2500 3,5781 2,4707 3,4258 -999,2500 4.3789 2,3926 3,351.6 -999.2500 4,7'773 2,~590 3,2246 -999,2500 bYP 010,H01 VERIFICATION bi. TING PAGE 9 DEPT 6200 0000 SFbU SP -44,3188 GR GR 79,3125 CALI .NCNb 2252,0000 FCNL ]1523 6 3125 i5,6875 606,5000 OEPT 610:0,0000 SFLU SP '47,3044 GR GR 78,8750 CALI NCNb 2008,0000 FCNL 72, 50 15,6016 570,0000 DEPT 600~,0000 SFbU SP -5 ,777.8 GR GR 84,7500 CALl NCNb 1943,0000 3,8887 83,1250 16,7655 560,0000 DEPT 5900 0000 SFLU SP '49,~92] GR GR 69, 875 CALI NCNb 24~0,0000 FCNL 5 ,7422 ,7813 15,5859 650,5000 D~PT 5800 0000 SFLU SP -48:7971 GR GR 7~,5625 C~LI NCN5 {93 ,0000 FCNL $7,0000 15.4453 539.5000 DEPT 5700 0000 SFBU SP '60' ,7391 GR GR 72,1575 CALI NCNb ~406,0000 FCNL ],9258 65,0000 16,7031 648.0000 DMPT 5600.0000 SFLU SP '83,1304 GR G~ 54'0000 CALl NCN5 2544.0000 FCNb IbM D{~ FtC3 DT DEPT 5500,0000 SFLU SP -105,2730 GR .NCNb 2096,0000 FCNL I, Lg NPHI DT DEPT 5400 0000 SFI, U SP -85'1208 GR . GR 55,5938 CILI NCNb 2374,0000 FCNb I NP~fI DRMO DT DT I I.,~ NPMI DRMO I LN NPNI D R H 0 DT 5 1719 51,8437 NPHI 15,1172 627,5000 DT 6 6094 59,9062 14,1875 608,0000 5 2539 57~2187 16,4844 737,0000 DEPT 5.300,0000 SFLU .~, 9629 SP 78,154b GR 5 ,5938 GR 67,6875 CaLl 15,4453 NCNI_, 2186.0000 FCNL 593,5000 DEP? 5200 0000 SFLU SP -130i4010 UR G~ 31 8437 CALl NCN]i, 2374 0000 FCNL 5,1523 29,7656 12,8281 631,5000 I [,~ iV~ NPHI DRRO DT DT I LN NPHI. DR H E'., PT D ~ H O D T 3.877 o 30. 8594 -999,2500 3,~566 29, g75 0,0728 NkA, i 9.2500 G R 4.5000 ILD 32 12~9 RHOB 0:077! NRAT -999,2500 (;R 4.,6914 lbD 31.. 1523 RHOB 0,0181 N ,A.I -999. 2500 GR 2,7~13 30,2246 0.0~79 N~IT -999.250O GR 4.4375 lbo 27.2~49 RHOB 0,1069 {'~RAT -999.2500 GR 4,93"15 IbD 32,2754 RHOB 0.0938 N~AT -999.2500 GR 5,77'73 1[.,I~ 31,8848 RHOB 0.032'7 ~RAT -999.2500 Ga 4.9297 24,9023 0,0786 -999,2500 4,9375 ILD 33.2031. RHO[~ 0,0981 Ni~A'I; -999.2500 Gq 2,t~q5 I[,D 30,5664 ~HOg 0,0225 NR~T '999,2500 GR 4.1055 2,40(,3 3,3848 -999,250u ~, 7969 2,3906, -999,25{)0 4. 8789 .~:4648 4980 999,250 .. 4,7422 2.386'1 3,4043 -999.2500 3.0273 ,3145 ,3379 -999.25o0 4 7 2' ,453,1, 3, 1797 -999.25o0 5,039~ 2,4121 3,4648 .999.250o 5 6055 2]2305 3,4141. -999.~500 4.4922 2,3359 3,0137 -999,2500 5.5430 2,4727 3,5332 -999,2500 !,759& 2.1'719 3.2910 '999,2500 hVP 010,HO1 VERIFICATION [,,]:STING PAGS~ 10 DEPT 5100,0000 SFbU SP -81,4375 GR GR 61,9375 CA[,I NCNb 2320. 0000 FCN[, DEPT 5000,0000 ~. [ LIJ SP ~105,5000 GR GR 46,0000 C~.LI NCNb 322,0000 FCNL DMPT 4900,0OO0 SFLU SP -127,~500 GR GR 35,21 B7 CALl NCNb 2036,00OO FCNL DEPT 4~00,0000 SFbU SP 8~,]625 GR G~ 6 , 750 C.ALI NCNb 2~06,0000 FCNL DEPT 4700,~000 SFL[{ SP -56, 562 G~ GR 76,3125 CALI NCNb 2037,0000 FCNL DMPT 4600 0OO0 SF[.U SP '56,781.] GR GR 51,2500 C~t~I NCNb i952,0000 FCNb DEPT 4500,0000 SFLU SP -53,6875 GR GR 55,8750 CAI, Ii NCNb 2466,0000 FCN[, DEPT 4400,0000 SFLU SP -53,0625 OR GR 66,0000 CAbI NCNb 2t64,00{)0 FCNb DEPT 4300 0000 SFLU SP -59~2500 GR OR 51 7188 CALI NCNL 2296:0000 FCNL DEPT 4200 0000 SFLU SP -75,8750 GR GR 53,3750 CALl NCNL 2018,0000 FCNL DEPT 4!00,0000 SFLU SP 81,4375 GR GR 56,3125 CALl 15,2187 613.0000 3,8164 44,6250 14,7031. 654,5000 11,6484 34,6875 ~,1875 5 ,0000 3 2793 61 5625 14 1t72 646 5000 6~,7656 16,7500 490,5000 3.4063 52,8750 14,1562 417,5000 3,0996 57,8437 15,8203 580,0000 6,2383 59,5000 15,9297 621,0000 7,9766 40,0625 14,6719 594,5000 4,8789 59 0625 14:0547 543.5000 8,7656 55.3438 14,4141 DRHO NPHI DRMO DT ILm IbM NPHI DRHO OT ILM NPHI ORH~ DT IL,~ ~ P H I DT ILN~ NPHI DR 5,6367 33-1055 RHOB 0,0552 NRAT '999,2500 GR 3,2617 29,8828 R~Ot3 -999,2500 6 5547 IbP 29 4922 RHOB fl O35~ NRAT -999 250O GR 3,3867 .'tl,9,)36 RHOB 0,0366 NRAT -999,2500 OR 3 5176 IbD 37 5977 R~C3B 0 0376 NR~T -909 2500 G~ 3 . 26 1. 7 I [,,D 42 3340 RHOB 0:003,4 ~T -999,2500 GR 3.5840 I[..D 43,0176 RBOB 0,0386 NRAT -999,250() G.R 4,~.461 33,1055 RHOB 0.0537 ~RAT -999,250o GR 8,0703 ILD 34.4238 R~OB 0.0063 NRAT -999.250o GR 4.4102 IbD 35,2539 RHO~ 0.o~29 N~AT '999,2500 GR 7,9180 38,0371 0,0283 .3867 3,5~15 -999.2500 3, 98 -999,2.500 '7461, : ii 367 2598 -999.2500 ~,2930 ,416f) 8555 -99.30:2500 3,3223 2.0176 4.093~ '999,2500 3,9395 2,1504 4.1836 -999.~500 4.578! 2,2539 3,5410 '999.2500 9,3828 2,1680 3 5918 -999.'25o0 4,4922 2.1250 3,6.509 -999,2500 8,3750 2,1055 3,8223 bvP OIO.HO1 VERIFICATION LISTING PAGE 1.1 NCNb 204,~ ,0000 MC ~IL DEPT 4000 0000 SFLU SP -78,.3750 GR GR 35,5313 CALI NCNb 1396.0000 FCNb 473 14 29 16 247 DEPT 3900,~000 SFLU 5 Sp -90, 625 ~ 53 GR 46,062:5 Ab! 4~ NCNL 1751.0000 FCNL DEPT 3800,0000 SFLU SP '71,5625 GR GR 48,]750 C~LI NCNb ~345,0000 FCNL DEPT ]700 0000 SFbU SP -82,6875 GR GR 56,4063 CALl NCN[, 1796,0000 FCNL DEPT 3600. 0000 SFbU SP '73~4375 GR. GR 72,0625 CAL! NCNb 1774.0000 FCNL DEPT 3500 0000 SFLU SP -96:2500 GR GR 62,2813 CALl NCNL ~776,0000 FCNL DEPT 3400,0000 SFLU SP '76,5000 GR GR 60,1875 CAbI NCNb 1553,0000 FCNL DEPT 3300,0000 SFLU SP -111,0625 GR GR 39,0313 CaLI NCNb 1702,0000 FCNL DEPT 3200 0000 SFLU SP -82~0625 GR GR 66,2500 CAt, I NCNb 1650,0000 FCNL DEPT 3100,0000 SFLU SP -91,3125 GR GR 51,3438 CALl NCNb 1615,0000 FCNL DEPT 3000,0000 SFLU S.P -i14,8125 GR 6 42 18 376 7 49 15 463 6 61. 17 422 4 41 14 441 6 67 17 390 6 36 13 411 6 64 16 396 7 59 14 441 5 42 .2500 0703 ,32 1 '5156 ,8'150 D T l LM NPHI DT -999.2500 (;~ 13.9~,~.53 56,5918 Ri-iOS 0,03133 NRA,~~ -999.2500 GR ,8945 .IL~ 7,6250 ILD ,7188 NPHI 35,1.562 ,5859 DRHO 0,0288 ,2500 DT -999~2500 GR 8594 ,9687 ,1875 ,250. o 1211 :9687 ,671. ,2500 3594 ,5625 ,7656 ,5000 ,~727 , 188 9883 ,3125 ,7969 ,5000 ,2383 ,3438 ,7656 .5000 ,6016 ,4375 ,7031 ,0000 IbM NPHI D R H O DT NPH]' DRHO DT NPHI DRHO DT ILM NPH! DRHO DT IbM N PH 1 DRHO DT !LM NPHI DRHO DT IbM NPHI DRHO DT IbM NPHI DRHO DT I N PHI !211 ,0625 .0859 ,2500 .4649 ,5313 5,4'297 ILD ~3,3105 RHOB 0,01.32 NR.AT -999,2500 GR 6,9375 ILD 35.8887 R~'~(')B 0,0063 NRAT -999,2500 GR 6.5547 ILD 36,0~40 Rt.'40B 0,0630 N~AT -999,25OO (;FI 5,6367 39,84.37 0,0522 -999.2500 GR 6,8086 IbD 36,621.1 R~OB 0.0630 NRAT '999,2500 GR 6,0781 lbo 39,1!.1.3 RHOB 0,0044 NRAT -999,2500 GR 7,2031 IbD 39,3555 RHOS 0.0498 NRAT -999.2500 GR 5,9648 ILD 40,7715 PHOB 0,01,17 NRAT -999,25oo GP 4,3281 IL,[) 39,1602 ~NCiB -999.25OO 15,61.72 1,5264 5,0~9~ -999,~500 ,,,1211 .90~'6~b0 ,250O 11'i65~ 1, 95: 4. 65[: 2 -999, 500 7.2031 2.1445 3,~14~q -999. 500 6 5547 2' ,2852 3,7832 -999,2500 6 1953 2:2480 3,~531 -999. 500 7,3.438 2 2813 3~8203 -999,25t'0 6.1953 2,07@1 3,8750 -999.250O 7.4805 2,3066 3,9687 -999.250O 6,679'1 2,2148 3.9922 -999,2500 4.0898 2.0~59 LVP 010.H01 VERIFICATION LISTING PAGE 12 GR 38,2500 CALI NCNL 1405,0000 FCNL 1.4,3125 DRHO 330,0000 DT DEPT 2900,0000 SFLU SP -8t,4375 GR GR 64,~375 CALl NCNb 1.327, 0OO FCNL 7,2578 I L 60,7188 N P H 3~,8750 DRHO · 2500 DT DEPT 2800,0000 SFI,,U P -109 8750 GR ~R 40' ,9375 CALl NCNb 1334.0000 FCNL 6,7305 IL~ 40,9062 i. 7,9531 305,0000 DT DEPT 2700,06~)00 SFLU SP "74, 75 GR GR 53.281] CALl: NC N L 1231.0000 F C I~ b 3,8887 58,2500 NP~I ~. 1438 DRHO 1 , 750 DEPT 2654 0000 S~I..,.J SP -999 2500 GR GR ,I0!093~ C~L! NCNb 1386 0000 FCNL -999,2500 I'l..,)~ 1.2, DRH[) 281,, 0000 DT ** F~'Ibg TRAILER ** FILE NAME :SERVIC,OO1 SERVICE NAMf] VERSION ~ : DATE : MAXIMU~ LENGTH : 1024 FILE TYPE : NEXT FILE NA~E ********** EOf' ********** ** TAPE TRAILER ** SERVICE NAME :SERVIC DATE :B2108/26 O~IGIN :1070 TAPE NAME :65424 CONTINUATION # NEXT TAPE N~ME COMMENTS :TAPE CO~ENTS ** REEL T~AILFR ** SERVICE NAME :SERVIC DATE :82/08/26 O~IGIN ~ REEL NAME {REEL ID CONTINUATION ~ N~XT REEL NAME COMMENTS :REEL COMMENTS 0,0!.42 NRAT '999,2500 GR 6,9375 ILD (). ! 245 NRA r -999,2500 Ga 6.5547 IL9 47,6074 RHOB 0.1226 NRAT -999.2500 3,5176 ILD 49,3164 R'HO~.~ NRAT 0,0532 C -999,2500 ~R 9 g, 250 (:) 51,074'2 -0. ~ 389 -999.25o0 3,8926 -999,2500 8,2187 2,1777 , 6211 -99..~500 1953 250e 3,b523 0645 4,582] -999,2500 -999.2500 1,7676 4,6~11 -999,2500 I~VP O10,H01 V'ERIFICATIOb~ LISTING i:~A(,;~ 13
