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175-075
RECEIVED ` STATE OF ALASKA . t. ALASKA OIL AND GAS CONSERVATION COMMISSION MAR 0 4 2015 WELL COMPLETION OR RECOMPLETION REPORT AND LOG OGCC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Other• ®Abandoned 0 Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory ❑Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No. of Completions Zero • • ® Development 0 Service 2. Operator Name: 5. Date Comp.,Susp.,o band.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 2/6/2015 175-075 • 314-596 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 2/21/1976 50-029-20187-00-00 ' 4a. Location of Well(Governmental Section): 7. Date T.D.Reached: 14. Well Name and Number: Surface: 3/14/1976 PBU 03-01 • 2017' FSL,664' FWL, Sec. 11,T1ON, R15E, UM • 8. KB(ft above MSL): 61' _ 15. Field/Pool(s) Top of Productive Horizon: 4012' FSL, 1439' FEL, Sec. 10,T1ON, R15E, UM GL(ft above MSL): 28' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9. Plug Back Depth(MD+TVD) Oil Pool 4172' FSL, 1528' FEL, Sec. 10,T1ON, R15E, UM 9318' 8569' • 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 713904. y- 5938075 • Zone- ASP4 • 10030' 9250' . ADL 028327&028328 • TPI: x- 711743 y- 5940010 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 711649 y- 5940168 Zone- ASP4 None 18. Directional Survey: ❑Yes ® No 19.Water depth, if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re-Drill/Lateral Top Window MD/TVD: DIL, GR/Sonic, FDC/CNL, CBL/VDL, CCL, Gyro, Vertilog N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 94# H-40 31' 111' 31' 111' 32" 300 sx Permafrost II 13-3/8" 72# MN-80 30' 2721' 30' 2721' 17-1/2" 5400 sx Permafrost II,Top Job w/320 sx Permafrost 9-5/8" 47# RS-95/MN-80 28' 9987' 28' 9209' 12-1/4" 1000 sx Class'G',105 sx PF II,702 sx Class'G',119 sx SqueezeCrete 7"x 4-1/2" 26#/12.6# L-80 1996' 8953' 1996' 8224' Scab Liner 939 sx Class'G' 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) of Top&Bottom; Perforation Size and Number): 5-1/2",17#x 4-1/2", 12.6#,13Cr80; 8911'; 8823'/8102'; AZIa^' 4-1/2", 12.6#, 13Cr80 8944'-9150' 8972'/8242' (wi 26. ACID, FRACTURE,CEMENT SQUEEZE, ETC. ir WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ® No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 7-7:-..41...:.: SCANNED MAY 1 2 2015 - •'`. See Attached 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 No • Sidewall Core(s)Acquired? ❑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 N REVfE,RSE Submit Original Only "u VT L 5747/,%. * Ate0 57-7/) A -w- %5-- RBDMSJk- APR - 7 2015 t " 29. GEOLOGIC MARKERS(List all formations z iarkers encounter 30. FORMATION TESTS NAME AD ND Well Tested? 0 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. Sadlerochit 9403' 8650' None Base of Sadlerochit 9911' 9136' 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: Trevor Hyatt,564-4627 Email: Trevor.Hyatt@bp.com Printed Name: Joe Lastu Title: Drilling Technologist Signature: Phone 564-4091 Date: 3/41 I5 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 ND 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: 03-01 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9393' Set 2-5/8" Posiset Plug 9383 10' Cement 9087' 25 Bbls Class 'G' 9087' - 9366' Mill Pilot Hole 9335' Set Whipstock 9318' Set 2nd Whipstock 03-01 , Well History (Pre-Rig Sidetrack) Date Summary 12/02/14 PULLED EMPTY 4-1/2"SS CATCHER FROM 6753'SLM. DRIFT W/20'x 2.70" DUMMY WHIPSTOCK TO 9532'SLM. 12/02/14 Bumped up psi to a test psi of 2500 1st 15 min IA loss 2 psi/2nd 15min IA loss 3 psi. MITxIA *INCONCLUSIVE*Bleed off psi FLUID PACKED ANNULUS FLUID PACKED SIGN hung on master valve caution tags hung on IA valve . Notified Sline to hang new psi gauge on IA. Sline in control of well upon LRS departure CV's=OTG FWHP's= 1460/484/-7. 12/20/14 INITIAL T/I/O= 1550/0/0 PSI. LRS PERFORMED L&K ON TBG W/293 BBLS 1%SLICK KCL&65 BBLS FRZ PROTECT. RIH WITH CROSSFLOW TOOLSTRING. LOGGED INTERVAL OVER PLUG SETTING DEPTH. NO CROSSFLOW DETECTED. RIH WITH POSISET PLUG ONCE IN 9-5/8" . BEGIN PUMPING A DIESEL TOTE FOR MORE FREEZE PROTECT DOWN TBG. 12/20/14 KCL down TBG to load and kill for E-Line. Pumped 12 bbls of Meth followed by 53 bbls of DSL down TBG to FP. FWHP=0/0/3 SV,MV,SSV=E-Line WV=C IA,OA=OTG Tag hung on WV E-Line on well upon departure DSO notified upon departure. 12/21/14 SET 2 5/8"POSISET PLUG IN 9-5/8"LINER @ 9395'MID ELEMENT(TOP @ 9393'). MADE 7 RUNS W/DUMP BAILERS LOADED W/CEMENT- 10'DUMPED ON TOP OF POSISET PLUG(EST TOC= 93831 CURRENTLY PULLING OUT OF THE HOLE TO RIG DOWN. 12/22/14 FINISHED PULLING OUT OF THE HOLE W/FINAL DUMP BAILER. ESTIMATED TOC @ 9382'. WELL LEFT SHUT IN ON DEPARTURE-NOTIFIED DSO OF WELL STATUS. FINAL T/I/O=0/0/0 PSI. 12/23/14 T/I/O=0/40/0. MITT FAILED to 1000 psi (Post E-line cement job)tbg lost 277 247 psi in first 15 min on 2 test attempts bleed well down to 0 rig down(swab closed wing closed ssv closed master open annulus valves open to gauges) FWHP=0/0/0. 01/03/15 Coil 3, 1.75", Scope: Set 17 ppg Cement Plug in Liner. MI Loc. 01/04/15 Coil 3, 1.75", Scope: Set 17 ppg Cement Plug in Liner. RU CTU 3. Barrier test. -Change Pack offs- Chain Inspec-M/U CTC, 2 stingers and 2.5" BDN. PJSM. PT lube. RIH. R/U cementers.Tag cement plug at 9378' up depth. Flag coil at 9373'. Pick up and flag coil at 9030'at cement cleanout depth. PT cement line with 4500 psi. PJSM Batch mix 16.5 PPG cement. Stage 5 bbl fresh water. Stage 25 bbl, 16.8 ppg G cement. Stage fresh water. Lost returns with 2 bbl cement out nozzle. partial returns after 2 more bbls pumped. 50% returns at start. Pull at 6 fpm, Full returns at end of cement. 18 BBLs returned to 40 bbl gauge tank. Casing capacity= 17.2 bbl up to tubing tailpipe at 9150'.Top of cement calculated at 9100'. Cleanout to 9030'as per program. POH. Freeze protect tubing. 01/05/15 Coil 3, 1.75", Scope: Set 17 ppg Cement Plug in Liner. Finish FP Well to 2500'-BD BHA(ball recovered)-WOC. M/U CTC, pull test. M/U MHA, PT. PJSM. M/U PDS logging tools.Thaw swab valve. RIH with logging tools for depth tag.Tag firm cement at 9092'CTMD. clean pick up,tag 3 times. Log up at 40 fpm to 8700'. POH at 80 fpm. Frz protect tubing with 60/40 meth. POOH download PDS data corrected TOC 9088' ELMD. 01/13/15 DRIFT w/20'x 2.70" DUMMY WHIPSTOCK,TAG TOC @ 9,065'SLM (sample of cement recovered). 01/15/15 T/I/O=0/0/0 Temp=S/I MIT-T(Pre CTD)Spot equip./open permit/rig up and start PT. Page 1 of 2 03-01 , Well History (Pre-Rig Sidetrack) Date Summary 01/16/15 MIT-T**PASSED**to 3000 psi. (Pre CTD) Pumped 2.5 bbls diesel down TBG to achieve test pressure. 1st 15 min.TBG lost 130 psi. 2nd 15 min.TBG lost 62 psi.Total loss in 30 min. = 192 psi. Bled back— 2.1 bbls Hung MIT info tags on WV and MV. RDMO SV,WV, SSV=closed, MV=open, IA and OA= OTG. FWHP's=250/0/0. 01/28/15 T/I/0=15/0/0. Pre CTD, Installed CTD TS-04 and PT to 5000 psi. Final WHP's 10/0/0. Page 2 of 2 North America-ALASKA-BP Page 1 o4.4- Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292018700 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/1/2015 03:30 - 06:00 2.50 MOB P PRE MOVE RIG -MOVE RIG OFF OF WELL 03-31A AND TRAVEL TO WELL 03-01A -SPOT AND SET RIG DOWN ON 03-01A. -ACCEPT RIG AT 06:00 ON 2/1/2015 06:00 - 08:00 2.00 MOB P PRE RU IN CELLAR. CYCLE TREE VALVES. PREP TO LEAK TIGHT TEST TREE VALVES. 08:00 - 09:00 1.00 MOB P PRE LEAK TIGHT TEST TREE VALVES. NIPPLE DOWN TREE CAP. 09:00 - 12:30 3.50 MOB P PRE NIPPLE UP BOPE. -SIMOPS:WELD STAND IN REEL HOUSE FOR REEL IRON. 12:30 - 15:00 2.50 MOB P PRE CONTINUE TO RU ANCILLARY EQUIPMENT. RU REEL IRON. -FILL STACK -OFFLOAD BHI 3"COIL TRACK TOOLS FROM PIPE SHED. -LOAD BHI 2-3/8"COIL TRACK TOOLS. 15'00 - 15:30 0.50 BOPSUR P PRE HELD RIG EVAC DRILL WITH AAR. 15:30 - 22:30 7.00 BOPSUR P PRE STATE GIVEN NOTIFICATION OF BOPE TEST 1/31/2015 07:28 STATE INSPECTOR BOB NOBLE WAIVED WITNESS 1/31/2015 08:21 PRESSURE TEST ALL BOP EQUIPMENT AS PER AOGCC REGS,PTD#214181,AND CRT-AK-10-45 -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST BOPE TO 250/3500 PSI FOR 5/5 CHARTED MIN -TEST CHOKE VALVES,CHOKE AND KILL HCR VALVES,INSIDE MANUAL VALVES ON CHOKE AND KILL LINES,BOP RAMS AND ANNULAR PREVENTER -ALL 2"PIPE RAMS TESTED WITH 2"TEST JOINT -2-3/8"PIPE RAMS TESTED WITH 2-3/8"TEST JOINT -BLIND RAMS TESTED ON OPEN HOLE -ANNULAR TESTED WITH BOTH 2-3/8"AND 2" TEST JOINT -TEST FULL OPENING SAFETY VALVE -FUNCTION BOPE FROM BOTH REMOTE PANELS -TEST GAS ALARMS -TEST INNER REEL/PACK-OFF TO 250/3500 FOR 5/5 CHARTED MIN -PERFORM DRAW DOWN TEST OF ACCUMULATOR -ALL TESTS WITNESSED BY WSL OR TOUR PUSHER HELD PRE SPUD MEETING WITH NIGHT CREW AT CREW CHANGE Printed 2/10/2015 9:09:02AM North America-ALASKA-BP Page 206A/ Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292018700 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 22:30 - 23:00 0.50 RIGU P PRE RIG EVACUATION DRILL -SOUND THE RIG EVACUATION ALARM ADVISED THE PAD OPERATOR. ALL HANDS PARTICIPATED AND REPORTED TO THE MUSTER AREA -HEAD COUNT CONFIRMED. AAR WITH CREW. 23:00 - 00:00 1.00 RIGU P PRE ASSEMBLE INJECTOR -INSTALL GOOSE AND ROLLERS ON TO TOP OF INJECTOR. INSTALL PACK-OFF ON RISER. -PICK UP INJECTOR AND CONNECT TO PACK -OFF 2/2/2015 00:00 - 03:15 3.25 RIGU P PRE PULL COIL OVER -CONNECT GRAPPLE TO 2"COIL.PULL TEST !-REMOVE SHIPPING BAR FROM COIL -PULL COIL OVER FROM REEL HOUSE TO INJECTOR. -TEST E LINE 2000 MEG OHMS -INSULATE(BOOT)E LINE END •03:15 - 04:30 1.25 BOPSUR ' P PRE 1COIL MANAGEMENT -FILL COIL WITH 10 BBL METHANOL FOLLOWED BY 40 BBL FRESH WATER. -PUMP METHANOL OUT OF SYSTEM. -TEST INNER REEL VALVES,PACK-OFF AND BULKHEAD TO 300-3500 PSI. 04:30 - 07:00 2.50 • RIGU I P PRE SLACK MANAGEMENT. PUMP SLACK BACK. REVERSE CIRCULATE -BLOW COIL DOWN TO CLEAR COIL EXPOSED TO ELEMENTS. -RIG UP COIL HYDRAULIC CUTTER. CUT 245'OF COIL 07:00 - 08:15 1.25 RIGU P PRE PJSM AND INSTALL CTC -INSTALL NIGHT CAP -DRESS COIL END,INSTALL SLB CTC -PULL TEST TO 35K# -PRESS TEST TO 250/3500 PSI 08:15 - 10:30 2.25 RIGU P PRE •PJSM AND HEAD UP BHI PU INJECTOR.MU STINGER AND NOZZLE. PUMP SLACK FORWARD OVER BUNGHOLE. -TEST E-LINE CONNECTIVITY,GOOD. -INSTALL BHI UQC WITH FLOATS. -RE-TEST E-LINE CONNECTIVITY,GOOD. -PRESS TEST UQC TO 250/3500 PSI,GOOD. -TEST UQC FLOATS TO 250/3500 PSI,GOOD. 10:30 - 11:15 0.75 STWHIP P PROD1 PJSM,OPEN WELL TO CLOSED CHOKE AND CHECK FOR PRESSURE. -WELLHEAD PRESSURE READING-18 PSI. -OPEN CHOKE LINE AND FLOWCHECK. I-NO FLOW. 11:15 - 12'15 1.00 STWHIP P PROD1 PJSM.PU PILOT MILL BHA. -PU 2.80 PARABOLIC MILL AND MU TO 2-3/8" X-TREME MOTOR W/0.9°AKO -MU 2-3/8"COILTRACK TOOLS TO MOTOR AND RIH. 11-STAB COIL,GET ON WELL,TEST QTS 250/3500 PSI 12:15 - 15:00 2.75 STWHIP P PROD1 RIH W/PILOT BHA F/60'TO 9087'MD -100 FPM,1.54/1.91 BPM IN/OUT -LOG TIE-IN W/-4'CORRECTION Printed 2/10/2015 9:09:02AM North America-ALASKA-BP Page 3441.4/ Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292018700 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 19:00 4.00 STWHIP P • PROD1 MILL PILOT HOLE F/9,087'TO 9180'MD. -BPM IN/OUT:1.52/1.52 BPM -DHWOB:0.31-1.51 KLBS -CIRC PRESSURE:2700 PSI -FREE SPIN:2525 PSI -MW IN/OUT:8.71/8.63 PPG -ECD:9.18 PPG -IA/OA/PVT:2 PSI/0 PSI/347 BBL MILLED F/9087'TO 9132'MD AT 80 FPH TO 95 FPH. AT 9132'ROP SLOWED TO BETWEEN 10 FPH AND 60 FPH. 19:00 - 00:00 5.00 STWHIP P PROD1 MILL PILOT HOLE F/9180'TO 9295'MD. -BPM IN/OUT:1.53/1.53 BPM -DHWOB:0.31-1.41 KLBS -CIRC PRESSURE:2673 PSI -FREE SPIN:2525 PSI -MW IN/OUT:8.72/8.64 PPG -ECD:9.23 PPG -IA/OA/PVT:4 PSI/0 PSI/350 BBL MILLING IN FIRM CEMENT 2/3/2015 00:00 - 02:00 2.00 STWHIP P PROD1 MILL PILOT HOLE F/9295'TO 9345'MD. -BPM IN/OUT:1.51/1.51 BPM -DHWOB:0.31-1.88 KLBS -CIRC PRESSURE:2747 PSI -FREE SPIN:2525 PSI -MW IN/OUT:8.72/8.63 PPG -ECD:9.26 PPG -IA/OA/PVT:4 PSI/0 PSI/351 BBL 02:00 - 02:15 0.25 STWHIP P PROD1 FLOW CHECK WELL. -NOTED A VERY GRADUAL INCREASE IN PVT (4 BBL)OVER THE PAST SEVERAL HOURS. THE INCREASE WAS NOT STEADY OR A CONSISTENT RATE.SURFACE LINES AND HOSES WERE CHECKED FOR LEAKS.A FLOW CHECK REVEALED NO FLOW.THE CONCLUSION WAS THAT THE PVT INCREASE WAS CAUSED WHEN THE SHAKERS WERE WASHED WITH THE WATER HOSE. 02:15 - 03:15 1.00 STWHIP P PROD1 MILL PILOT HOLE F/9345'TO 9365'MD. -BPM IN/OUT:1.51/1.51 BPM -DHWOB:0.31-1.73 KLBS -CIRC PRESSURE:2659 PSI -FREE SPIN:2525 PSI -MW IN/OUT:8.72/8.64 PPG -ECD:9.26 PPG -IA/OA/PVT:4 PSI/0 PSI/351 BBL 03:15 - 09:30 6.25 STWHIP P PROD1 REAM PILOT HOLE -REAM UP AND DOWN INSIDE THE 4-1/2" TUBING TAIL REAM THE 9-5/8"CASING CONTACT POINT. -BACK REAM THE 9-5/8"CASING WITH TOOL AT 45°LEFT AND RIGHT OF TOOL FACE HIGH SIDE. -LOG TIE-IN W/+4'CORRECTION. -RIH AND TAG TD AT 9366'MD. 09:30 - 11:45 2.25 STWHIP P PROD1 POH W/PILOT BHA TO 60'. 100 FPM,1.68/1.27 BPM IN/OUT Printed 2/10/2015 9:09:02AM North America-ALASKA-BP Page 4 Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 ; End Date: X3-0166W-C (3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292018700 Active datum:Kelly Bushing/Rotary Table t61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:45 - 12:30 0.75 STWHIP P PROD1 PJSM UD PILOT BHA. -POP OFF INJECTOR,UNSTAB COIL -BLOW DOWN BHA. -L/D PILOT BHA. -GAUGE MILL AT 2.80"GO,2.79"NO-GO 12:30 - 14:00 1.50 STWHIP P PROD1 PJSM M/U CALIPER/DRIFT BHA TO 70'. -LOAD DRIFT AND CALIPER TOOLS IN PIPE SHED. -MU DRIFT AND HANG WITH TUGGER. -MU CALIPER TOOLS TO BOTTOM OF DRIFT. -FUNCTION TEST CALIPER TOOLS-GOOD. -RIH W/DRIFT AND CALIPER TOOLS. i-MU COILTRACK TO TOP OF DRIFT AND RIH. -PU INJECTOR,STAB COIL,GET ON WELL AND TEST QTS. 14:00 - 18:30 2.50 STWHIP P PROD1 PJSM AND RIH W/BHA ON COIL F/70'TO 9,355'MD. -100 FPM,0.55/0.89 BPM IN/OUT -LOG TIE-IN W/+5'CORRECTION 16:30 - 17:00 0.50 STWHIP P PROD1 WAIT FOR CALIPER TO OPEN. CALIPER TO OPEN.. 17:00 - 17:20 0.33 STWHIP P PROD1 LOG CEMENT PILOT HOLE AND 4-1/2"TUBING UP F/9,355'TO 8,300'MD 50 FPM,1.00/0.79 BPM IN/OUT 17:20 - 18:50 1.50 ' STWHIP. P PROD1 POH W/BHA F/8,300'TO 70'MD. -100 FPM,1.01/0.60 BPM IN/OUT 18:50 - 19:30 0.67 STWHIP P PROD1 TAG UP AT SURFACE.C/O WITH DAY CREW& PJSM WITH NITE CREW FOR HANDLING BHA._ 19:30 - 20:20 0.83 STWHIP P PROD1 POP OFF WELL.STAND BACK INJECTOR.LD LOGGING TOOLS.BLOW DOWN BHI TOOLS. 20:20 - 20:45 0.42 STWHIP 'P PROD1 MU WS SETTING BHA.SCRIBE HOT TO SETTING TOOLS. 20:45 - 21:10 0.42 STWHIP P PROD1 STAB ONTO WELL.TEST QTS 250PSI/4000PSI -PASS.POWER UP&TEST TOOLS.OPEN EDC. 21:10 - 23:00 1.83 STWHIP P PROD1 RIH WITH WS SETTING BHA.PUMP 0.35BPM/800PSI. 23:00 - 23:45 0.75 STWHIP P PROD1 LOG DOWN FOR TIE-IN FROM 8800',MINUS • 4FT CORRECTION. 23:45 - 23:50 0.08 STWHIP P PROD1 WT CHECK AT 9050'(TOC),PUW=32K,SOW= 19K. 23:50 - 00:00 0.17 STWHIP P PROD1 LOG CCL DOWN ACROSS WS SET DEPTH. 2/4/2015 00:00 - 00:40 0.67 STWHIP P PROD1 CONTINUE TO LOG DOWN FOR CCL ACROSS SET DEPTH.COLLARS AT 9313'&9353'. CONSULT WITH ODE OVER SET DEPTH. _ 00:40 - 00:50 0.17 STWHIP P PROD1 CLOSE EDC.PRESSURE UP&SET WS, 3250PSI.GOOD SET.3-1/2"MB WS SET W/ TOP AT 9335',15DEG ROHS. 00:50 - 01:00 0.17 STWHIP P PROD1 FLOW CHECK AT TOC-NO FLOW. 01:00 - 02:30 1.50 STWHIP P PROD1 POH.CIRC 1.3BPM/1900PSI.PJSM REGARDING LD WS SETTING BHA. 02:30 - 02:40 0.17 STWHIP P PROD1 FLOW CHECK-NO FLOW. 02:40 - 03:15 0.58 STWHIP P PROD1 POP OFF WELL.LD WS SETTING BHA. 03:15 - 03:20 0.08 STWHIP N PROD1 PJSM REGARDING MU MILLING BHA. 03:20 - 04:00 0.67 STWHIP N PROD1 MU MILLING BHA.MU INJECTOR TO BHA. STAB ONTO WELL. Printed 2/10/2015 9:09:02AM North America-ALASKA-BP Page 5 Operation Summary Report Common Well Name 03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292018700 Active datum:Kelly Bushing/RotaryTable (261.Oousft(above Mean Sea Level) Date • From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:00 - 04:15 0.25 STWHIP N PROD1 PRESSURE TEST QTS.250PSI/4000PSI- PASS.POWER UP&TEST TOOLS.OPEN EDC. 04:15 - 07:15 3.00 STWHIP N PROD1 RIH WITH MILLING BHA.CIRC 0.5BPM/825PSI. -LOG TIE-IN WI-4'CORRECTION -TAG TOWS AT 9335'MD -DRY TAG TOWS AT 9335.5'MD. -BRING PUMP UP TO 1.62 BPM,THEN SHUT DOWN AND MEASURE GAIN IN PIT VOLUME OF 2 BBL TO FINGERPRINT SYSTEM,PRIOR TO MILLING WINDOW INTO SHUBLIK. -SPR'S P#1,1.5BPM@2435PSI, • 1BPM@1674PS1,0.5BPM©1007PSI P#2,1.5BPM@2380PS1, 1BPM01626PS1,0.5BPM@1025PS1 07:15 - 15:00 7.75 STWHIP N PROD1 TIME MILL WINDOW AT 1.0 FT/HR FROM 9335' !TO 9342'MD. WINDOW EXIT AT 9339.7'MD. CONTINUE TO TIME MILL UNTIL STRING REAMER LEAVES CASING. -CIRC PRESSURE:2965 PSI -BPM IN/OUT:1.72/1.72 PVT:345 BBLS -MW IN/OUT:8.72/8.63 PPG -ECD/IA/OA:9.30 PPG/0 PSI/0 PSI STALLED MOTOR 1 TIME. 15:00 - 16:00 1.00 STWHIP N PROD1 MILL RATHOLE FROM 9342'TO 9350'MD. -CIRC PRESSURE:2805 PSI -BPM IN/OUT:1.67/1.65 PVT:345 BBLS -MW IN/OUT:8.72/8.63 PPG -ECD/IA/OA:9.28 PPG/0PSI/OPSI 16:00 - 18:00 2.00 STWHIP N PROD1 MAKE THREE REAMING PASSES THROUGH WINDOW,THEN DRY DRIFT. WINDOW SMOOTH. PU TO 9165',THEN MAKE THREE REAMING PASSES FROM 9165'TO 9155'AT 180°TF,135° TF,AND 225°TF. TURN MOTOR BACK TO 15°ROHS AND RIH F/ _ 9155'TO BOTTOM AT 9350'MD. 18:00 - 19:35 1.58 STWHIP N PROD1 POH F/9150'TO 60'.PJSM REGARDING SWAP OUT BHA WHILE POH. 19:35 - 20:15 ' 0.67 STWHIP N PROD1 FLOW CHECK-NO FLOW.POP OFF WELL& • PLACE INJECTOR OVER BUNG HOLE.BREAK OFF MILL.LD MOTOR.MU 2.64 AKO MOTOR& SAME BHI COIL TRAC TOOLS&RERUN BIT. PU&MU INJECTOR ONTO BHA. 20:15 - 20:30 0.25 DRILL N PROD1 PRESSURE TEST QTS 250PSI/4000PSI-PASS. POWER UP&TEST TOOLS.OPEN EDC. 20:30 - 22:10 1.67 DRILL N PROD1 RIH WITH DRILLING BHA.CIRC THRU EDC, 1 BPM/1800PSI. 22:10 - 22:45 0.58 DRILL N PROD1 LOG DOWN FOR TIE-IN FROM 8800',MINUS 4' CORRECTION. 22:45 - 23:00 0.25 DRILL N PROD1 CONTINUE TO RIH. Printed 2/10/2015 9:09:02AM • North America-ALASKA-BP Page 6,04 Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292018700 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 DRILL N PROD1 ATTEMPT TO DRILL 3.25"BUILD SECTION FROM 9350' -NBI 16.27° -ROP 0-3'/HR,NUMEROUS STALLS W/5-10K OP,ISSUES GETTING TO BOTTOM. -BPM IN/OUT:1.70/1.70 -CIRC PSI:2700 FREE SPIN (50-75PSI MW) ECD:9.34 PPG(OBD) -MW IN/OUT:8.7 PPG/8.62 PPG -IA/OA/PVT:0 PSI/0 PSI/348 BBLS -DHWOB:0.70K LBS-3.6K LBS -86°FIN/91°F OUT DRILL TO MIDNITE DEPTH OF 9353'. 2/5/2015 00:00 - 02:15 2.25 DRILL N PROD1 WITH GREAT DIFFICULTIES,REAM& BACKREAM AREA FROM 9340'TO 9353'& CONTINUE TO DRILL 3.25"BUILD SECTION FROM 9353' NBI 16.57° '-ROP 3'/HR.CONTROL DRILL USING 3'/HR. -BPM IN/OUT:1.70/1.70 CIRC PSI:2700 FREE SPIN (50-75PSI MW) -ECD:9.34 PPG(OBD) -MW IN/OUT:8.7 PPG/8.62 PPG IA/OA/PVT:0 PSI/0 PSI/348 BBLS DHWOB:0.70K LBS-1.0K LBS -86°FIN/91°F OUT -9354'SAMPLE WAS 90%CEMENT,REST METAL. -DRILL TO 9358'. 02:15 - 04:30 2.25 DRILL N PROD1 CONTINUE TO DRILL 3.25"BUILD SECTION FROM 9358' -NBI 17.4°AT 9343',HOLDS 16-17°&NOT BUILDING. -ROP 3'/HR.CONTROL DRILL USING 8'/HR. -BPM IN/OUT:1.70/1.70 -CIRC PSI:2700 FREE SPIN (50-75PSI MVV) -ECD:9.34 PPG(OBD) -MW IN/OUT:8.7 PPG/8.62 PPG -IA/OA/PVT:0 PSI/0 PSI/348 BBLS -DHWOB:0.70K LBS-1.1K LBS -86°FIN/91°F OUT -STALL AT 9359',10K OP. -9355'&9365'SAMPLE WAS 100%CEMENT. -NBI SHOWS SAME INC AS PREVIOUS WELLBORE. DRILL TO 9372'(STILL INSIDE 9-5/8"CASING BASED OF CEMENT SAMPLES&NO CHANGE IN INC). 04:30 06:45 2.25 DRILL N PROD1 OPEN EDC&FLOW CHECK-NO FLOW. POH.CIRC THRU EDC AT 1.84BPM/2475PS1. 06:45 - 07:15 0.50 DRILL N PROD1 PJSM L/D BUILD BHA. -POP OFF AND STAND INJECTOR BACK. -L/D BUILD BHA. Printed 2/10/2015 9:09:02AM North America-ALASKA-BP Page 7 par Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292018700 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:15 - 10:45 3.50 DRILL N PROD1 PJSM CUT 100'OF COIL FOR CHROME MANAGEMENT. -CUT OFF CTC AND UQC -RU CUTTER,AND CUT 100'OF COIL -R/D CUTTER -MU CTC AND PULL TEST -MU UQC PULL TEST. -PRESSURE TEST CTC AND UQC 300/4000 PSI -PT CHECKS. 10:45 - 11:30 0.75 STWHIP N WEXIT PJSM,MU WHIPSTOCK BHA. -MU NEW WHIPSTOCK WITH COILTRACK -STAB COIL -GET ON WELL,TEST QTS 250/3800 PSI 11:30 - 14:15 2.75 STWHIP N WEXIT RIH W/WHIPSTOCK BHA. -100 FPM,0.35/0.71 BPM IN/OUT LOG TIE-IN W/-4'CORRECTION -STACK OUT IN CEMENT PILOT HOLE AT 9122'MD. MAKE MULTIPLE ATTEMPTS TO GET THROUGH,ROTATE TOOLFACE MULTIPLE ORIENTATIONS WITH NO SUCCESS. 14:15 - 17:00 2.75 STWHIP N WEXIT POI-IW/WHIPSTOCK BHA F/9122'. 60 FPM,1.10/0.85 BPM IN/OUT 17:00 - 17:30 0.50 I STWHIP N WEXIT PJSM,LD WHIPSTOCK BHA. -STAND BACK COILTRACK TOOLS. -LD WHIPSTOCK. -WHIPSTOCK TRAY AND BOTTOM NOSE PIECE PACKED WITH STEEL SHAVINGS. 17:30 - 18:00 0.50 STWHIP N WEXIT PJSM,MU CLEANOUT BHA PER OCN#6 STAB COIL,GET ON WELL,TEST QTS 250/3800 PSI. 18:00 - 19:40 1.67 STWHIP N WEXIT 'RIH W/CLEANOUT BHA.CIRC AT 0.6BPM/900PSI. 19:40 - 20:10 0.50 STWHIP N WEXIT LOG DOWN FOR TIE-IN FROM 8800',MINUS 3.5'CORRECTION.CIRC 0.65BPM/956PSI. 20:10 - 21:30 1.33 STWHIP N WEXIT RIH AT 5'/MIN W/15ROHS,SET DOWN NO PUMPS AT 9127'.RIH AT 10'/MIN&PUMP 1.61BPM/2000PSI.PUMP 4OBBL HI-VIS PILL. NO FURTHER ISSUES RIH TO 9335'.MAKE 1 UP/DOWN PASS AT 20'/MIN FROM 9000'TO 9335'WHILE PUMPING AT 1.65BPM/3150PSI. DRY DRIFT FROM 9100'TO 9200'-NO ISSUES. CIRC AT 1.6BPM/2560PSI&RIH TO 9335'. OPEN EDC. 21:30 - 23:30 2.00 STWHIP N WEXIT POH.CIRC THRU EDC AT 2.56BPM/3900PSI. BOTTOMS UP RECOVERED THUMB NAIL SIZED PIECES OF ROUND CEMENT PIECES& THUMB NAIL SIZED PIECES OF FLAT METAL FLAKES&-4"OF A GREEN 7"0-RING FOLLOWED BY LOTS OF FINE CEMENT.PJSM REGARDING HANDLING BHA WHILE POH. 23:30 - 23:35 0.08 STWHIP N WEXIT FLOW CHECK-NO FLOW. 23:35 - 23:50 0.25 STWHIP N WEXIT POP OFF WELL.STAND BACK INJECTOR.LD BHA.NO ISSUES WITH MILL. 23:50 - 00:00 0.17 STWHIP N WEXIT STAB ONTO WELL.CLOSE SWAB.PRESSURE TEST 7"0-RING EQUIPMENT-PASS.BLEED OFF. 2/6/2015 00:00 - 00:10 0.17 STWHIP N WEXIT CONTINUE TO TEST 7"O-RING EQUIPMENT- PASS. Printed 2/10/2015 9:09:02AM • , • North h America-ALASKA-BP Page n>2st Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Date/Time:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292018700 Active datum:Kelly Bushing/Rotary Table @61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:10 - 00:45 0.58 STWHIP P WEXIT MU WS SETTING BHA.PU INJECTOR.STAB ON TO WELL. 00:45 - 01:00 0.25 STWHIP P WEXIT POWER UP&TEST TOOLS.OPEN EDC.CIRC THRU EDC&PUMP 0.5BPM/800PSI.TEST QTS 250PIS/4000PSI-PASS. 01:00 - 03:15 2.25 STWHIP P WEXIT RIH,CIRC THRU EDC AT 0.45BPM/800PSI. 03:15 - 03:45 0.50 STWHIP P WEXIT LOG DOWN FOR TIE-IN FROM 8810',MINUS 4.5'CORRECTION. 03:45 - 04:15 0.50 STWHIP P WEXIT RIH.CIRC THRU EDC AT 0.45BPM/923PSI.SET DOWN AT 8951',NO OTHER ISSUES.19K RIW, 32K PUW.CLOSE EDC. 04:15 - 04:20 0.08 STWHIP P WEXIT PRESSURE UPTO 3280PSI.SET 3-1/2" MONOBORE WS WITH TOP AT 9318'AT 20 ROHS.SET 2K DOWN. 04:20 - 06:30 2.17 STWHIP P WEXIT POH.CIRC 1.5BPM/12300PSI. 06:30 - 07:30 1.00 STWHIP P WEXIT PJSM,LD WHIPSTOCK BHA,MU WINDOW MILLING BHA. GAUGE MILLS-WINDOW:2.75"GO,2.74" NO-GO;STRING:2.74"GO,2.73"NO-GO GET ON WELL,TEST QTS 250/3800 PSI 07:30 - 09:30 2.00 STWHIP P WEXIT RIH W/WINDOW MILLING BHA -80-100 FPM W/0.45 BPM 1-LOG TIE-IN W/-6'CORRECTION. 09:30 - 09:45 0.25 STWHIP P WEXIT I TAKE SPR'S AND BENCHMARK SYSTEM FLOWBACK VOLUME AT 1.67 BPM,WITH 2 _.BBL RETURNED. 09:45 - 10:00 0.25 STWHIP P WEXIT CONTINUE TO RIH AND TAG WHIPSTOCK AT 9318.15'PUMPS OFF,9317.75'PUMPS ON. 10:00 - 15:15 5.25 STWHIP P WEXIT MILL WINDOWAAS PER OCN#5 F/9317.75' 5,k-0A+ TO 9324.2'MD. -POTENTIAL WINDOW EXIT AT 9322.2'MD. CONTINUE TO TIME MILL UNTIL STRING V •-0 I ik REAMER LEAVES CASING AT 9224.2'MD. -DHWOB 3.5 KLBS -CIRC PRESSURE:2965 PSI FREE SPIN:2700 PSI -BPM IN/OUT:1.67/1.69 PVT:350 BBLS -MW IN/OUT:8.72/8.63 PPG -ECD/IA/OA:9.28 PPG/0 PSI/0 PSI -SHOWED SIMILAR CHARACTERISTICS TO PREVIOUS ATTEMPT. -EARLY SAMPLES SHOWED NO FORMATION, AND VERY LITTLE CEMENT,MOSTLY STEEL. 15:15 - 18 00 2.75 STWHIP P WEXIT MILL RATHOLE FROM 9324.2'TO 9338'MD. -CIRC PRESSURE:2905 PSI FREE SPIN:2700 PSI -DHWOB:1.0-4.1 KLBS -BPM IN/OUT:1.67 11.67 PVT:350 BBLS -MW IN/OUT:8.72/8.63 PPG -ECD/IA/OA:9.28 PPG/O PSI/O PSI -NEAR BIT INC BAGAN TO INCREASE ABOVE ORIGINAL HOLE AT 9328.8'MD BIT DEPTH, 9315'NBI DEPTH. APPEARS TO BE FOLLOWING WHIPSTOCK TRAY. -SAMPLE FROM 9330'SHOWS 5%OF FORMATION. MILL TO 9337',NBI SHOWS 3 DEG INCREASE IN INC. 18:00 - 19:30 1.50 STWHIP P WEXIT MAKE 3 UP/DOWN REAM PASSES AT 1'/MIN- CLEAN.DRY DRIFT WINDOW-CLEAN. Printed 2/10/2015 9:09:02AM r Page 9 p4' North America-ALASKA-BP Operation Summary Report Common Well Name:03-01 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/1/2015 End Date: X3-0166W-C:(3,861,841.00) Project:Prudhoe Bay Site:PB DS 03 Rig Name/No.:NORDIC 2 Spud Daterfime:3/22/1976 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292018700 Active datum:Kelly Bushing/Rotary Table©61.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase I Description of Operations (hr) (usft) 19:30 - 19:35 0.08 STWHIP P WEXIT FLOW CHECK PASS.OPEN EDC. 19:35 - 21:25 1.83 STWHIP P WEXIT POH CIRC THRU EDC AT 2.55BPM/3765PSI. PJSM REGARDING HANDLING BHA WHILE POH. 21:25 - 21:30 0.08 STWHIP P WEXIT TAG UP.FLOW CHECK-NO FLOW. 21:30 - 22:30 1.00 STWHIP P WEXIT POP OFF.STAND BACK INJECTOR&CIRC IN BUNG HOLE.PURGE&BLOW DOWN BHA.LD BHA IN SECTIONS FOR NEXT RUN.MILL& REAMER WERE 2.74"GO.MILK MOTOR- FINE.LD MOTOR. 22:30 - 22:35 0.08 STWHIP P WEXIT !PJSM REGARDING MU BUILD BHA. 22:35 - 23:20 0.75 STWHIP P WEXIT MU BUILD BHA IN SECTIONS W/RE-RUN 3" HYC BI-CENTER BIT&ULS MM.PU INJECTOR &MU TO BHA.STAB ONTO WELL. 23:20 - 23:40 0.33 STWHIP P WEXIT POWER UP&TEST TOOLS.OPEN EDC.CIRC THRU EDC 0.4BPM/730PSI.PRESSURE TEST QTS,250PS1/4000PSI-PASS. 23:40 - 00:00 0.33 STWHIP P WEXIT RIH WITH BUILD BHA.CIRC THRU EDC AT 0.67BPM/950PSI. 2/7/2015 00:00 - 01:15 1.25 DRILL P PROD1 CONTINUE TO RIH WITH BUILD BHA.CIRC THRU EDC AT 0.67BPM/950PSI. 01:15 - 01:45 0.50 DRILL P PROD1 LOG DOWN FOR TIE-IN FROM 8800'.MINUS 6.5'CORRECTION.CIRC THRU EDC AT 0.67BPM/950PSI. 01:45 - 02:00 0.25 DRILL P PROD1 RIH.CIRC THRU EDC AT 0.67BPM/950PS1- _CLEAN.STOP AT 9300'.CLOSE EDC. 02:00 - 06:00 4.00 DRILL P PROD1 DRILL 3"BUILD SECTION FROM 9337' -NBI 19.84° -ROP 0-10'/HR(INITAL) TO 20-30'/HR. -BPM IN/OUT:1.55/1.55 -CIRC PSI:2535 FREE SPIN (50-75PSI MW) -ECD:9.25 PPG(OBD) -MW IN/OUT:8.7 PPG/8.62 PPG -IA/OA/PVT:0 PSI/0 PSI/165 -DHWOB:0.70K LBS-3.6K LBS -86°FIN/64°F OUT PUMP 4OBBLS HI-VIS PILL FOLLOWED BY NEW MUD FROM 9343'. -DRILL TO 9383'MD 06 DO - 13.30 7.50 DRILL P PROD1 DRILL 3"FROM 9383'TO 9500'MD. -CIRC PRESSURE:3100 PSI FREE SPIN:2900 PSI -DHWOB:1.0-3.5 KLBS -BPM IN/OUT:1.75/1.74 PVT:355 BBLS -MW IN/OUT:8.67/8.61 PPG -ECD/IA/OA:9.36 PPG/0 PSI/0 PSI -AVERAGE DLS ON FIRST THREE CLEAN SURVEYS 41.5°. CALL AND DISCUSS WITH ODE. POH TO DIAL DOWN MOTOR. -AVERAGE DLS ON PREVIOUS RUNS WITH SAME BIT,MOTOR,AND AKO COMBINATION 34° 13'30 - 16:00 2.50 DRILL P PROD1 POH W/3"BUILD BHA F/9500'MD TO 60'MD. -80-100 FPM,1.31/0.99 BPM IN/OUT. 16.00 - 16:45 0.75 DRILL P PROD1 POP OFF WELL. BREAK AND LD 3"BUILD BHA. BIT GRADED 1-1. DIAL MOTOR DOWN TO 1.77°AKO. 16:45 - 17:00 0.25 DRILL P PROD1 FUNCTION TEST BOPE F/DRILLER'S REMOTE PANEL. Printed 2/10/2015 909•02AM ,TTS= 7"CII r WELLI- AD= FMCO —O 1 SAFETY NOTES: •"4-1/2"CHROME TBG"" 4 ACTUATOR= AXELSON OKB.ELEV= 61' BF.ELEV= 4 l J KOP= ? �� • 1941' —15-1/2"X 4-1/2'XO,121=3.958" Max Angle= 35"@ 6400' •i i Datum MD= 9622' 1996' 9-5/8"x 7"BKR C-2 ZXP LW�4 I 4‘.. w/FLEXLOO(LNR FiGR,ID=6.270" Datum TVD= 8800'SS 4% I 1 A 2078' 1 4-1/2"HES X NP,D=3.813"1 9-5/8"CSG,47#,L-80 TOI, ID=8.681" —I 2167' ..J i A ► ► 2167' —I9-5/8"FES ES CEMENTER [13-3/8"CSG,72#,MN 80,ID=12.347 1—{ 2720' ►4 GAS LFT MANDRELS 0ST MD TVD DEV TYPE VLV LATCH PORT DATE ►j 6 3401 3392 16 KGB2 DMY BK 0 12/01/14 05 4978 4815 30 KGB2 DMY BK 0 12/01/14 �j 7--- 4 5797 5508 34 KGB2 DMY BK 0 12/01/14 ► 3 6663 6224 34 KGB2 DMY BK 0 12/01/14 Minimum ID =3.725" 9128' ► 2 7488 6917 31 KGB2 DM' BK 0 03/27/07 ►4 1 8734 8020 23 KGB2 DMY BK 0 03/27/07 HES XN NIPPLE k I I { 8802' 1-14-1/2"HES X NP,D=3.813" ►4 ►4 4 �4�� 210 8823' —17"X 4-1/2"BKR S-3 PKR,D=3.875' ►4 ►4 ' , 8847• —14-1/2"FPS X NP,0=3.813" ►4 ►4 4-1/2"TBG, 12.6#,13CR 80, H 8911' ► 8911' H4-1/2"WLEG,D=3.958" V A M TOP,.0152 bpf,ID=3.958" j' / • -,--.- 8913' Hr X 4-1/2"PORTED XO,D=3.958" (7'LNR,26#,L-80,BTC-M,.0383 bpf, D=6.276" H 8913' C —8913' HRESTRICTION,D=3.88"(07/13/14) 4-1/2"TBG,12.6#,L-80, H 8942' 1 8944' H4-1/2"TBG STUB(03/22/07) — BT-M,.0152 bpf,D=3.958' I 8953' H9-5/8"X 4-112"UNIQUE OV ERSHOT 8970' H4-1/2"X 5-1/2"XO,D=3.92" 8972' —19-5/8"X 5-1/2"TfW HBBP-T PKR,D=4.875" TOC(01/04/15) —19088' ELMD '-----1 8977' —15-1/2"X 4-1/2"XO,ID=3.958" 4-1/2"TBG, 12.6#,13-CR-80, —1 9150' 9128' I—{4-1/2"FES XN NP,D=3.725' i. 9150' —14-1/2"WLEG,D=3.958" .NSCGNSCT, .0152 bpf,D=3.958" 3-1/2"MONOBORE'M-FSTOCK — 9318' 9152' —{ELMD TT LOG(XX/XX/XX)? w/CMT SLIPS(02/06/15) * * * * * * * * .. . • • 1, 3-1/2"MONOBORE W1f'STOCK(02/04/15) — 9335' II -9383' —10EMENT PLUG(12/21/14) PERFORATION SUMMARY 9393' —12-5/8"SLB POSISET PLUG(12/21/14) REF LOG: BRCS ON 03/13/76 1 . 9541' —1 TOP OF CEMENT(04/29/10) .w.*.w.♦.v.+ ANGLE AT TOP PERF: 17°@ 9404 ?.r.—_._..... 9566' H3-3/8"BP(04/29110) Note:Refer to Production DB for historical pert data ��FISH-4-1/2"LOCK KEY (7/20/05) l SIZE SPF INTERVAL Opn/Sgz DATE SEE PAGE 2 FOR PERFORATIONS ???? _-FISH-13.06'LONG IBP(06/01/02) I I I I 9620' —{CMT PLUG(SET 04/21/92) 9-5/8"CSG,47#,RS-95/MN-80,D=8.681" —I 9987' ► 11/111'4 4 ►11111111111/11111111.4 TD —I 10030' ►11111111111/11111111 DATE REV BY COMMENTS , DATE REV BY COMIVENTS PRUDHOE BAY INT 04/10/76 ORIGINAL COMPLETION 12/12/14 NXW/JWC GLV GO(12/01/14) WELL: 03-01 02/26/96 RWO 01/12/15 JCM'JMD SET POSISET/CMT PLUG(12/21/14) FERMT No:'1750750 03/30/07 N4E5 RWO 01/12/15 RW/JMD SET CMT(01/04/15) AR No: 50-029-20187-00 11/05/12 IIJS/JMD PI3RF CORRECTION(10/28/12) SEC 11,T1ON,R15E,2016'FSL&664'FWL 07/25/14 SWC/JMLtTBG RESTRICTION(07/13/14) 09/18/14 JMD SCHEMATIC CORRECTIONS BP Exploration(Alaska) 03-01 • • 1'I 1• 114 1 1 4e• .►4 40• 4 4 4 ►� 4 k ►� 4 4 4 4 4 4 4 4 0 0 4 4 4 4 4 4 ►4 1 I 0 4 4 4 O 4 I I 4 4 4 ! , • 11 PERFORATION SUMMARY IRIEF LOG: BI-CS ON 03/13/76 ANGLE AT TOP PERF: 17°@ 9404 Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz CATE 4 9404-9424 S 04/21/92 3-3/8" 4 9424-9494 C 03/27/94 1:X(. 4 9494-9501 S 04/21/92 3-3/8" 4 9522-9536 C 05/04/92 +~ r 4 9536-9561 S 04/21/92 3-3/8" 4 9571-9592 C 05/04/92 4 9592-9608 S 04/21/92 4 9622-9658 S 04/21/92 4 9671-9696 S 04/21/92 4 9728-9742 S 04/21/92 4 9788-9813 S 04/21/92 ,,•••••••_• 1 11N. 1 DATE REV BY COPvtU'1TS DATE REV BY COMMENTS PRIDHOEBAY UNIT 04/10/76 ORIGINAL COMPLETION 12/12/14 NXW/JME GLV C/O(12/01/14) WELL: 03-01 02/26/96 RWO 01/12/15 JCMJMD SET POSISET/CMT PLUG(12/21/14) PE MT No:'1750750 03/30/07 N4ES RWO 01/12/15 RW/JMD SET CMT(01/04/15) AR No: 50-029-20187-00 11/05/12 HDS/JMD PERF CORRECTION(10/28/12) SEC 11,T10N,R15E,2016'FSL&664'FWL 07/25/14 SWC/JMC TBG RESTRICTION(07/13/14) 09/18/14 JMD SCHEMATIC CORRECTIONS BP Exploration(Alaska) THE STATE of i GOVERNOR SEAN PARNELL John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-01 Sundry Number: 314-596 Dear Mr. McMullen: .ase 09_ and Guz 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner '1-, DATED this Z day of November, 2014. Encl. SCANNED NOV 18 2014 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION pSY\ APPLICATION FOR SUNDRY APPROVAL i1 (i.flw 20 AAC 25.280 11 tw 4 01 NOVO 6 2014 1. Type of Request: 11 ❑ Abandon ® Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc.175-075 ❑ Exploratory ❑Stratigraphic ® Development ❑ Service 3. Address: 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50.029-20187-00-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 03-01 Will planned perforations require a Spacing Exception? ❑ Yes 19 No 9. Property Designatior 10. Field / Pool(s): ADL 028328 & 028327 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) 1 10030' 9250' 9620' 8858' 9566'& 9620' Unknown (2) Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 31'- 111' 31'- 111' 1530 520 Surface 2691' 13-3/8" 30'- 2721' 30' - 2721' 5380 2670 Intermediate Production 9957' 9-5/8" 30'- 9987' 30'- 9209' 6870/8150 4760/5080 Liner Scab Liner 6957' 7" x 4-1/2" 1996'- 8953' 1996'- 8224' 7240/8430 5410/7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): T5-1/2", Tubing Size: Tubing Grade: Tubing MD (ft): 9424'- 9592' 8671'- 8831' n# X 4-1/2", 12 6#; 4-1/2", 12.6# 13Cr80 8911'; 8944' - 9150' Packers and SSSV Type: 7" x 4-1/2" Baker S-3 Packer Packers and SSSV 8823'/ 8102' 9-5/8" x 5-1/2" TIW HBBP-T Packer MD (ft) and TVD (ft): 8972'/ 8242' 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch El Exploratory ❑Stratigraphic ®Development E] Service ❑ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. November 15, 2014 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned 16. Verbal Approval: Date ❑ WAG ❑ SPLUG ® Suspended Commission Representative: 17. I hereby certify that the true a or , to the st of my knowledge. Contact: Trevor Hyatt, 564-4627 /Tforo's Printed Name: Johnu le itle: Engineering Team Leader Emai- l: Trevor.Hyatt@bp.com Signature: hone: 564-4711 Date: /L/ " Commission Use Only Condition of roval: Notify Commission so that a representative may witness - Is\ Sundry Number: 2j\ QQ ���� El Plug Integrity [9'BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance /�S7@ol,rZ j Other: 3 � 'O !' S r/ (�- s l C " " XA-c-. ® og Spacing Exception Required? ❑ Yes dNo Subsequent Form Required: APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date: Form 10-403 Rewsed 10/2012 ti s li for 12 months from the date of app oval Submit In Duplicate Rfl�Q - ii , , am &AQ Kine 1 Pr ,n1 �� To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt bp CTD Engineer Date: November 3, 2014 Re: 03-01 Sundry Approval Sundry approval is requested to plug the 03-01 perforations as part of the pre -rig prior to drilling and completing the proposed 03-01A coiled tubing sidetrack. History of 03-01: 03-01 was completed in 1976. In 2007 a RWO was completed to repair IA x OA. OA is fully cemented to surface. Reason for sidetrack: It is consistently very high watercut. There are no further wellwork options for this well. The best utility for this well is a sidetrack to new bottomhole location to as part of waterflood p ttern rotation pros !� �o'%cvr. Voll fro 06-,0 f /f0 /3� Proposed plan for 03-01 A: Drill a through tubing sidetrack with a Coiled Tubing Drilling rig on or around January 15th, 2015 with Nordic 2. The sidetrack, 03-01A, will exit the existing 9- 5/8" casing and kick off the Shublik. This sidetrack will be completed with a 2-3/8" 13Cr solid liner, cemented in place. This Sundry covers plugging the existing 03-01 perforations via the pre rig coil cement iob and 03-01A liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the proposed sidetrack is attached for reference. Pre -Rig Work scheduled to begin November 15th, 2014 1. S Dummy whipstock drift 2.* C Set cement plug in 9-5/8" casing and 4-1/2" tubing by pumping -30 bbls of 17.0 ppg cement. Clean out to 9,050' MD. 3. S Run a 2.70" drift and tag TOC. 4. F MIT -T to 3,000psi. 5. O Bleed wellhead, production, flow, and GL lines down to zero and blind flange. 6. O Remove wellhouse and level pad. Perform liner cleanout with mill, motor and RPM/GR/CCL log. * Approved alternate plug placement per 20 AAC 25.112(i) «� RigWork scheduled to begin January 15th, 2015 1. MIRU and test BOPE 250 psi low and 3,500 psi high. 2,500 psi MASP . 2. Drill 2.74" pilot hole from TOC to 9,365' MD 30' rat hole). 3. Cali erpilot hole using PDC logging conveyed on coil. 5. Set 3-1/2" mono -bore whipstock with cement slips at 9,335' MD. 6. Mill 2.74" window at 9,335' MD and 10' of rathole. 7. Drill build section: 3" OH, -555' (350 de /100 planned) with resistivity. 8. Drill lateral section: 3" OH, 1644' (120 de /100planned) with resistivity. 10. Run 2-3/8" 13Cr liner leaving TOL at 8,860' MD. 11. Pump primary cement leaving TOC at 8,860' MD, 11.2 bbls of 15.3 ppg liner cmt planned. r/ % � C-> � � 1 , 12. Perform liner cleanout with mill, motor and RPM/GR/CCL log. 13. Perforate liner based on log interpretation -20' of erfs 14. Freeze protect well to 2500' MD 15. Set TWC, RDMO Post -Rig Work: 1. Re -install wellhouse, flowline and pull TWC. 2. Set liner top packer with Slickline (if needed) & test to 2,500psi. 3. Set generic GLV's, SBHPS, ASRC flow back, SIT. Trevor Hyatt CTD Engineer 564-4627 CC: Well File Joe Lastufka TREE= . 7" CNV WELLHEAD= FMC ACTUATOR = AXELSON OKE. la" = 61 BF. ELEV = 6 KOP= ? WX Angie = 35" 6400' Datum MD 9627 OatumND=��� 8800'SS 9-518" CSG, 47#, L-80 TC8 10=8.681- H 216T 13-3/8" CSG, 72#, tNNN-80, D =12.347' H 272W Minimum ID = 3.726" @ 9128' HES XN NIPPLE 4-12' TBG, 12.6#, 13CR-80, H 8911' YAM TOP, .0152 bpf, D = 3.958" 7' LMR, 2611, L-80, BTC -M. .0383 bpf, D = 6.276' 8913' 4-12" TBG, 12.6#, L-80, 8942' BT -M, .0152 bpf, D = 3.958" 4-12" TBG, 12.6#,13 -CR -80, I—j 9150' .NSCGNSCT, .0152 bpf, D = 3.958" 1 PERFORATION SUMMARY REF LOG: BHCS ON 03113(76 ANGLEAT TOPPERF: 17* @ 9404 Note: refer to Production DB for historical perf data SIZE ( SPF ( INTERVAL I OpnlSgz I DATE 9-5/8- CSG, 47#, RS -951W80, D = 8.681' 998T 10030' 03-01 SAFETY NOTES: *** 4-112" CHROME TBG*** 1941' 1996' 9-5/8'x 7" BKR C•2 ZXP LIP w / FLO(LOCK LNR HGR, D = 6.270" 207V H4-12" HES X NP, D = 3.813" 216T 9-518" HES ES CEAA6YTT32 GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3401 3392 16 KGB2 DOME BK 16 06129/12 5 4978 4815 30 KGB2 DOA+£ BK 16 06129!12 4 5797 5508 34 KGB2 DOME BK 16 0629112 3 6663 6224 34 KGB2 SO BK 24 06/M12 2 7488 6917 31 KGB2 DAY BK 0 03/27/07 1 8734 8020 23 KGB2 DM1Y BK 0 103r27107 $802• H4-12- HES X NP, D = 3.813' 8823' H 7- X 4-12" BKR S-3 PKR, D = 3.875' 884T 4-12' HES X NP, D = 3.813" 8911' 4-12" WLEG, D = 3.958- 8913' 7" X 4-12- PORTED XO, D= 3.958" —8913• RtsTRICn ct4, D = 3.88" (E7 13114) $944' 4-12" TBG STIR (0322/07) $953' 9-58' X 4-12" UN QUE OV 9iSHOT 8970' 4-12' X 5-1/2" XO, D = 3.92' 8972' 9-5/8- X 5-112- TIW FBBP-T PKR, D = 4.875' 897T 5-112" X 4-12- XO, D = 3.958" 9128' 4-12- HES XN 9162' B.hiD TT LOG (xxncxrxx)? 9641' — jTOP OF CEMENT (0429110) 96"", 3-38" BP (0429110) ?777 FISH - 4-12- LOCK KEY (720/05) ??7'j FISH - 13.06" LONG BP (06/01102) 9620' CMT PLUG (SET 0421/92) DATE REV BY COMfu6JTS DATE REV BY COLOA34TS 04110/76 ORIGINAL COMPLETION 05/03/10 �JW/PJC CMTCORRECMNS (0429110) 02/26/96 RWO 07/09/12 GJF/JMD GLV GO (06/29/12) 03/30/07 WE'S RWO 11/05/12 HDS/JMD PERF CORK CTION (1028/12) 04/20/07 KSBITLH GLV GO 0725/14 SWCIJMD TBG RESTRICTION (07/13114) 104/291071 FR/PJC JDRLG DRAFT CORRECTIONS 09/18/14 JMD SCHEMATIC CORREC IONS 04/30/10 GJF/PJC SET BP/CEuENT TOP (04/29/10 PRUDHOE BAY UNIT' WELL: 03-01 PERWT No: 1750750 API No: 50-029-20187-00 SEC 11, T10N, RI 5E, 2016' FSL 8 664' FWL BP Exploration (Alaska) PERFORATION SLAS WRY REF LOG: BRCS ON 03/13/76 A NGLE AT TOP PERF: 17' @ 9404 Note: Refer to Production DB for historical perf data SIZE SPF IYTERI/AL Opn/Sgz DATE 02126196 4 9404-9424 S 0421/92 3-3/8' 4 9424-9494 O 03/27/94 FR/PJC jDFLG DRAFT CORRECTIONS 4 9494-9501 S 0421/92 3-318" 4 9522-9536 O 05/04/92 4 9536-9561 S 0421/92 3-318" 4 9571-9592 C 05104/92 4 9592-9608 S 0421192 4 9622 -9658 S 0421192 4 9671-9696 S 0421192 4 9728-9742 S 0421/92 4 9788-9813 S 0421/92 4"bliPr DATE REV BY COA+tAI NTS OATS REV BY COWAgas 04/10176 ORIGINAL COMPLETION 05/03/10 JWF/PJC CMT CORI;E-G NS (0429/10) 02126196 RWO 07/09/12 GJF/.NCO GLV CIO (0629/12) 03/30107 NOES RWO 11/05112 HDS/JWD PERF CORRECTION (10/28112) 0420107 KSBITLH GLV CIO 0725/14 SWC/JW TBG RESTRICTION (07/13/14) 104r291071 FR/PJC jDFLG DRAFT CORRECTIONS 09/18/14 JMD ISCMATICCORRECTIONS 04/30/10 GIF/PJC ISET BP/CBAEW TOP (0429110 R2LAHOE BAY UNIT WELL: 03-01 PBUT No: 1750750 AR No: 50-029-20187-00 SEC 11, T10K R1 5F, 2016' FSL & 664' FWL BP Exploration (Alaska) TREE = 7" CM/ WELLHEAD = FMC ACTUATOR= AXELSON OKB- ELEV = 61' BF. ELEV = PORT KOP= 6 Max Angie = ^ @A' Datum ND KGB2 Daturn TVD = 8800' SS PROPOSED 9-518" CSG, 47#, L-80 TClk D = 8.681^ H 2167' 13-3l8" CSG, 72#, N -BTC, D= 12.347' 1--j 2720' Minimum ID = " @ ' 2-718" X 2-3/8" XO ITOP OF LINER 8 CMT L /—/T 3-112" LNR #, 0087 bpf. ID 2-718" LNR, ®#. _ _ bpf, D = 4-112" TBG, 12.6#, 13CR-80, VAM TOP, .0152 bpf, D = 3.958" 7" LW 26#, L-80, BTC -M, -0383 bpf, D = 6-276" 4-1/2' TBG, 12.6#, L-80,. BT -M, .0152 bpf, D = 3.958" 4-112" TBG STUB (03/22/07) 4-1/2" TBG, 12.6#, 13 -CR -80, NSCCINSCT, .0152 bpf, D = 3.958' 3-1/2' MONOBORE WS w /CMT SLIPS (XX/XX/14) 2.8" C94ENT PLOT HOLE 03-01A 1 —8860' 1 1 8911' 1 8913- F-8-94-7 1 8944' 1 1 9150' 1 PERFORATION SUMMARY REF LOG: ON ANGLEAT TOP PERF: —* @ _' Note: Refer to Reduction DB for historical pert data 9335' 9360' 118* it -OW 19-5/8. CSG, 47#, RS-95/MP} 80, D= 8.681" 99$7' SAFETY NOTES: ***CHROME TBG & LNR*** 1941' 1996' 9-5/8" x 7" BKR C-2 ZXP LTP w / FLEXLOCK LNR HGR, D = 6.270" ST IVD 2157' 9-518^ HES ES TYPE GAS LFT MANDRELS ST IVD TVD DEV TYPE VLV LATCH PORT DATE 6 3401 3392 16 KGB2 DOME BK 16 0629112 5 4978 4815 30 KGB2 DOME BK 16 0629/12 4 5797 5508 34 KGB2 DOME BK 16 0629/12 3 6663 6224 34 KGB2 SO BK 24 0629112 2 7488 6917 31 KG62 DW BK 0 0327107 1 8734 8020 23 KG62 DMY BK 1 d 0327107 8802' j—{4-1/2" HF5 X NlP D= 3.813" 8823' H7' X 4-1/2" BKRS-3 ACR D= 3.875^ 884T 4-112' HEB X NP, D = 3.813' —8860' 3.70" DEPLOY SLV, D = 3.00' MID -t_ 2-3/8" LW #, 13CR-80 bpf, D = " DATE REV BY COMMENTS DATE REV BY COWAENTS 04110/76 ORIGINAL COMPLETION 2-718^ HES X NP, D = 2.313" 02!26/96 RIND 2-718" X 2-318' XO, D = 8911' 4-12" WLEG, D = 3.958^ ^8913' RE.STRJCTION, D = 3.88' (07/13114) 8913' 7" X 4-112" PORTED XO, D = 3.958" 8953' 9-518^ x 4 -tit^ LINgQUEOVE3�SH0T 8970' X 5-12" XO, D = 3.92^ 8972' 9-5/8' X 5-112" TMf hBBP-T PKR, D = 4,875- 897r —T5 -1/2--X 4-1/2" XO, D = 3.98" 9128' 4-112" HES XN NP, D = 3.725" 9150' 4-1/2" WLE�i, D = 3.958" 9152` ELMD TT LOG {XXlXX/XX)7 MLLOUT WINDOW (03-01A) PUP JOINT w /RA TAG, D= " MID -t_ 2-3/8" LW #, 13CR-80 bpf, D = " DATE REV BY COMMENTS DATE REV BY COWAENTS 04110/76 ORIGINAL COMPLETION 02!26/96 RIND 03/30/07 N4E5 RiNO 09/18li4 JMD BUILT PROPOSED 0926114 THIJMD jREVISEDLWTOP`DEF`TH PUP DONT v IRA TAG, D= I PRUDHOE BAY UNIT WELL: 03-01A PERMIT No: API No: 50-029-20187-01 SEG 11, T10K R15E, 2016 FSL & 664' FWL BP Exploration (Alaska) NORDIC CTD UNIT # 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM __ - Choke Penal S1ar19pipe 2"CirculIne Driller GaugeM,0 M7, Manual Choke 'GalistaWIFOLD MMMMB MM 19 (j y� MM 75 ur rranstleger _r>P°'°� _ _y MM6 PVI` Sensor MM7 I Baker Choke MM 13 MM4, MM 17 KILL SIDE MANUAL VALVE CHOKE SIDE I MANUAL VALVE KILL HCR 1 Rev Cir Line /CHOKE HCR fAlr B/ow tlown MM 12 MM14 I NIM Choke Lina I uMng So er Choke KIN Line I I — — — — — — — — — — — — — — MP2 MP, 1 V I J KIII Line 1 \ BOP 1 HP 11 HP 10 rram r CONED TUBING I \SOP 177 } e CIRCULATING SYSTEM Hp,e I 1 HP9 HIPS I I TO Inner Reel 1 Valve HP7 Hp NP4 HP3 '' ! �I 1 HP2 HP, N2 t CHOKE MANIFOLD �- I MGS :Tk I 29 GA3 BUSTER CM 30 O / 1 PB, CM14 CMS Note qu5 CMB C 1 PB2 leg Is I m PB3 ti high — 1 CM7 CM15 CM2 / a POSSUM .BELLY I / aw°iar CM21 CW CM77 C CM20 CM22 CM23 / � Tlperl Tank I I CM1B CM19 /I TIGER TANK _ • Sundry Application Plug for Re -drill Wells Work Flow • This process is used to identify wells that are suspended for a very short time prior to being re -drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status of "Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box in the Patricia or Steve upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Patricia or Steve work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, then check the "Suspended" box and initial that change. Guy or Victoria The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug for Jenni Redrill" box, she will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, she will check the History tab Jenni in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, she will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will change Jenni the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Jenni Geologists will check the "Well by Type Work Outstanding" user query in Patricia or Steve RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. g!Eodata Gyrodata Incorporated 23000 Northwest Lake Dr. Houston, TX 77095 (281)213-6300 Fax: (281) 213-6301 RECEIVED SEP 0 2 2014 AOGGC SURVEY REPORT BP Exploration Drill site: 3, Well: 3-01, 4 112" Tubing Prudhoe Bay, N. Slope Borough Alaska AK0814GCM176 August 4, 2014 Serving the Worldwide Energy Industry with Precision Survey Instrumentation DATA LOGGED R i 3 /20141 M.K.BENDER gEo2da ta Gyrodata Incorporated 23000 Northwest Lake Dr. Houston, TX 77095 (281)213-6300 Fax: (281) 213-6301 August 27, 2014 State of Alaska - AOGCC Attn: Makana Bender 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Re: Drill site: 3, Well 3-01, 4 1/2" Tubing Prudhoe Bay, N. Slope Borough Alaska AK0814GCM176 Enclosed, please find two (2) copies, and one (1) disk of the completed survey for the above referenced well. We would like to take this opportunity to thank you for using Gyrodata, and we look forward to serving you in the future. Sincerely, Rob Shoup VP of Special Services RS:fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation A Gyrodata Directional Survey DEFINITIVE for BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 Run Date: 04 Aug 2014 Depth Reference: Rotary Table Report Generated: 08 Aug 2014,04-11 Air Gap (RKB to Ground / RKB to MSL): 61.00 Surveyor: Christopher Prince, Joshua -Cam a Vertical Section Calculated from Well Head Location Calculation Method: MINIMUM CURVATURE ��rc Closure Calculated from Well Head Location Survey Latitude: 70.233751 deg. N Longitude: 148.272986 deg. W Horizontal Coordinates Calculated from Well Head Location Azimuth Correction: Gyro: Bearings are Relative to True North A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 0.00 0.00 0.00 0.00 0.00 0.0 0.0 0.00 N 0.00 E R.K.B. ELEVATION 61 FT;BASE FLANGE ELEVATION 27.56 FT;SWAB TO BASE FLANGE 13.74 FT; SWAB TO GYRO 8.44 FT; ZERO TOOL ON SWAB 11.26 FT 0 - 9546 FT RATE GYROSCOPIC CONTINUOUS SURVEY RUN IN 4 1/2" TUBING MEASURED DEPTHS ARE REFERENCED TO THE ORIGINAL RKB @ 61 FT AMSL 100.00 0.38 119.23 0.10 100.00 0.3 119.2 0.16 S 0.29 E 200.00 0.44 142.64 0.04 200.00 1.0 127.7 0.63 S 0.81 E 300.00 0.46 190.43 0.09 299.99 1.6 143.8 1.33 S 0.97 E 400.00 0.26 190.09 0.05 399.99 2.1 156.1 1.95 S 0.86 E 500.00 0.27 231.94 0.05 499.99 2.4 164.6 2.32 S 0.64 E 600.00 0.25 236.73 0.01 599.99 2.6 174.1 2.58 S 0.27 E 700.00 0.44 184.18 0.09 699.99 3.1 178.9 3.08 S 0.06 E 800.00 0.71 157.62 0.09 799.98 4.0 176.2 4.04 S 0.27 E 900.00 0.73 155:52 0.01 899.98 5.3 171.6 5.19 S 0.77 E 1000.00 0.54 153,45 0.05 999.97 6.3 168.7 6.20 S 1.24 E 1100.00 0.44 171.25 0.05 1099.97 7.2 167.8 7.00 S 1.51 E 1200.00 0.51 158.72 0.03 1199.96 8.0 167.5 7.79 S 1.73 E 1300.00 0.54 157.55 0.01 1299.96 8.9 166.5 8.64 S 2.07 E 1400.00 0.36 193.72 0.08 1399.96 9.6 166.9 9.38 S 2.18 E 1500.00 0.40 204.23 0.02 1499.95 10.2 168.9 10.00 S 1.96 E 1600.00 0.48 219.90 0.04 1599.95 10.8 171.7 10.64 S 1.55 E 1700.00 0.38 167.52 0.10 1699.95 11.4 173.2 11.29 S 1.35 E A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 1800.00 0.32 134.43 0.05 1799.95 11.9 172.2 11.81 S 1.62 E 1900.00 0.34 105.00 0.04 1899.94 12.3 170.1 12.08 S 2.11 E 2000.00 0.39 99.71 0.02 1999.94 12.5 167.4 12.21 S 2.73 E 2100.00 0.24 111.77 0.04 2099.94 12.8 165.2 12.35 S 3.26 E 2200.00 0.38 76.17 0.06 2199.94 12.9 163.0 12.35 S 3.78 E 2300.00 0.19 64.33 0.05 2299.94 12.9 160.8 12.20 S 4.25 E 2400.00 0.33 154.94 0.10 2399.94 13.2 159.9 12.39 S 4.52 E 2500.00 0.53 144.32 0.05 2499.93 13.9 159.3 13.02 S 4.92 E 2600.00 0.32 154.20 0.06 2599.93 14.6 158.8 13.65 S 5.31 E 2700.00 0.25 150.30 0.02 2699.93 15.1> 158.6 14.09 S 5.53 E 2800.00 4.25 298.35 1.12 2799.84 12.7 169.2 12.51 S 2.38 E 2900.00 5.92 308.16 0.47 2899.45 9.0 213.1 7.57 S 4.94W 3000.00 6.65 319.78 0.37 2998.85 12.7 270.2 0.04 N 12.73 W 3100.00 7.52 323.27 0.24 3098.09 22.6 295.5 9.70 N 20.38W 3125.00 8.38; 318.25 1.11 3122.85 25.7 298.7 12.37 N 22.57 W 3150.00 9.19 312.65 1.17 3147.55 29.4 300.9 15.08 N 25.25W 3175.00 9.99 307.06 1.23 3172.20 33.5 301.9 17.74 N 28.45 W 3200.00 10.62 304.27 0.80 3196.80 38.0 302.4 20.35 N 32.09W 3225.00 10.67 304.12 0.06 3221.37 42.6 302.6 22.94 N 35.91 W 3250.00 11.14 304.56 0.48 3245.92 47.3 302.8 25.61 N 39.81 W 3275.00 11.52 305.03 0.39 3270.43 52.2 302.9 28.41 N 43.84W 3300.00 11.62 305.43 0.13 3294.92 57.3 303.1 31.31 N 47.94W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE DEPTH SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. deg./ feet feet deg. 25 ft. HORIZONTAL COORDINATES feet 3325.00 12.13 305.63 0.51 3319.39 62.4 303.3 34.30 N 52.13 W 3350.00 12.41 305.88 0.28 3343.82 67.7 303.5 37.40 N 56.44W 3375.00 12.75 306.30 0.35 3368.22 73.1 303.7 40.61 N 60.84W 3400.00 13.22 305.89 0.48 3392.58 78.8 303.9 43.92 N 65.38W 3425.00 13.99 307.20 0.83 3416.88 84.6 304.1 47.42 N 70.10W 3450.00 14.10 307.45 0.13 3441.13 90.7 304.3 51.10 N 74.92 W 3475.00 14.66 307.75 0.56 3465.35 96.9 304.5 54.89 N 79.84W 3500.00 14.80 307.60 0.15 3489.52 103.2 304.7 58.77 N 84.87W 3525.00 15.34 308.47 0.59 3513.66 109.7 304.9 62.78 N 89.99 W 3550.00 15.71 307.97 0.40: 3537.75 11`6.4 305.1 66.91 N 95.25 W 3575.00 15.96 308.21 0.27 3561.80: 123.2 305.3 71.12 N 100.63 W 3600.00 16.09 308.25" 0.13. 3585:83 130.1 305.4 75.39 N 106.05 W 3625.00 16.54 308.03 , 0.45 3609.83 137.1 305.5 79.73 N 11 1.57 W 3650.00 16.90 308.01 0.36 3633.77 144.3 305.7 84.16 N 117.24W 3675.00 17 _ .�� �: 0.33" 357 67' x:151.6" oaf ._. ";:305.8 88.67 N 123.02 W 3700.00 17.53 308.08 0.30 3681.53 159.1 305.9 93.27 N 128.90W 3725.00 17.90 308.87 0.44 3705.34 166.7 306.0 98.01 N 134.86W 3750.00 18.23 309.51 0.39 3729.11 174.4 306.1 102.91 N 140.86W 3775.00 18.61 309.32 0.38 3752.83 182.3 306.3 107.92 N 146.97W 3800.00 19.03 309.79 0.45 3776.49 190.4 306.4 113.06 N 153.19 W 3825.00 19.66 310.10 0.64 3800.08 198.7 306.6 118.37 N 159.53 W A Gyrodata Directional Survey BPXA Leaser PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 3850.00 20.23 310.33 0.58 3823.58 207.2 306.7 123.88 N 166.05 W 3875.00 20.65 310.37 0.42 3847.01 215.9 306.9 129.53 N 172.70W 3900.00 21.24 310.14 0.60 3870.35 224.8 307.0 135.31 N 179.52W 3925.00 21.78 310.65 0.57 3893.61 234.0 307.1 141.25 N 186.50W 3950.00 22.24 310.58 0.46 3916.79 243.3 307.3 147.35 N 193.61 W 3975.00 22.91 310.85 0.68 3939.87 252.9 307.4 153.61 N 200.89W 4000.00 23.71 311.75 0.88 3962.83 262.8 307.6 160.14 N 208.32W 4025.00 24.29 312.32 0.62 3985.67 272.9 307.7 166.95 N 215.87 W 4050.00 25.06 312.66 0.78 4008.39 283.3 307.9 174.00 N 223.57W 4075.00 25.65 312.92 0.60: 4030.98 294.0 308.1 181.27 N 231.42W 4100.00 26.22 .' 312.92 0.57 '` 4053.46 304.9 308.2 188.72 N 239.43 W 4125.00 26.64 312.70 ., 0.43 4075.85 316.0 308.4 196.28 N 247.59 W 4150.00 27.05 ' 12-0161',, 0.50 4098.16 327.2 308.5 203.89 N 255.93 W 4175.00 27.44, ° . 311'00- ; 0.39 4120.38 338.6 308.7 211.55 N 264.43 W 4200.00 27.57 '� . =. 311:75. 0.17, 414256 350:2' 308.8 219.26 N 273.03 W 4225.00 27.67 312.03 0.16 ' 4164.71 361.7 308.9 226.99 N 281.66W 4250.00 27.75 312.08 0.08 4186.84 373.3 309.0 234.78 N 290.29 W 4275.00 27.79 312.25 0.09 4208.96 385.0 309.1 242.60 N 298.92W 4300.00 28.04 312.10 0.26 4231.05 396.7 309.2 250.46 N 307.60 W 4325.00 28.13 312.33 0.14 4253.11 408.4 309.2 258.37 N 316.31 W 4350.00 28.17 312.47 0.08 4275.15 420.2 309.3 266.32 N 325.02W 4375.00 28.25 312.29 0.12 4297.18 432.0 309.4 274.28 N 333.75W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM 176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 4400.00 28.13 312.52 0.16 4319.22 443.8 309.5 282.25 N 342.47 W 4425.00 28.27 312.57 0.14 4341.25 455.6 309.6 290.24 N 351.18W 4450.00 28.19 312.45 0.10 4363.28 467.4 309.6 298.23 N 359.89W 4475.00 28.31 312.69 0.17 4385.30 479.2 309.7 306.23 N 368.61 W 4500.00 28.32 312.82 0.06 4407.31 491.1 309.8 314.28 N 377.32W 4525.00 28.39 312.96 0.10 4429.31 502.9 309.9 322.36 N 386.01 W 4550.00 28.63 312.96 0.24 4451.28 514.8 309.9 330.50 N 394.75 W 4575.00 28.62 312.89 0.03 4473.22 526.8 310.0 338.65 N 403.52W 4600.00 28 75 Q 44 5 15 538.8 310.1 346.84 N 412.29 W 4625.00 28 7 A 3 4 550.8 310.1 355.09 N 421.04W 4650.00 28.74 313: N 0.,538.98 562.8 310.2 363.36 N 429.78 W 4675.00 28.92' " " 313. 0. ; $8 574.8 310.3 371.67. N 438.52W 4700.00 28.80 313:64 " " 0.12 4582.78 586.9 310.4 379.99 N 447.25 W 4725.00 28.90 313:85 0.14 4604.68 598.9 310.4 388.33 N 455.97W 4750.00 28.99` 313.98 r 0.11 4626.55 6+11.0 310.5' 3`96.72 N 464.68 W 4775.00 29.05 314.10 0.08 4648.41 623.1 310.6 405.16 N 473.40 W 4800.00 29.33 314.37 0.31 4670.24 635.3 310.6 413.66 N 482.14W 4825.00 29.32 314.71 0.17 4692.04 647.5 310.7 422.25 N 490,86W 4850.00 29.52 314.83 0.21 4713.81 659.7 310.8 430.90 N 499.58W 4875.00 29.50 314.85 0.02 4735.57 672.0 310.9 439.58 N 508.31 W 4900.00 29.42 315.26 0.22 4757.34 684.3 310.9 448.28 N 517.00 W 4925.00 29.90 315.18 0.48 4779.06 696.6 311.0 457.06 N 525.71 W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE DEPTH SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. deg./ feet feet deg. 25 ft. HORIZONTAL COORDINATES feet 4950.00 29.89 315.35 0.09 4800.73 709.0 311.1 465.92 N 534.48 W 4975.00 30.05 315.59 0.20 4822.39 721.5 311.2 474.82 N 543.24W 5000.00 30.24 315.37 0.22 4844.01 734.0 311.2 483.77 N 552.04W 5025.00 30.48 315.18 0.26 4865.58 746.6 311.3 492.75 N 560.94W 5050.00 30.55 315.58 0.21 4887.12 759.3 311.4 501.78 N 569.85 W 5075.00 31.04 315.38 0.50 4908.59 772.1 311.4 510.91 N 578.83 W 5100.00 31.08 315.43 0.05 4930.01 784.9 311.5 520.09 N 587.88W 5125.00 31.39 315.60 0.32 4951.39 797.9 31`1.6 529.34 N 596.97 W 5150.00 31.61. 315°:40 0.24 4972.70 810.9 311.6 538.66 N 606,12W 5175.00 31,73' 3.15.45 0.12 4993.98 824.0 311.7' 548.01 N 615.33 W 5200.00 32.11 315.26 0.39' 5015.20 837.2 311.7 - 557.41 N 624.62 W 5225.00 32.11 315.50 0.13 5036.38 850.4 311.8 566.87 N 633.96 W 5250.00 32.48 315.66 0.38 5057.51 863.8 311.9 576.41 N 643.31 W 5275.00 32.57 315`.80 0.12 5078.59 877.2 311.9 586.04 N 652.69 W 5300.00 32.79 315.73 0.22" 5099.63 890.6 "312.0 595.71 N 662.11 W 5325.00 33.06 316.08 0.33 5120.61 904.2 312.0 605.47 N 671.56W 5350.00 33.03 316.23 0.09 5141.57 917.8 312.1 615.30 N 681.00 W 5375.00 33.22 316.44 0.22 5162.51 931.4 312.2 625.18 N 690.44 W 5400.00 33.27 316.40 0.05 5183.42 945.1 312.2 635.11 N 699,88W 5425.00 33.34 316.20 0.13 5204.31 958.8 312.3 645.04 N 709.37W 5450.00 33.24 315.23 0.54 5225.21 972.5 312.3 654.86 N 718.95 W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 5475.00 32.43 313.79 1.13 5246.21 986.0 312.4 664.36 N 728.61 W 5500.00 32.73 312.78 0.62 5267.28 999.5 312.4 673.59 N 738.41 W 5525.00 33.00 311.97 0.52 5288.28 1013.1 312.4 682.73 N 748.44 W 5550.00 32.85 310.06 1.05 5309.26 1026.6 312.4 691.65 N 758.69W 5575.00 32.78 308.55 0.82 5330.27 1040.2 312.3 700.23 N 769.17W 5600.00 32.50 307.59 0.59 5351.33 1053.6 312.3 708.55 N 779.78 W 5625.00 32.69 307.43 0.21 5372.39 1067.0 312.2 716.75 N 790.47W 5650.00 32.99 307.54 0.31 5393.39 1080.5 312.1 725.00 N 801.23 W 5675.00 33.01 307.83 0.16 5414.36 1094.1 312.1 733.32 N 812.00 W 5700,00 33.61 308.00 0.61 5435.25 1107.8 312.0 741.76 N 822.83 W 5725.00 33.63 307.78 0.12 5456.07 112`1.6 312.0 750.26 N 833.76W 5750.00 34.07 308.41 0.56 5476.83 1135.5 311.9 758.85 N 844.72W 5775.00 34.36 308.26 0.30 5497.51 1149.5 311.9 767.57 N 855.74W 5800.00 34.57 308.42 0.23 5518.12 1163.7 311.8 776.35 N 866.84W 5825.00 34.22 308.76 0.40 5538.75 1177.8 311.8 785.16 N 877.88 W 5850.00 34.46 308.62 0.25 5559.39 1191.8 311.8 793.97 N 888.88W 5875.00 34.26 308.88 0.25 5580.03 1205.9 311.7 802.80 N 899.89 W 5900.00 34.61 308.63 0.38 5600.65 1220.1 311.7 811.65 N 910.91 W 5925.00 34.50 308.79 0.14 5621.24 1234.2 311.7 820.52 N 921.98 W 5950.00 34.68 309.08 0.24 5641.82 1248.4 311.6 829.44 N 933.02w 5975.00 34.82 308.95 0.16 5662.36 1262.6 311.6 838.41 N 944.09W 6000.00 34.49 308.83 0.34 5682.92 1276.8 311.6 847.33 N 955.15 W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM 176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE DEPTH SEVERITY DEPTH DIST. AZIMUTH feet deg. deg, deg./ feet feet deg. 25 ft. HORIZONTAL COORDINATES feet 6025.00 34.27 309.28 0.34 5703.56 1290.9 311.5 856.23 N 6050.00 34.23 309.42 0.09 5724.22 1305.0 311.5 865.15 N 6075.00 34.44 309.39 0.21 5744.86 1319.1 311.5 874.10 N 6100.00 34.74 309.62 0.33 5765.45 1333.3 311.5 883.13 N 6125.00 34.65 310.09 0.28 5786.00 1347.5 311.5 892.25 N 6150.00 34.93 310.63 0.42 5806.53 1361.8 311.5 901.49 N 6175.00 34.69 310.72 0.25 5827.06 1376.0 311.4 910.79 N 6200.00 34.79 310.87 0.13 5847.60 1390.3 311.4 920.10 N 6225.00 34.64 311.08 0.19 5868.15 1404.5 311.4 929.43 N 6250.00 34.60 311.34 0.15 5888.72 1418.7 311.4 938.79 N 6275.00 34.77 311.20 0.19 5909.28 1432.9 311.4 948.17 N 6300.00 34.41 311.37 0.37 5929.86 1447.1 311.4 957.54 N 6325.00 34.52 311.39 0.11 5950.47 1461.3 311.4 966.89 N 6350.00 34.51 311.21` 0.10 5971.07 1475.4 311.4 976.24 N 6375.00 34.45 311.21 0.06 5991:68 1489.6 311.4 985.56 N 6400.00 34.91 311.48 0.48 6012.24 1503.8 311.4 994.96 N 6425.00 34.75 311.29 0.19 6032.76 1518.1 311.4 1004.40 N 6450.00 34.77 311.41 0.07 6053.30 1532.4 311.4 1013.82 N 6475.00 34.65 312.06 0.39 6073.85 1546.6 311.4 1023.29 N 6500.00 34.49 311.69 0.26 6094.44 1560.8 311.4 1032.76 N 6525.00 34.39 312.15 0.28 6115.06 1574.9 311.4 1042.21 N 6550.00 34.43 312.35 0.12 6135.68 1589.0 311.4 1051.71 N 966.12 W 977.00 W 987.89W 998.84 W 1009.77 W 1020.64W 1031.46W 1042.24 W 1052.99W 1063.68 W 1074.37W 1085.04W 1095.65W 1106,29W 1116.94 W 1127.62W 1138.33W 1149.03W 1159.66W 1170.22W 1180.74W 1191.20W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCMI76 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE DEPTH SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. deg./ feet feet deg. 25 ft. HORIZONTAL COORDINATES feet 6575.00 34.34 311.75 0.35 6156.31 1603.2 311.4 1061.16 N 1201.68W 6600.00 34.49 312.20 0.30 6176.94 1617.3 311.5 1070.61 N 1212.18 W 6625.00 34.14 312.32 0.36 6197.59 1631.4 311.5 1080.09 N 1222.62 W 6650.00 34.47 312.32 0.33 6218.24 1645.5 311.5 1089.58 N 1233.03W 6675.00 34.36 311.75 0.34 6238.86 1659.6 311.5 1099.04 N 1243.53W 6700.00 33.97 312.50 0.57 6259.55 1673.6 311.5 1108.45 N 1253.94W 6725.00 34.30 312.22 0.37 6280.24 1687.7 311.5 1117.91 N 1264.31 W 6750.00 34.10 312.25 0.20 6300.92 1701.7 311.5 1127.35 N 1274.71 W 6775.00 33.95 312.81 0.35 6321.64 1715.7 311.5 1136.81 N 1285.02W 6800.00 34.10 312.51 0.23 6342.36 1729.7 311.5 1146.29 N 1295.31 W 6825.00 33.88 312.09 0.32 6363.08 1743.7 311.5 1155.69 N 1305.64W 6850.00 33.98 312.86 0.44 6383.83 1757.6 311.5 1165.12 N 1315.94W 6875.00 33.87 312.48: 0.24 6404.57 1771.6 311.5 1174.57 N 1326.20W 6900.00 33.50 311.93 0.48. 6425.37 1785.4 311.5 1183.89 N 1336.47W 6925.00 33.63 '. 312.66 _. 6446.21 ` 1799.2 311.5 '' 1193.19 N 1346.69 W 6950.00 33.94 312.66 0.31 6466.98 1813.1 311.6 1202.61 N 1356.91 W 6975.00 33.51 312.02 0.56 6487.78 1827.0 311.6 1211.96 N 1367.17W 7000.00 33.18 312.22 0.35 6508.66 1840.8 311.6 1221.18 N 1377.37W 7025.00 33.34 312.40 0.19 6529.57 1854.5 311.6 1230.41 N 1387.50W 7050.00 33.36 311.83 0.31 6550.45 1868.2 311.6 1239.62 N 1397.70W 7075.00 33.02 312.45 0.48 6571.37 1881.9 311.6 1248.80 N 1407.85W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 7100.00 33.47 312.68 0.47 6592.28 1895.6 311.6 1258.07 N 1417,94W 7125.00 33.00 312.10 0.57 6613.19 1909.3 311.6 1267.31 N 1428.06W 7150.00 33.13 312.71 0.36 6634.14 1922.9 311.6 1276.51 N 1438.13W 7175.00 33.04 312.36 0.21 6655.09 1936.6 311.6 1285.74 N 1448,19W 7200.00 32.84 311.94 0.30 6676.07 1950.2 311.6 1294.86 N 1458.27W 7225.00 32.95 312.16 0.16 6697.06 1963.8 311.6 1303.95 N 1468.35W 7250.00 33.05 312.84 0.38 6718.03 1977.4 311.6 1313.15 N 1478.39W 7275.00 32.53 311.77 0.78 6739.04 1990.9 311.6 1322.26 N 1488.40W 7300.00 32.73 312.06 0.25 6760.10 2004.4 311.6 1331.27 N 1498.43W 7325.00 32.88 312.87 0.46; 6781.11 2017.9 311.6 1340.41 N 1508.42W 7350.00 32.21, 311.76 0.90; 6802.19 2031.4 311:6 1349.47 N 1518.37W 7375.00 32.41" 311.88 0.21 6$23.32 2044.7 311.6 - 1358.38 N 1528.32W 7400.00 32.74 311.69 0.35 6844.38 2058.2 311.6 1367.35 N 1538.36W 7425.00 32.49 311:93 0.28 6865.44 2071.7 311.6 1376.33 N 1548.40W 7450.00 32.13 312.32 0.42 6886.57 2085.0 311.6'- 1385.29 N 1558.31 W 7475.00 32.4I 312.13 0.30 6907.71 2098.4 311.6 1394.26 N 1568.20W 7500.00 32.06 311.72 0.41 6928.85 2111.7 311.6 1403.17 N 1578.12W 7525.00 31.67 312.15 0.45 6950.09 2124.9 311.6 1411.99 N 1587,94W 7550.00 31.60 312.99 0.45 6971.37 2138.0 311.6 1420.86 N 1597.59W 7575.00 31.49 312.60 0.23 6992.68 2151.1 311.7 1429.75 N 1607.19W 7600.00 31.43 311.88 0.38 7014.00 2164.2 311.7 1438.52 N 1616.85W 7625.00 31.07 312.60 0.52 7035.38 2177.1 311.7 1447.24 N 1626.45 W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM 176 MEASURED DEPTH feet 7650.00 7675.00 7700.00 7725.00 7750.00 7775.00 7800.00 7825.00 7850.00 7875.00 7900.00 7925.00 7950.00 7975.00 8000.00 8025.00 8050.00 8075.00 8100.00 8125.00 8150.00 8175.00 INCL AZIMUTH deg. deg. DOGLEG VERTICAL CLOSURE SEVERITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 25 ft. HORIZONTAL COORDINATES feet 30.87 313.40 0.46 7056.81 2190.0 311.7 1456.01 N 31.12 312.40 0.57 7078.24 2202.9 311.7 1464.77 N 30.83 312.78 0.35 7099.68 2215.7 311.7 1473.48 N 30.55 313.62 0.51 7121.18 2228.5 311.7 1482.22 N 30.96 313.12 0.48 7142.66 2241.3 311.7 1491.00 N 30.18 312.79 0.80 7164.19 2254.0 311.7 1499.66 N 29.96 313.95 0.62 7185.82 2266.5 311.7 1508.26 N 30.24 313.59 0.33 7207.45 2279.0 311.7 1516.93 N 29.90 313 T 0 X41 ;7229:08 ,�� 229 i .5 311.7 1525.53 N 29.92 313, r7�50.75 ` 2304.0 311.7 1534.12 N 29.59" 314:81 0 57 7272.46 ,%,223164 311.8 1542.79 N 29.41 313.87 , �" = 0.50'. 2 2328.7 311.8 1551.39 N 29.421, 314:19, 0.16 7316.00 2341.0 311.8 1559.93 N 29.38 315.5'6`` 0.67 7337.78 2353.2 311.8 1568.58 N 28.39 315AIj>° 0.99 ' 7359:67 23.65.3 311.8 1577.20 N 28.39 314.b 0.37 7381.66 2377.1 311.8 1585.62 N 28.42 315.15 0.22 7403.65 2389.0 311.9 1594.01 N 28.07 314.99 0.36 7425.67 2400.8 311.9 1602.39 N 27.85 316.36 0.68 7447.75 2412.5 311.9 1610.77 N 27.93 315.60 0.36 7469.85 2424.2 311.9 1619.18 N 27.19 315.07 0.78 7492.01 2435.7 311.9 1627.41 N 27.27 316.50 0.66 7514.24 2447.1 311.9 1635.61 N 1635.86W 1645.29W 1654.77W 1664.07W 1673,36W 1682.67W 1691.77W 1700.83 W 1709.93 W 1718.97W 1727.85W 1736.65W 1745.48W 1754.18W 1762.64 W 1771.03 W 1779.45W 1787.81 W 1796.00 W 1804.12W 1812.25W 1820.23 W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE DEPTH SEVERITY DEPTH DIST. AZIMUTH feet deg. deg. deg./ feet feet deg. 25 ft. HORIZONTAL COORDINATES feet 8200.00 27.18 316.26 0.14 7536.47 2458.5 312.0 1643.89 N 1828.12W 8225.00 26.91 315.56 0.42 7558.74 2469.9 312.0 1652.05 N 1836.03 W 8250.00 26.71 317.16 0.75 7581.05 2481.1 312.0 1660.21 N 1843.81 W 8275.00 26.09 316.18 0.76 7603.45 2492.2 312.0 1668.30 N 1851.44W 8300.00 26.62 316.45 0.54 7625.85 2503.3 312.0 1676.32 N 1859.10W 8325.00 25.96 317.08 0.72 7648.26 2514.3 312.1 1684.39 N 1866.69 W 8350.00 25.40 317.65 0.61 7670.79 2525.1 312.1 1692.36 N 1874.03 W 8375.00 25.97 317.80 0.57 7693.32 2535.9 312.1 1700.38 N 1881.32W 8400.00 25.89 316.72 0.48 7715.80 2546.8 312.1 1708.41 N 1888.73W 8425.00 24.94 317.75 ' 1.05' 7738.39 2557.4" 312.2 1716.28 N 1896.02W 8450.00 25.26 3`18.21 0.37; . 7761.02 2568.0 312.2 1724.16 N 1903.12W 8475.00 24.94 317.46 0.45" 7783.66 2578.5 3+12.2 1732.02 N 1910,24W 8500.00 24.98 317.04 0.18 7806.33 2589.1 312.2 1739.77 N 1917.40W 8525.00 25.10 317.95 0.40 7828.98 2599.6 312.2 1747.57 N 1924.55W 8550.00 24.24' 318.41 - 0.88 7851.70 " 2610.0 312.3 1755.34 N 1931.51 W 8575.00 24.58 318.63 0.35 7874.46 2620.2 312.3 1763.09 N 1938,35W 8600.00 24.44 317.84 0.36 7897.21 2630.6 312.3 1770.82 N 1945.26W 8625.00 23.68 318.67 0.83 7920.04 2640.7 312.3 1778.42 N 1952.04W 8650.00 23.69 319.94 0.51 7942.93 2650.7 312.4 1786.04 N 1958,59W 8675.00 23.93 318.71 0.55 7965.80 2660.7 312.4 1793.69 N 1965,17W 8700.00 23.27 319.10 0.68 7988.71 2670.6 312.4 1801.23 N 1971.75W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED DEPTH feet 8725.00 8750.00 8775.00 8800.00 8825.00 8850.00 8875.00 8900.00 8925.00 8950.00 8975.00 9000.00 9025.00 9050.00 9075.00 9100.00 9125.00 9150.00 9175.00 9200.00 9225.00 9250.00 INCL AZIMUTH deg. deg. DOGLEG VERTICAL CLOSURE SEVERITY DEPTH DIST. AZIMUTH deg./ feet feet deg. 25 ft. 23.18 320.37 0.51 8011.69 2680.4 312.4 22.78 320.83 0.44 8034.70 2690.1 312.5 21.86 320.58 0.92 8057.83 2699.5 312.5 21.57 322.32 0.71 8081.06 2708.6 312.5 21.56 321.97 0.13 8104.31 2717.7 312.6 21.41 322.39 0.21 8127.57 2726.7 312.6 20.75 322.62 0.67 8150.90 2735.5 312.6 20.72 324.34 0.61 8174.28 2744.2 312.7 20.84 323.83 0.22 8197.65 2752.9 312.7 20.28 323.73 0.56 8221.06 2761.5> 312.7 20.33 ' 325.03 0.45 8244.50 2770.0 312.8 19.39 324.78 0.94 8268.02 2778.3 312.8 19.71 325.59 0.42 8291.58' 2786.5 312.8 19.50` 325.41 0.22 8315.13 2794.7 312.9 19.40 326.01 0.22 8338.70 2802.8 312.9 18.99 326.63 0.46 8362.31 2810.8 313.0 18.90 326.57 0.09 8385.96 2818.7 313.0 18.89 326.87 0.10 8409.61 2826.6 313.0 18.68 328.43 0.54 8433.28 2834.4 313.1 18.54 328.41 0.14 8456.97 2842.1 313.1 18.32 328.73 0.24 8480.69 2849.7 313.2 18.06 329.12 0.29 8504.44 2857.2 313.2 HORIZONTAL COORDINATES feet 1808.76 N 1978.12W 1816.30 N 1984.31 W 1823.65 N 1990.33 W 1830.88 N 1996.09 W 1838.13 N 2001.73 W 1845.37 N 2007.35W 1852.50 N 2012.82 W 1859.61 N 2018.09 W 1866.80 N 2023.29W 1873.88 N 2028.48W 1880.93 N 2033.53W 1887.88 N 2038,41W 1894.75 N 2043.19 W 1901.66 N 2047.94W 1908.54 N 2052.63 W 1915.38 N 2057.19W 1922.16 N 2061.65 W 1928.92 N 2066.10W 1935.72 N 2070.40W 1942.52 N 2074,58W 1949.26 N 2078.70W 1955.95 N 2082.73 W A Gyrodata Directional Survey BPXA Lease: PRUDHOE BAY UNIT - EOA Well: DRILLSITE: 03 WELL: 03-01, 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Job Number: AK0814GCM176 MEASURED INCL AZIMUTH DOGLEG VERTICAL CLOSURE HORIZONTAL DEPTH SEVERITY DEPTH DIST. AZIMUTH COORDINATES feet deg. deg. deg./ feet feet deg. feet 25 ft. 9275.00 17.89 329.46 0.20 8528.22 2864.6 313.2 1962.58 N 2086.67W 9300.00 17.60 329.96 0.33 8552.03 2871.9 313.3 1969.16 N 2090.52W 9325.00 17.48 330.27 0.15 8575.87 2879.1 313.3 1975.69 N 2094.27W 9350.00 17.33 330.30 0.15 8599.72 2886.3 313.4 1982.19 N 2097.98 W 9375.00 17.09 330.76 0.28 8623.60 2893.3 313.4 1988.63 N 2101.62 W 9400.00 16.89 331.01 0.21 8647.51 2900.3 313.5 1995.01 N 2105.17W 9425.00 17.08 330.74 0.21 8671.42 2907.3 313.5 2001.39 N 2108.73 W 9450.00 17.03 330.96 0.08 8695.32 2914.3 313.5 2007.79 N 2112.30W 9475.00 16.97 330.99 0.06 8719.23 2921.3 313.6 2014.18 N 2115.84 W 9500.00 17.00 331.37 0.11 ` 8743.14 2928.2 313.6 2020.58 N 2119.36 W 9525.00 16.96 331.01 0.11 8767.05 2935.2 313`.7 2026.98 N 2122.88W 9546.00 17.11 330.79 0.19 8787.13 2941.1 313.7 2032.36 N 2125.87W Final Station Closure: Distance: 2941.06 ft Az: 313.71 deg. BPXA Well: PRUDHOE BAY UNIT - EOA DRILLSITE: 03 WELL: 03-01 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH 3S 30 25 z O 20 H z U z 15 10 5 C 11 Aug 10:44 Presented Survey Gyrodata AK0814GCM176 DEFINITIVE -------------------- ,-------------------- ------ i i------ ------- ---------------------------------- ---- ------ BOTTOM HOLE LOCATED MD: 9546.00 t........................................ .................. 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 MEASURED DEPTH (ft) BPXA Well: PRUDHOE BAY UNIT - EOA DRILLSITE: 03 WELL: 03-01 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH Illlllllllllllllli>���Z�] 250 200 N Q 150 100 11 Aug 10:44 Presented Survey Gyrodata AK0814GCM176 DEFINITIVE BOTTOM HOLE LOCATED MD::9546.00 r - 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 MEASURED DEPTH (ft) BPXA Well: PRUDHOE BAY UNIT - EOA DRILLSITE: 03 WELL: 03-01 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH 1.2 1.1 1.0 0.9 0.8 > 0.7 w V) U 0.6 J O 0.5 0.4 0.3 0.2 0.1 0.0 r � 11 Aug 10:44 Presented Survey Gyrodata AK0814GCM176 DEFINITIVE ---- - . .................. ------------------- .......... ---- -- - - -------------- ------ --- - ---- ------------- ---- - - ---- -- ----------------------------------------- - - - - - - - - - - - - - - - - - - - - - .................... .............. ---- - - - - - - - - - - - - ------- -- - ----- ----- .... - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - . . . . . . . --- . . . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - BOTTOM HOLE LOCATED -------------------------- --; -- ----- ------------ ------------------------------------------- MD 546-00----- --- -- -- - -- - --- - - ---- �9 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 MEASURED DEPTH (ft) BPXA Well: PRUDHOE BAY UNIT - EOA DRILLSITE: 03 WELL: 03-01 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH 0 1000 2000 3000 4000 a LU D J V 5000 LU 6000 7000 mi 11 Aug 10:45 Presented Survey Gyrodata AK0814GCM176 DEFINITIVE 0 1000 2000 3000 4000 5000 6000 7000 8000 9000 10000 11000 MEASURED DEPTH (ft) BPXA Well: PRUDHOE BAY UNIT - EOA DRILLSITE: 03 WELL: 03-01 4 1/2" TUBING Location: WELLHEAD, N. SLOPE BOROUGH 2000 1800 1600 1400 ,1200 z = 1000 0 z 80C 60C 40C 20C C t r 11 Aug 10:45 Presented Survey Gyrodata AK0814GCM176 DEFINITIVE BOTTOM HOLO ------ -LOCATED- -------; ........ ------------------ I ------------- ---- .....--------------- -- ----- ---. .---------------..-------------------------- ------ D 9546.00 --------------------------------------- -2200 -2000 -1800 -1600 -1400 -1200 -1000 -800 -600 -400 -200 0 EASTING (ft) Survey QC - RGS-CT Specification Sheet I gpotata SURVEY QUALITY CONTROL - SPECIFICATION DATA PRE -JOB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 64 270.32 299.46 0.00007454 -10.61 63 270.32 304.90 0.00007590 -10.89 62 225.00 750.87 0.00018777 -13.30 61 225.00 742.13 0.00018558 -15.31 60 45.51 635.96 0.00015898 -7.96 59 45.51 635.25 0.00015880 -10.82 58 359.38 -68.54 -0.00001722 -13.08 57 359.38 -57.99 -0.00001457 -12.48 56 330.38 -527.84 -0.00013229 -14.20 55 330.38 -519.47 -0.00013020 -14.59 54 300.65 -374.94 -0.00009354 -11.59 53 300.65 -373.77 -0.00009325 -12.72 52 269.32 331.95 0.00008263 -9.29 51 269.32 339.21 0.00008444 -9.50 50 240.10 762.76 0.00019030 -13.26 49 240.10 770.79 0.00019231 -13.34 48 209.84 591.86 0.00014835 -11.22 47 209.84 591.88 0.00014835 -12.74 46 179.25 -28.20 -0.00000708 -10.63 45 179.25 -29.38 -0.00000738 -10.79 44 149.15 -557.51 -0.00013969 -7.61 43 149.15 -552.90 -0.00013854 -10.38 42 118.73 -399.37 -0.00009960 -9.29 41 118.73 -392.15 -0.00009780 -10.16 40 90.80 189.57 0.00004718 -6.60 39 90.80 194.09 0.00004830 -7.61 38 60.00 656.74 0.00016382 -10.40 37 60.00 655.78 0.00016358 -9.64 36 29.68 516.25 0.00012938 -7.23 35 29.68 517.70 0.00012975 -7.54 34 359.32 -52.63 -0.00001322 -10.31 33 359.33 -45.89 -0.00001153 -14.12 32 269.69 324.16 0.00008069 -10.64 31 269.69 328.97 0.00008189 -11.61 30 222.92 744.40 0.00018621 -12.48 29 222.92 741.05 0.00018537 -15.07 28 45.48 656.22 0.00016405 -0.70 27 45.48 660.15 0.00016504 -0.58 26 0.77 -21.37 -0.00000537 -3.55 25 0.77 -13.31 -0.00000334 -4.85 24 331.82 -506.93 -0.00012708 -11.27 23 331.82 -502.25 -0.00012591 -10.73 22 301.22 -377.84 -0.00009427 -8.37 21 301.22 -376.03 -0.00009382 -9.44 20 269.40 338.61 0.00008429 -6.82 19 269.40 341.51 0.00008501 -7.50 18 239.66 783.35 0.00019546 -6.91 17 239.66 784.03 0.00019563 -5.24 16 211.20 624.76 0.00015657 -7.83 15 211.20 625.91 0.00015686 -12.68 14 180.76 14.12 0.00000355 -1.03 13 180.76 18.36 0.00000461 -5.00 12 150.24 -537.57 -0.00013472 -5.92 11 150.24 -539.02 -0.00013509 -4.45 10 119.83 -399.90 -0.00009975 -10.09 9 119.83 -403.63 -0.00010068 -12.25 8 90.23 234.29 0.00005831 0.19 7 90.23 240.59 0.00005988 -1.21 6 60.06 682.50 0.00017025 -7.29 5 60.06 689.75 0.00017206 -7.90 SURV-Q167 (OPS SUR -MA -003) 19'h Nov 03 / Rev 15 Page i of 6 AK0814GCM176 Survey QC - RGS-CT Specification Sheet yl*►t 4 30.11 528.57 0.00013246 -8.18 3 30.12 531.64 0.00013323 -10.96 2 359.57 -89.01 -0.00002236 -7.24 1 359.57 -89.08 -0.00002238 -7.93 MBO = 0.14 Gravity Error = 180.37 Scale Factor Uncertainty = 0.00004501 Rate Error = -9.14 POST -]OB CALIBRATION VERIFICATION CHECK (ROLL TEST) Station ToolFace Gravity Error Scale Factor Rate Error (deg) (Mg) Uncertainty (deg/min) 13177 270.05 306.51 0.00007629 -6.92 13176 270.05 311.64 0.00007757 -5.24 13175 225.63 778.78 0.00019473 -15.47 13174 225.63 777.53 0.00019442 -14.18 13173 46.01 676.91 0.00016922 -8.81 13172 46.01 680.78 0.00017019 -9.00 13171 0.37 8.38 0.00000211 -8.33 13170 0.37 7.38 0.00000185 -3.57 13169 330.01 -479.67 -0.00012023 -6.80 13168 330.01 -471.66 -0.00011822 -7.55 13167 301.60 -362.62 -0.00009048 -6.11 13166 301.60 -359.68 -0.00008975 -8.98 13165 270.25 319.73 0.00007959 -7.63 13164 270.25 326.94 0.00008138 -7.61 13163 240.05 785.73 0.00019604 -7.57 13162 240.05 786.08 0.00019613 -7.01 13161 210.14 644.38 0.00016153 -5.63 13160 210.14 641.63 0.00016084 -6.44 13159 180.61 50.59 0.00001271 -5.35 13158 180.61 49.89 0.00001254 -5.51 13157 150.39 -500.78 -0.00012552 -4.87 13156 150.39 -495.98 -0.00012431 -5.87 13155 120.17 -406.10 -0.00010130 -4.56 13154 120.17 -402.48 -0.00010040 -3.16 13153 89.80 223.32 0.00005558 -3.33 13152 89.80 226.06 0.00005626 -4.30 13151 60.63 669.39 0.00016696 -7.37 13150 60.63 671.25 0.00016743 -7.40 13149 30.99 551.34 0.00013816 -8.66 13148 30.99 547.19 0.00013712 -7.76 13147 0.68 9.00 0.00000226 -12.30 13146 0.68 13.85 0.00000348 -15.60 13145 269.32 339.94 0.00008462 -8.86 13144 269.32 345.08 0.00008590 -7.63 13143 225.27 749.19 0.00018734 -8.81 13142 225.27 750.56 0.00018768 -10.73 13141 44.70 652.33 0.00016310 -6.08 13140 44.70 648.84 0.00016223 -6.68 13139 359.71 -36.34 -0.00000913 -6.56 13138 359.71 -30.40 -0.00000764 -5.75 13137 329.39 -510.97 -0.00012805 -8.76 13136 329.39 -504.69 -0.00012648 -7.24 13135 300.21 -333.98 -0.00008332 -9.02 13134 300.21 -333.18 -0.00008312 -7.70 13133 270.22 340.47 0.00008475 -7.99 13132 270.22 350.11 0.00008715 -6.81 13131 239.91 774.97 0.00019335 -8.24 13130 239.91 775.60 0.00019351 -7.31 13129 210.28 605.98 0.00015188 -6.78 13128 210.28 604.40 0.00015149 -8.23 13127 180.63 16.91 0.00000425 -6.03 13126 180.62 20.44 0.00000514 -4.80 13125 150.08 -520.37 -0.00013042 -3.45 SURV-Q167 (OPS SUR -MA -003) 19'" Nov 03 / Rev 15 Pape 2 of 6 AK0814GCM176 Survey QC - RGS-CT Specification Sheet 13124 150.08 -517.54 -0.00012971 -4.29 13123 120.59 -389.88 -0.00009726 -4.22 13122 120.59 -389.18 -0.00009709 -3.47 13121 89.64 278.16 0.00006923 -4.74 13120 89.64 294.34 0.00007326 -4.60 13119 60.33 691.74 0.00017255 -4.23 13118 60.33 698.90 0.00017434 -5.26 13117 31.87 544.00 0.00013630 -4.56 13116 31.87 547.76 0.00013724 -3.62 13115 1.01 -36.02 -0.00000905 -4.36 13114 1.01 -29.07 -0.00000730 -4.85 MBO = 0.32 Gravity Error = 202.87 Scale Factor Uncertainty = 0.00005064 Rate Error = -6.88 INITIALISATION Gyro Compass Reading / Station Raw Inclination Raw Azimuth Abs (ERM -s ERrneo) 143 10.60 305.38 0.0191 144 10.60 305.41 0.0184 145 10.60 305.57 0.0446 146 10.60 305.43 0.0250 147 10.60 305.34 0.0019 148 10.60 305.56 0.0030 Average 10.60 305.45 0.0186 Tolerance on Average* 0.002 4 0.0821 Standard Deviation 0.00 0.10 0.0158 Tolerance on St. Dev.** 0.10 0.20 0.0380 Advanced Initialisation Azimuth, Ending Time Ending Depth Advanced Initialisation Standard Deviation Ending Azimuth Tolerance = TBA * Tolerance on Average of earth horizontal rate difference is given by (1/Cost) * J[(CosA*SinI*0.1)2+0.0811 0/hr ** Tolerance on Standard Deviation of earth horizontal rate difference tolerance is given by (1/Cost) *A(CosA*SinI*0.1)2+(0.082/(n-1))) O/hr DRIFT TUNES Drift Tune Number Ending Time Ending Depth Ending Inclination Ending Azimuth Residual Gx Bias Start End Residual Gy Bias Start End 1 655.91 4000.20 23.61 311.31 0.001 -0.000 -0.002 0.002 2 1388.22 6001.91 34.56 308.33 0.002 -0.002 -0.004 0.004 3 1400.26 8007.24 28.78 314.64 0.002 -0.003 -0.002 0.002 4 790.45 8800.08 21.53 321.94 -0.001 0.001 0.002 -0.003 5 1115.04 9546.92 17.16 330.75 -0.000 0.000 -0.001 -0.000 6 1007.93 8800.42 21.82 322.89 -0.001 0.001 -0.001 -0.001 7 1059.86 8007.03 28.47 315.31 -0.000 0.001 -0.004 0.002 8 2140.88 6000.04 34.45 309.34 -0.003 0.004 0.001 -0.003 9 2159.66 3999.94 23.79 312.18 -0.004 0.003 0.004 -0.003 10 1056.89 3179.80 10.31 305.83 -0.002 0.002 0.001 -0.001 Average -0.001 0.001 -0.001 -0.000 Standard Deviation 0.002 0.002 0.003 1 0.002 Tolerance for both the Average and the Standard Deviation 0.0330/hr 0.0330/hr 0.0330/hr I 0.0330/hr SURV-Q167 (OPS SUR -MA -003) 19' Nov 03 / Rev 15 Page 3 of 6 AK0814GCM176 Survey QC - RGS-CT Specification Sheet � gyp*1ata_ INCLINATION AND AZIMUTH INRUN AND OUTRUN COMPARISON Depth Corrected Inclination Corrected Azimuth Inrun * Outrun* Difference Inrun * Outrun * Difference 100.00 0.40 0.30 0.10 119.11 121.96 -2.85 200.00 0.43 0.44 -0.01 154.85 142.69 12.16 300.00 0.46 0.38 0.09 192.47 180.53 11.93 400.00 0.37 0.26 0.10 212.68 191.25 21.43 500.00 0.27 0.23 0.04 232.83 229.75 3.08 600.00 0.25 0.24 0.01 206.60 237.73 -31.13 700.00 0.23 0.44 -0.21 180.93 183.25 -2.32 800.00 0.49 0.71 -0.22 163.99 156.49 7.50 900.00 0.74 0.73 0.01 147.06 155.18 -8.12 1000.00 0.66 0.54 0.12 160.89 152.46 8.43 1100.00 0.57 0.38 0.19 175.04 170.09 4.96 1200.00 0.57 0.51 0.06 176.50 157.80 18.70 1300.00 0.57 0.54 0.03 178.35 156.77 21.58 1400.00 0.57 0.35 0.22 191.51 194.58 -3.07 1500.00 0.58 0.40 0.18 204.68 204.99 -0.31 1600.00 0.50 0.48 0.02 206.89 220.49 -13.61 1700.00 0.43 0.38 0.05 209.37 166.77 42.60 1800.00 0.34 0.32 0.01 135.09 133.44 1.65 1900.00 0.24 0.34 -0.10 60.70 104.07 -43.37 2000.00 0.23 0.39 -0.16 81.31 98.98 -17.66 2100.00 0.22 0.25 -0.03 102.89 114.31 -11.42 2200.00 0.20 0.38 -0.18 77.89 75.80 2.09 2300.00 0.17 0.20 -0.02 53.10 63.92 -10.82 2400.00 0.36 0.33 0.04 104.74 155.68 -50.94 2500.00 0.56 0.53 0.02 155.73 143.64 12.09 2600.00 0.46 0.32 0.14 143.37 155.29 -11.92 2700.00 0.36 0.22 0.13 130.88 155.42 -24.54 2800.00 3.05 4.25 -1.20 218.31 299.34 -81.03 2900.00 5.75 5.93 -0.17 306.06 309.05 -2.99 3000.00 6.66 6.65 0.00 315.34 319.85 -4.51 3100.00 7.52 7.58 -0.05 322.94 323.04 -0.10 3200.00 10.59 10.65 -0.06 304.33 304.10 0.23 3300.00 11.61 11.62 -0.01 305.43 305.31 0.12 3400.00 13.18 13.28 -0.10 305.65 306.04 -0.38 3500.00 14.79 14.94 -0.15 307.36 307.74 -0.38 3600.00 16.07 16.10 -0.03 308.05 308.36 -0.31 3700.00 17.49 17.29 0.21 307.72 308.37 -0.64 3800.00 19.03 19.01 0.01 309.91 309.58 0.33 3900.00 21.21 21.28 -0.07 309.85 310.36 -0.51 4000.00 23.68 23.69 -0.01 311.32 312.16 -0.84 4100.00 26.23 26.20 0.03 312.68 313.12 -0.44 SURV-Q167 (OPS SUR -MA -003) 19" Nov 03 / Rev 15 Page 4 of 6 AK0814GCM176 Survey QC - RGS-CT Specification Sheet gymldsta] 4200.00 27.60 27.37 0.23 311.60 311.86 -0.26 4300.00 28.08 27.80 0.28 311.89 312.28 -0.39 4400.00 28.16 27.92 0.25 312.09 312.91 -0.82 4500.00 28.35 28.03 0.32 312.47 313.15 -0.68 4600.00 28.83 28.39 0.43 312.84 313.58 -0.74 4700.00 28.83 28.49 0.34 313.26 314.00 -0.73 4800.00 29.35 29.04 0.31 313.95 314.77 -0.82 4900.00 29.45 29.25 0.20 315.03 315.48 -0.45 5000.00 30.29 29.93 0.36 315.12 315.62 -0.50 5100.00 31.08 30.91 0.17 315.02 315.84 -0.82 5200.00 32.09 31.89 0.20 314.84 315.67 -0.82 5300.00 32.80 32.52 0.28 315.30 316.16 -0.86 5400.00 33.24 33.04 0.21 315.94 316.86 -0.92 5500.00 32.73 32.47 0.26 312.37 313.18 -0.81 5600.00 32.49 32.25 0.25 307.17 308.00 -0.83 5700.00 33.59 33.42 0.17 307.77 308.22 -0.44 5800.00 34.59 34.29 0.29 307.91 308.93 -1.03 5900.00 34.64 34.48 0.15 308.14 309.11 -0.97 6000.00 34.53 34.39 0.15 308.33 309.33 -1.00 6100.00 34.73 34.69 0.04 309.05 310.16 -1.11 6200.00 34.84 34.66 0.18 310.33 311.39 -1.06 6300.00 34.39 34.40 -0.01 310.87 311.84 -0.97 6400.00 34.94 34.81 0.13 311.05 311.89 -0.85 6500.00 34.52 34.36 0.15 311.18 312.17 -0.99 6600.00 34.50 34.43 0.06 311.74 312.64 -0.90 6700.00 33.96 33.94 0.02 312.00 312.98 -0.98 6800.00 34.10 34.06 0.04 312.06 312.93 -0.88 6900.00 33.48 33.51 -0.03 311.48 312.36 -0.88 7000.00 33.18 33.39 -0.21 311.68 312.71 -1.03 7100.00 33.45 33.48 -0.03 312.29 313.03 -0.74 7200.00 32.83 32.87 -0.04 311.65 312.19 -0.54 7300.00 32.73 32.72 0.01 311.70 312.39 -0.69 7400.00 32.70 32.81 -0.11 311.32 312.02 -0.71 7500.00 32.08 32.02 0.06 311.33 312.08 -0.75 7600.00 31.41 31.44 -0.02 311.50 312.22 -0.73 7700.00 30.87 30.97 -0.09 312.36 313.16 -0.81 7800.00 29.96 30.12 -0.15 313.65 314.22 -0.57 7900.00 29.60 29.71 -0.11 314.46 315.12 -0.66 8000.00 28.47 28.53 -0.07 315.28 315.63 -0.34 8100.00 27.84 27.88 -0.04 315.88 316.81 -0.93 8200.00 27.24 27.15 0.08 315.92 316.56 -0.64 8300.00 26.64 26.62 0.02 315.86 316.98 -1.11 8400.00 25.97 25.82 0.16 316.28 317.11 -0.83 8500.00 24.98 25.14 -0.16 316.47 317.54 -1.07 SURV-Q167 (OPS SUR -MA -003) 191" NOV 03 / Rev 15 Page 5 of 6 AK0814GCM176 Survey QC - RGS-CT Specification Sheet � § tc: b� ta 8600.00 24.50 24.38 0.12 317.35 318.29 -0.94 8700.00 23.32 23.24 0.08 318.53 319.63 -1.10 8800.00 21.58 21.74 -0.16 321.86 322.89 -1.03 8900.00 20.65 20.80 -0.15 323.88 324.77 -0.89 9000.00 19.35 19.34 0.01 324.32 325.19 -0.86 9100.00 18.98 19.19 -0.22 326.43 326.79 -0.36 9200.00 18.48 18.61 -0.13 328.34 328.45 -0.11 9300.00 17.55 17.66 -0.11 330.03 329.79 0.24 9400.00 16.85 16.92 -0.07 330.76 331.23 -0.47 9500.00 17.03 16.94 0.09 331.13 331.57 -0.44 Average 0.0344 �' �� �� p� ' -0.7171 Standard Deviation 0.1953 0.3031 Tolerance for both the Average and the Standard Casing 0.30 Casing 0.50 Deviation Drill i e 0.30 Drill i e 0.750 * Inclination and Azimuth interpolated to same depths as shown. SURV-Q167 (OPS SUR -MA -003) 191" Nov 03 / Rev 15 Page 6 of 6 AK0814GCM176 Survey QC - RGS-CT Analysis Sheet 9W-- *0-3--t- SURVEY QUALITY CONTROL - DATA ANALYSIS RFFFRFNC_F SYSTFMS Grid System I I Grid Correction 0.00 Azimuth reference: Grid True North TRUE NORTH Vertical reference: RKB/MSL/Other I RKB I If other give details TIE ON DATA Depth 0.00 Inclination 0.00 Azimuth 0.00 TVD 0.00 Northings 0.00 Eastin s 0.00 Latitude 70.2338 Az. Ref: Grid/True True Grid Corrected Y N? N Description CALIBRATION Tool Number F0181 Calibration Date 1 30 Apr 2014 OPERATING TEMPERATURE Calibration range From 49.91 To 119.94 Gyro operating ran a From 67.26 To 86.79 Spec' -Within calibration ran e FIELD ROLL TEST(Only valid on Fixed structures. When not possible input roll test data performed after return to base Cal value I Pre job offset jPost job offset I Abs dif.cal.post Abs dif. re. ost Spec' Accel Scale 1 0.0000541 0.000045 1 0.000051 1 0.000051 0.000006 Cal Post - 0.00015 Mass Unbalance 1 3.93 1 0.14 1 0.32 1 0.32 10.19 1 Pre/Post- 0.4° hr INITIALISATION Depth A rox 3200.28 No of stns 1 6 Sec' - Min No. - 6 Azimuth Mean 305.45 Std deviation0.10 Std dev' Spec' - Azi SD 0.20 Inclination Mean 10.60 Std deviation 0.00 Spec' - Inc SD 0.10 Earth Horizontal Rate Mean Abs meas-theor 0.02 Std deviation 0.02 S c' - See 0167 F4 TOOLFACE RATE Maximum toolface rate 1 59.24 Spec' - 400° sec INfOUT COMPARISON (AZT' N/A IF INC' G15°l Inclination Difference Mean 0.03 Std dev' 0.20 Sec's - Casing0.3° Drill i 0.30 Azimuth Difference Mean -0.72 Std dev' 0.30 Sec's - Casing 0.5° Drill pipe 0.750 Lateral Divergence/1000 4.64 Sec - 5.0/1000 Vertical Divergence/1000 0.38 S c' - 2.0/1000 FPT3S i'r6T*W Y7 r767I Wireline Company Schlumber er Line type 0.23" Encoder SF Schlumberger Max Depth TD 9546 CCL Corrected N Zero Depth(Rig u RKB @ 61 ft AMSL Rezero Depth -3.2 Given pup joint depth NA Measured PI NA Strech cor. At TO divided by TD 1000 .4210 S ec- 1.5/1000 Dif. Between rigup and rezero depths divided by TD 1000 1 .3368 Sec' - 2.0/1000 Dif. Between given and meas depth divided by meas 1000 I NA S c' - 2.0/1 00 SURV-Q165 (OPS SUR -MA -010) 22n° San 2004 / Revision 20 Paye 1 of 1 AK0814GCM176 Survey QC - RGS-CT Acceptance Sheet -���- FIELD AND SURVEY INFORMATION Operator BPXA Field / Platform WELLHEAD Well Number PRUDHOE BAY UNIT - EOA DRILLSITE: 03 WELL: 03-01 Survey section From 0.00 ft. to 9546.00 ft. Date 03 Aug 2014 Gyrodata Job No AK0814GCM176 Gyrodata Surveyors Christopher Prince, Joshua Camacho Job Objective High Accuracy Gyro Survey SURVEY PERFORMANCE SURVEY ACCEPTED In Spec' QC Parameter Yes/No/NA Possible Actions Contact Duty Engineer to discuss options: Operational temperature within Yes 1. Recalibrate tool to higher temperature specification 2. Resurvey with backup tool 3. Resurvey 'Hot' section at higher speed Roll test data within specification Contact Duty Engineer to discuss options: Only valid on land/fixed installations Yes 1. Recalibrate tool and reprocess survey 2. Resurve with backup tool Continuous initialisation within Take new initialisation, after three failures: specification Yes 1. Contact Duty Engineer or, 2. Resurve with back up tool. Contact Duty Engineer to discuss options: Toolface rate within specification Yes Resurvey section from previous bias check Investigate and comment if effects are negligible Contact Duty Engineer to discuss options: Drift tunes within specification Yes 1. Reprocess with different software settings 2. Resurve with backup tool Inrun/Outrun comparison within Contact Duty Engineer to discuss options. specification Yes Resurvey is usually not required if either inrun or outrun meet all other QC parameters Depth control within specification Yes Contact Duty Engineer to discuss options. Action taken: Note: Provided satisfactory action has been taken, parameters out with specification will not necessarily fail a survey. SURVEY ACCEPTED Gyrodata Representative Client's Representative SURV-Q166 (OPS SUR -MA -003) 13'" Nov 03 / Revision 12 Page 1 of 1 AK08146CM176 Schtumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Weli Job # N0.5514 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Log Description Date BL Color CD 2-30A P-16 03-01 AWJI.00077 AYS4-00122 89RH-00024 MEMORY GLS - PRODUCTION PROFILE _ C X-FLOW CHECK/IBP/CEMENT DUMP - 03/06/10 03/08/10 04121/10 1 1 1 1 1 1 P2-22 U-03 03-37 BBUO-00007 88KA-00021 BBKA-00023 USIT ~ X-FLOW CHECK/P UG/C MENT ~ L/ ' L STATIC PRESSURE SURVEY . j 03/08/10 04!22/10 04/24/10 1 1 1 1 1 1 5-111 R-28 BSJN-00049 BCZ2-00009 INJECTION PROFILE - ~ PRODUCTION PROFILE - G 04/19/10 04/26/10 1 1 1 1 R-04 BCZ2-00010 PRODUCTION PROFILE - 04/27/10 1 1 13-23A S-O6 Z-31 17-22 14 BBSK-00016 BBKA-00026 63S0-00060 AWJI-OODBS INJECTION PROFILE INJECTION PROFILE ~ INJECTION PROFILE MEM PRODUCTION PROFILE ~" - pq/Y9/1D 04/30/10 04/27/10 04/28/10 1 1 1 1 1 1 1 1 -D7 AVYO-00068 PRODUCTION PROFILE - 04/26/10 1 1 04-29AL7 BBSK-00017 USIT 04/30/10 1 1 A•O6 BBKA-OODO6 RST - 02/09/10 / 1 A-28 AYTO-00037 RST 02/16/10 i 1 17-09A 10AKA0128 OH MWD/L D EDIT 02/11/10 2 1 17-09APB1 10AKA0128 OH MWD/LWD EDIT 02/07/10 2 1 DI FARE ec KNflWI FrlldG CCr `nDT ev mr_r.uu r_ wun nvr,,n.,,.,.. ...... ,....... ~.-... _-- BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Alaska Data 8 Consulting Services 2525 Gambell Street, SuOe 400 Anchorage, AK 99503-2839 os/o7n o °~''kA~'~LG~L7r/ t1 ~.1 ~_. f ._ ~tl ~Lr ~~~`t ~, ~~;~ 201(1 ;,~,-~ - l~ ,~~~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSI~ APR 2 ~ I~~ORT OF SUNDRY WELL OPERATIONS „~p_a~,,,,,,~ 1. Operations ~~~ Qn 1a$ P rf d ~j~,ell ^ Plug Perforations ^ Stimulate^ Other Q ?$q p(ug Set orme e : Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension^ y~~' t Change Approved Progra perat. Shutdown ^ Perforate ^ Re-enter Suspended Well^ / .L7~ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: Permit to Drill Number: Name: Development ^~ Exploratory 175-0750 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ API Number: Anchorage, AK 99519-6612 50-029-20187-00-00 8. Property Designation (Lease f~umber) : 9. Well Name and Number: ~ ADLO-028328 ~ PBU 03-01 10. Field/Pool(s): PRUDHOE BAY FIELD / RUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10030 feet Plugs (measured) 9549' 4/21/10 feet true vertical 9250.82 feet Junk (measured) UNKNOWN DEPTh feet Effective Depth measured 9620 feet Packer (measured) 8823 8972 true vertical 8859 feet (true vertical) 8103 8242 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 94# H-40 SURFACE - 80 SURFACE - 80 1530 520 Surface 2720 13-3/8" 72# MN-80 SURFACE - 2750 SURFACE - 2720 5380 2670 Intermediate Production 9987 9-5/8" 47# L-80 SURFACE - 9987 SURFACE - 9210 6870 4760 Liner 6957 7"26# L-80 1996 - 8953 1996 - 8224 7240 5410 Liner Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13CR80 SURFACE - 9150 SURFACE - 8410 Packers and SSSV (type, measured and true vertical depth) 7"X4-1 /2" BKR S-3 PKR 8823 8103 9-5/8"X5-1/2" TIW HBBP T PKR 8972 8242 12. Stimulation or cement squeeze summary: Intervals treated (measured): i ~~ r' w) ~~ 1 :_ 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: 146 77 9612 233 Subsequent to operation: 151 72 9285 247 14. Attachments: .Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre le Title Data Management Engineer Signature ~- Phone 564-4944 Date 4/26/2010 u Form 10-404 Revised 7/2009 ~~~~ cif R ~ ~ ~ ~~~~ ~~i..~ ` v' Subm t On'ginal Only / 03-01 175-075 ~C~C ATTAP~LJ IIACAIT • • Sw Name 03-01 Operation Date 4/18/77 PerF Operation Code ~ PER Meas Depth Top 9,671. Meas Depth Base 9,696. Tvd Depth Top 8,907.6 Tvd Depth Base 8,931.5 03-01 4118/77 PER 9,728. 9,742. 8,962.11 8,975.49 03-01 4/18/77 PER 9,788. 9,813. 9,019.48 9,043.39 03-01 11/5184 APF 9,481. 9,501. 8,725.97 8,745.09 03-01 11127/85 APF 9,404. 9,481. 8,652.35 8,725.97 03-01 11/27/85 APF 9,525. 9,561. 8,768.03 8,802.44 03-01 11/5/87 APF 9,572. 9,608. 8,812.95 8,847.37 03-01 11/5/87 APF 9,622. 9,658. 8,860.75 8,895.17 03-01 3/17/91 RPF 9,572. 9,608. 8,812.95 8,847.37 03-01 4/21/92 SQZ 9,404. 9,813. 8,652.35 9,043.39 03-01 5/4/92 APF 9,522. 9,525. 8,765.16 8,768.03 03-01 5/4/92 APF 9,571. 9,572. 8,812. 8,812.95 03-01 5/4/92 RPF 9,480. 9,494. 8,725.01 8,738.39 03-01 5/4/92 RPF 9,525. 9,536. 8,768.03 8,778.54 03-01 5/4/92 RPF 9,572. 9,592. 8,812.95 8,832.07 03-01 1/30/94 RPF 9,571. 9,579. 8,812. 8,819.65 03-01 3/27/94 RPF 9,424. 9,480. 8,671.47 8,725.01 03-01 6/22/02 SPS 9,551. 9,620. 8,792.88 8,858.84 03-01 4/20/10 BPS 9,559. 9,579. 8,800.53 8,819.65 03-01 4/21/10 SPS 9,549. 9,559. 8,790.97 8,800.53 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS / SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • • 03-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 4/16/2010:;*"*WELL FLOWING ON ARRIVAL*""(profile mod) i j DRIFT W/ 2'x 1 7/8" STEM, 3.50" CENT, TEL, S. BAILER. (empty) TO 8883' s SLM ADRIFT W/ 2'x 1 7/8" STEM, 3.25" CENT, TEL, S. BAILER. ~LOC TT @ 9124' SLM = (+ 28' CORRECTION TO 9152' ELM), TAG HARD BOTTOM @ 9558' SLM / 9586' ELM (corrected), 6' OF FILL ABOVE BOTTOM OPEN PERF. ***WSR CONT ON 4/17/10""" ~ 4/17/2010~"""WSR CONT FROM 4/16/10*** (profile mod) `RIG DOWN SWCP 9 ~**'`WELL LEFT FLOWING ON DEPARTURE**'"* 4/19/2010 """"WELL SHUT-IN ON ARRIVAL*"**(E-LINE XFLOW/IBP/CEMENT DUMP BAILER) INITIAL T/I/O = 1500/1500/0 PSI BRIG UP E-LINE ~RIH WITH PL TOOLSTRING TO PERFORM XFLOW LOG ~****CONTINUED ON 20-APR-2010 WSR**** __. _ _ _W~_..._ __---~ ___ 4/20/2010~'~"""LOG CONTINUED FROM 19-APR-2010"***(E LINE XFLOW/IBP/CEMENT DUMP BAILER) LOG PL TOOLS TO CHECK FOR CROSS-FLOW. NO CROSS-FLOW .OBSERVED. `SET BAKER 3" IBP MID ELEMENT (a 9566', FISHING NECK 1.375" EXTERNAL, 3680# DOWN TO EQUALIZE, 5520# PULL TO RELEASE. OAL 11.04' WITH TWO 6" SEALS AND ONE 1"STIFFENER RING, TOP OF ;FISHING NECK LOCATED 9559'. **'`*CONTINUED ON_ 21-APR-2010 WSR""*" _ 4/21/2010*"**LOG CONTINUED FROM 20-APR-2010*'""*(E-LINE XFLOW/IBP/CEMENT FDUMP BAILER) 'FINISH DUMPING CEMENT ON TOP OF IBP. TOTAL CEMENT DUMPED = ~ 10.4' 'FINAL T/I/O = 1600/1500/0 PSI FINAL VALVE POSITIONS: WING, SWAB CLOSED. MASTER, SSV, VALVES ~TO GAUGES OPEN. **''*JOB COMPLETE**** FLUIDS PUMPED BBLS 2 diesel 14 meth 16 Total TREE = 7" CM/ WELLHEAD= FMC ACTUATOR = AXELSON KB. ELEV = 61' BF. ELEV = KOP= ? Max Angle = 35 @ 6400' Datum MD = 9622' Datum TV D = 8800' SS ~9-5/8" CSG, 47#, L-80, BTGM, ID = 8.681" ~- 13-3/8" CSG, 72#, MN-80, ID = 12.347" SA ES: *** 4-112" CHROME TBG*** ~ 03-01 1941' - -~ 5-112" X 4-1/2" XO, ID = 3.958" 1996' 9-5/8" x 7" BKR G2 ZXP LTP w / FLEXLOCK LNR HGR, ID = 6.270" 207 4-1/2" HES X NIP, ID = 3.813" 2142' -~ 9-5/8" HES ES CEMENTER t~A S LIFT MA NDRFL S ST MD TVD DEV TYPE VLV LATCH PORT DATE 6 3401 3392 16 KGB2 DOME BK 16 04!20107 5 4978 4815 30 KGB2 SO BK 20 04/20/07 4 5797 5508 34 KGB2 DMY BK 0 03/27/07 3 6663 6224 34 KGB2 DMY BK 0 03/27/07 2 7488 6917 31 KGB2 DMY BK 0 03/27/07 1 8734 8020 23 KGB2 DMY BK 0 03/27/07 Minimum ID = 3.725" @ 9128' HES XN NIPPLE L4-112" TBG, 12.6#, 13CR-$0, (-1 8911, VAM TOP, .0152 bpf, ID = 3.958" 7" LNR, 26#, L-80, BTGM, .0383 bpf, ID = 6.276" 8913' 4-1/2" TBG, 12.6#, L-80, 8953' IBT-M, .0152 bpf, ID = 3.958" 4-112" TBG, 12.6#, 13-CR-80, I 9150' NSCC/NSCT, .0152 bpf, ID = 3.958" PERFORATION SUMMARY REF LOG: BRCS ON 03/13/76 ANGLE AT TOP PERF: 17 @ 9404 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE SEE PAGE 2 FOR PERFORATIONS 9-5/8" CSG, 47#, L-80, ID = 8.681" 9987' 0 10030' DATE REV BY COMMENTS DATE REV BY COMMENTS 04110!76 ORIGINAL COMPLETION 02126/96 RWO 03!30(07 N4ES RWO 04!20!07 KSB/TLH GLV C/O 04129!07 FRlPJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 03-01 PERMIT No: 1750750 API No: 50-029-20187-00 SEC 10 T10N R15E 1578.57 FEL 1129.48 FNL BP Exploration (Alaska) $802' -~ 4-112" HES X NIP, ID = 3.813" 8823' 7" X 4-1/2" BKR S-3 PKR, ID = 3.875" $$47' 4-1/2" HES X NIP, ID = 3.813" $911' -~4-1/2" WLEG, ID = 3.95$"1 $913' 7" X 4-112" PORTED XO, ID = 3.958" 8944' 4-1/2" TBG STUB 1 8953' 9-518"X4-1/2"UNIQUEOVERSHOT 8970' 4-112" X 5-1i2" XO, iD = 3.92" $972' 9-518" X 5-1/2" TNV HBBP-T PKR, ID = 4.875" 8977' 5-112" X 4-1/2" XO, ID = 3.958" 912$' 4-1 /2" HES XN NIP, ID = 3.725"~ 9150' - 4-1(2" WLEG, ID = 3.958" 9152' ELMD TT LOG (XX/XX/XX}? I ???? FISH- 4-1/2" LOCK KEY (7/20/05) ???? FISH - 13.06' LONG IBP (06!01!02) 9620' CMTPLUG(SET04/21/92) ~ 03-01 ~ PERFORATION SUMMARY REF LOG: BHCS ON 03!13/76 A NGLE AT TOP PERF: 17 @ 9404 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9404 - 9424 S 04/21/92 3-3/8" 4 9424 - 9494 O 03/27/94 4 9494 - 9501 S 04/21/92 3-3/8" 4 9522 - 9536 O 05/04/92 4 9536 - 9561 S 04/21/92 3-3/8" 4 9571 - 9592 O 05/04/92 4 9592 - 9608 S 04/21/92 4 9622 - 9658 S 04/21/92 4 9671 - 9696 S 04/21/92 4 9728 - 9742 S 04/21/92 4 9788 - 9813 S 04!21192 DATE REV BY COMMENTS DATE REV BY COMMENTS 04!10/76 ORIGINAL COMP~EfION 02!26196 RWO 03/30!07 N4ES RWO 04120/07 KSBiTLH GLV GO 04/29(07 FRIPJC DRLG DRAFT CORRECTIONS PRUDHOE BAY UNIT WELL: 03-01 PERMIT No: 1750750 API No: 50-029-20187-00 SEC 10 T1 ON R15E 1578.57 FEL 1129.48 FNL BP 6cploration (Alaska) t ail Schlumberger ��� NO. 5436 Alaska Data & Consulting v' i } t ` 9 Services � - Company: State of Alaska 2525 Gambell Street, suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD • MPC -04 AXBD -00061 MEMORK•GLS '3 11/17/09 1 1 NK -38A AWJI -00057 MEM PROD PROFILE L 11/04/09 1 1 14 -12 133SO -00033 PRODUCTION PROFILE 11/13/09 1 1 13 -35 8148 -00084 INJECTION PROFILE V 11/10/09 1 1 06 -08A B14B -00082 PLUGBACK SET W /X -FLOW CHECK - 11/08/09 1 1 H -30 AV1H -00031 PRODUCTION PROFILE 11/14/09 1 1 18 -11 A B2NJ -00038 MEM CNL & SCMT G 111/06/09 1 1 Y -23B AYKP -00055 GLS - 14 G j 11/22/09 1 1 N -24 AYS4 -00109 PRODUCTION PROFILE - 11/08/09 1 1 02 -31A AYKP -00053 PRODUCTION PROFILE 11/15/09 1 1 03 -01 B81(5.00014 PRODUCTION PROFILE 00 q 11/24/09 1 1 L -213 B581 -00017 INJ PROFILE W/WFL 11/19/09 1 1 W -209 AYKP -00054 INJ PROFILE W/WFL - T 2 11/17/09 1 1 X -05 AP30 -00072 PRODUCTION PROFILE 11/29/09 1 1 X -07 AYS4 -00111 PRODUCTION PROFILE Q - I!E 11/27/09 1 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petiotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E Benson Blvd. Anchorage, AK 99503 -2838 Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth 05115107 NO. 4024 . <- / 7 c c""· --:-z '. . J -' } '7,j sCANNED MAY 1 7 2007 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite! 100 Anchorage, AK 99501 Field: Prudhoe Bay . Well Job' Loa DescriDtion Date BL Color CD L3-22 11638627 PRODUCTION PROFILE 04/14/07 1 L3-30 11637115 PRODUCTION PROFILE 03/19/07 1 L4-10 11660529 MEM PROD PROFILE 04/04/07 1 L3-12 11686732 PRODUCTION PROFILE 04/08/07 1 02-29C N/A EMIT & CALIPER IMAGE 04/17/07 1 DS 02-36 11637141 MULTI-FINGER CALlPE 03/14/07 1 F-16A NIA SCMT 02/12/07 1 X-21A 11660531 MEM CBL 04/07/07 1 F-08A 11676934 SCMT 03/20107 1 A-30A 11628762 MEM CBL 03/13/07 1 03-36A 11637326 USIT (CORROSION) 04/12/07 1 03-36A 11637326 USIT (CEMENT) 04/12/07 1 DS 17-05 11594492 USIT 04/24/07 1 DS 03-01 11630462 USIT 03/11/07 1 . PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) tnc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: t1í\)' J\. 6 l.u01 (~) Alaska Data & Consulting Services 2525 Gambell Street, Suite 4 0 Anchorage, AK 99503-2 38 ATTN: Beth Received by: STATE OF ALASKA ~ ~--/?-d¡' - -- - -- - -- A~KA OIL AND GAS CONSERVATION COMMISSION APR 1 3 2007 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & Gas Cons. Convnission Anc~rago feet feet Plugs (measured) 9620 feet Junk (measured) Yes, Unknown feet Size MD TVD Burst Collapse 20" 80' 80' 1530 520 13-3/8" 2720' 2720' 5380 2670 9-5/8" 9987' 9210' 6870 4760 7" 1996' - 8953' 7240 5410 iGMNED APR 1 8 2007 ;. 1. Operations Performed: o Abandon o Alter Casing o Change Approved Program 181 Repair Well 181 Pull Tubing o Operation Shutdown 2. Operator Name: BP Exploration (Alaska) Inc. 3. Address: P.O. Box 196612, Anchorage, Alaska 7. KB Elevation (ft): 99519-6612 61' / 8. Property Designation: ADL 028328 / 11. Present well condition summary Total depth: measured Effective depth: true vertical measured true vertical Length 10030 I 9251 I 9620 8859 Casing Structural Conductor Surface Intermediate Production Liner Scab Liner 80' 2720' 9987' Perforation Depth MD (ft): Perforation Depth TVD (ft): 9424' - 9592' 8671' - 8832' o Re-Enter Suspended Well o Other o Plug Perforations 0 Stimulate o Perforate New Pool 0 Waiver o Perforate 0 Time Extension 4. Well Class Before Work: 5. Permit To Drill Number: 181 Development 0 Exploratory 175-075 - o Stratigraphic 0 Service 6. API Number: 50-029-20187 -00-00 ,r 9. Well Name and Number: PBU 03-01 .-- 10. Field / Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool .-- 5-1/2", 17# x 4-1/2", 12.6# & Tubing Size (size, grade, and measured depth): 4-1/2", 12.6# 7" x 4-1/2" Baker 'S-3' Packer Packers and SSSV (type and measured depth): 9-5/8" x 5-112" TIW 'HBBP-T' packer 12. Stimulation or cement squeeze summary: Intervals treated (measured): 13Cr80 To 8911' & 8944' - 9150' 8823' 8972' Treatment description including volumes used and final pressure: Cut and pull tubing f/8944'. Cut and pull 9-5/8" casing f/2167'. Run 9-5/8",47#, L-80 tieback to 2167'. Cement w/145 Bbls Class 'G' (814 cu ft /702 sx). Identify leaking interval in 9-5/8". Cement wI 22 Bbls SqueezeCrete (124 cu ft /119 sx). Run 7", 26#, L-80 Liner from 1996' - 8953'. Cement wI 194 Bbls Class 'G' (1089 cu ft /939 sx). Run new Chrome completion. 13. Oil-Bbl Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14. Attachments: 0 Copies of Logs and Surveys run 15. Well Class after proposed work: o Exploratory 181 Development 0 Service 181 Daily Report of Well Operations 16. Well Status after proposed work: o Well Schematic Diagram 181 Oil 0 Gas 0 WAG 0 GINJ 0 WINJ 0 WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact David Reem, 564-5743 307-054 Printed Name Terrie Hubble Signature~0Vù t. ~ 1 ~ Form 10-404 Revised 04/2006 0 RIG , N A I Title Technical Assistant Phone 564-4628 Date (J- II:!:! D 7 fBIISIrL APR 1 8 2007 1_.. IGr'1t \~ Prepared By Name/Number: Terrie Hubble, 564-4628 Submit Original Only ~. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/6/2007 13:00 - 18:00 5.00 RIGD P PRE Maintain Rig while Well Support finishes removing the Well house and Flowline off of 03-01. 18:00 - 22:00 4.00 MOB P PRE Pre-tour safety meeting. Continue servicing the Rig while the pad is prepped and built up with gravel. Met with DSO and he inspected the Tree with the WSL and Driller - OK. 22:00 - 00:00 2.00 MOB P PRE Lower and scope Derrick. Disconnect modules and back off of well slot 03-02. 3/7/2007 00:00 - 02:00 2.00 RIGD P PRE Continue backing out of well slot 03-02. Continue site prep on 03-01. 02:00 - 04:00 2.00 MOB P PRE Move Pits, Pipe Shed and Sub modules from 03-02 to 03-01. 04:00 - 06:00 2.00 RIGU P PRE Position the Sub over well slot 03-01. 06:00 - 08:00 2.00 RIGU P PRE Raise derrick and prep floor and cellar for e-line work. Accept rig @ 0800-hrs. 08:00 - 10:00 2.00 WHSUR P DECOMP Wait on Valve Shop to arive to pull BPV. 10:00 - 11 :00 1.00 WHSUR P DECOMP PJSM. PU lubricator. Pull BPV. UD lubricator. 11 :00 - 14:00 3.00 DHB P DECOMP Wait for SWS E-line to arrive on wellpad. 14:00 - 18:00 4.00 DHB P DECOMP PJSM all crew - Rig up E-Line equipment. Rigging up E-line equipment for full pressure control and to RIH w/Baker composite bridge plug. Pressure test Lubricator to 3,000 psi - OK. 18:00 - 20:00 2.00 DHB P DECOMP RIH with Composite Bridge Plug on E-line. 20:00 - 20:30 0.50 DHB P DECOMP Tie-in to the existing Tubing Tally at the Packer Assembly. Set the Baker Composite Plug at a depth of 9,025' center of element. The CCL to COE was 13.8', stopped the cable at 9,011.2'. Upon set, we lost 100 Ibs in tension. 20:30 - 21 :30 1.00 DHB P DECOMP POOH with E-line. 21 :30 - 22:00 0.50 DHB P DECOMP Stop 200' from surface to MIT the Tubing against the Plug. Attempt to test with Rig diesel but the Tubing is on a vac and not sure where the fluid level is. Call out Little Red to assist with the MIT-T. 22:00 - 00:00 2.00 DHB P DECOMP Wait on Litlle Red to arrive on location. 3/8/2007 00:00 - 02:00 2.00 DHB P DECOMP Little Red arrives on location. PJSM. RU Little Red to the Pump In Sub on the Lubricator. Pre-heat the diesel to 60 degrees for lead in. 02:00 - 03:00 1.00 DHB P DECOMP Begin filling up the Tubing with diesel at a rate of 1 bpm / 200 psi. Pressure test the Tubing to 1,000 psi for 10 mins, charted against the Composite Plug @ 9,025' - OK. It took 32.4 bbls to fill the Tubing (- 850' down). 03:00 - 04:00 1.00 DHB P DECOMP Bleed the diesel off of the Lubricator to a bleed trailer. RD Little Red. PJSM with Schlumberger E-line on the Jet Cutter and associated hazards. 04:00 - 05:30 1.50 DHB P DECOMP Make up Jet Cutter Assembly with E-line. RIH with Jet Cutter Assembly on E-line. 05:30 - 06:00 0.50 DHB P DECOMP On bottom across Packer Assembly. Tie-into previous Plug setting pass. Jet cut the Tubing at a depth of 8,942'. eCL to cutter = 14.4', stop depth = 8,927.6'. Good indication of cut seen on surface. Increase in tension was noted due to U-tube of fluid from the Tubing into the IA. 06:00 - 07:00 1.00 DHB P DECOMP POOH with Jet Cutter Assembly on E-line. 07:00 - 08:30 1.50 DHB P DECOMP Rig down E-line equipment. 08:30 - 11 :00 2.50 KILL P DECOMP Pre-tour. Rig up circulating lines to tree cap and IA. 11 :00 - 15:30 4.50 KILL P DECOMP Circulate well @ 3-4-BPM @ 250120-PSI taking returns to Tiger Tank. Monitored and bled OA as needed holding Printed: 41212007 11: 11 :22 AM '--'" ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/812007 11 :00 - 15:30 4.50 KILL P DECOMP pressure to no higher than 300-PSI. Shut in well and monitor for 30-minutes. TIIIO = 010/250. 15:30 - 16:30 1.00 KILL P DECOMP Slow down lines and rig down circulating equipment. Peak vac truck driver created 15-gallon seawater spill to gravel pad. AOGCC - Lou Grimaldi waived witness BOPE test. 16:30 - 18:00 1.50 WHSUR P DECOMP Set TWC. Perform CMIT x IA x OA and test TWC from below to 2000-PSI for 10 charted minutes. PIT TWC from above to 1000-PSI for 10 charted minutes. 18:00 - 22:00 4.00 WHSUR P DECOMP N/D Tree and Adapter Flange. Screw on Hanger XO to ensure the threads are good - OK. Hanger threads are 9" Acme LH , 6 3/4 turns. Capped the Control Lines with FMC rep. Functioned LDS - OK. (1) LDS was backed out completely due to being broken. 22:00 - 00:00 2.00 BOPSUP P DECOMP PJSM. NU 135/8" SOPE and Test Spool. 3/9/2007 00:00 - 03:30 3.50 BOPSUF P DECOMP Continue NU BOPE. 03:30 - 10:30 7.00 BOPSUF P DECOMP Pressure test BOPE per BP I AOGCC Regulations to 250/ 3,500 psi. The state's right to witness the test was waived by Lou Grimaldi on 3/8/2007. The test was witnessed by the WSL,Toolpusher and Driller. Valve #12 failed and grease did not help it. Had to take it apart and repair it. Resume testing BOPE. 10:30 - 11 :00 0.50 BOPSUF P DECOMP Rig down BOPE test equipment. 11 :00 - 12:00 1.00 PULL P DECOMP Rig up floor with handling tools to pull 7" x 5-1/2" X 4-1/2" completion. PUMU landing joint to 7" L.H.Acme XO for top hanger threads. 12:00 - 13:00 1.00 PULL P DECOMP Engage tubing hanger with landing joint. BOLDS. Hoist Tubing Hanger to rig floor. Up wt. to unland Tubing Hanger = 180K. PUW to hoist Tubing Hanger to floor = 140K. 13:00 - 13:30 0.50 PULL P DECOMP Break out and lay down Tubing Hanger and 1 st joint of 7" Tubing. 13:30 - 14:15 0.75 PULL P DECOMP PJSM - POH UD Tubing. Standdown and review "control of work" process expectations and reviewed 15 gallon seawater spill on 3/8/07. 14:15 - 17:30 3.25 PULL P DECOMP POH UD 7" x 5-1/2" X 4-1/2" completion Tubing through pipe shed 1 x 1. 48 jts. OOH @ 17:30-hrs. Filling hole continuously pumping across the top with charge pump. Fluid losses = O-Bbls. 17:30 - 23:00 5.50 PULL P DECOMP Continue POH with existing Completion Tubing laying down in the Pipe Shed 1 x 1. Recovered all Stainless Steel Control Line and all 57 Bands. 23:00 - 00:00 1.00 PULL P DECOMP Stop POOH to hold HSE safety discussion on "Control of Work" standard. Also discussed and reviewed the 15 gallon seawater spill that occured on 3/8/07. 3/10/2007 00:00 - 03:30 3.50 PULL P DECOMP Continue POH with existing 4 1/2" Tubing Completion. Set aside Joints #22 and #69 along with GLM #2 and #5 for further inspection in Anchorage. 03:30 - 04:30 1.00 PULL P DECOMP On surface with the cut 4 1/2" Joint. The cut Joint length = 17.64'. The Jet cut was slightly flared and pretty clean overall. Recovered a total of (76) Jts of 7" , (1) Jt of 5 1/2" and (143) Jts of 4 1/2". RD Tubing Handling Equipment. PU and set 8 15/16" ID Wear Ring. 04:30 - 05:30 1.00 PULL P DECOMP Clear and clean Rig Floor. 05:30 - 06:00 0.50 CLEAN P DECOMP RU 3 1/2" DP Handling Equipment and Pipe Spinners. Printed: 4/2/2007 11 :11 :22 AM ~J Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 Dåte From -To 3/10/2007 06:00 - 09:00 3.00 CLEAN P DECOMP PUMU BHA #1 - 4-1/2" dress off mill, 8-1/8" mill shoe, 8-1/8" boot basket, 9-5/8" scraper, 6-1/4" LBS, 6-1/4" jars & 9 x 6-14" drill collars. 09:00 - 19:30 10.50 CLEAN P DECOMP RIH w/BHA #1 on 3-1/2" DP 1 x 1 from pipe shed. 30 jts. RIH @ 11 :OO-hrs. 165 jts. RIH @ 16:00-hrs. Tagged 4-1/2" tubing stump @ 8944' DPM. 19:30 - 22:00 2.50 CLEAN P DECOMP LD DP pup joint, PU one joint DP. Established dress off parameters - 155k Ib PU, 130k Ib SO, 142k Ib rot, 65 spm, 600 psi, 150 amps. Dressed 4-1/2" tubing stump to 8954' DPM (swallowed 10' of stump). Made five passes over stump while rotating before dress-off shoe passed freely over stump without rotating. 22:00 - 00:00 2.00 CLEAN P DECOMP Attempted to reverse circulate while over tubing stump. Could not reverse - 1000 psi, <2 bpm (Fasdril plug @ 9025' tested to 1000 psi.) Lined up to pump long way. PU off tubing stump. Circ long way 5 bpm @ 1000 psi, 6 bpm @ 1600 psi. 3/11/2007 00:00 - 00:30 0.50 CLEAN P DECOMP Continue circ long way @ 6 bpm. Pumped 15 bbl High-Vis sweep, had minimal metal in returns. 00:30 - 04:00 3.50 CLEAN P DECOMP POH, standing back 3-1/2" DP. 50 stnds OOH @ 0400 hrs. Change to Dayllight Saving Time leaves 23-hour day. 04:00 - 06:00 2.00 CLEAN P DECOMP Slip and cut drill line. Pre-tour meeting - day crew. 06:00 - 08:00 2.00 CLEAN P DECOMP POH, standing back 3-1/2" DP & 6-1/4" DC's in derrick. 08:00 - 09:00 1.00 CLEAN P DECOMP BOLD BHA #1 . 09:00 - 10:00 1.00 CLEAN P DECOMP Clear & clean rig floor. 10:00 - 11 :00 1.00 EVAL P TIEB1 PJSM - N/D flow nipple and air boots. N/U shooting flange 11 :00 - 11 :30 0.50 EV AL P TIEB1 PJSM - Rigging up and running wireline: All rig crew and SWS crew. 11 :30 - 13:30 2.00 EVAL P TIEB1 Rig up E-Line equipment w/lubricator and packoff. PIT packoff to 200-PSI. Ambient temp. = -40F. 13:30 - 14:30 1.00 EVAL P TIEB1 RIH w/USIT logging tool string to 8930'. 14:30 - 23:00 8.50 EVAL P TIEB1 USIT log in cement/corrosion mode from 8930' to surface. Made high resolution pass from 3100' to 2000'. Transmitted log data to Frank Roach. Determined TOC approx. 2200', string shot depth @ 2155' and 9-5/8" casing cut depth @ 2135', referenced to the USIT dated 03/11/2007, 1922 hrs. 23:00 - 00:00 1.00 FISH P TIEB1 RIH with 4-strand string shot on E-line. Positioned shot @ 2149' - 2161' and detonated. POH, RD E-line. 3/12/2007 00:00 - 01 :30 1.50 FISH TIEB1 Continue RD E-line service. 01 :30 - 05:30 4.00 FISH TIEB1 PUMU RBP on 3-1/2" DP. RIH on 3-1/2" DP to set at 3000'. 05:30 - 06:00 0.50 FISH TIEB1 Set and release from RBP. Center of packer element @ 3000' DPM. Top of fishing neck @ 2995' Tested RBP to 1000 psi for 10 charted minutes. 06:00 - 09:30 3.50 FISH TIEB1 Pull and stand back 1-stand DP. Dump and flush 2,200# 20-40 river sand down DP. Pump DP volume - 20-Bbls. - down DP to flush sand out of DP. Let sand fall out for 30 minutes. Tag top of sand @ 2,943'. POH UD 1-joint DP. 09:30 - 11 :30 2.00 FISH TIEB1 Circulate 311-Bbls. 120F seawater to empty pits @ 4-5 BPM from taking returns to Tiger Tank. Circulate and swap hole over to 9.8-ppg NaCI brine. 11 :30 - 13:00 1.50 FISH TIEB1 POH UD RBP setting tool. 13:00 - 14:00 1.00 FISH TIEB1 PUMU BHA #2: 8-1/2" Mullti-String casing cutter and RIH on DP. 14:00 - 15:30 1.50 FISH TIEB1 RIH w/BHA #2 Printed: 4/2/2007 11: 11 :22 AM '-'"' ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/12/2007 15:30 - 17:00 1.50 FISH TIEB1 Locate casing collar @ 2168' and @ 2122' w/Multi-String cutter blades. 17:00 - 19:00 2.00 FISH TIEB1 Pick up 20' off of collar @ 2168' and cut casing. 19:00 - 00:00 5.00 FISH TIEB1 Established circulation through casing cut and up 13-3/8" x 9-518" annulus @ 2-1/2 bpm, 700 psi. Held PJSM. RU to take OA returns to open-top tank, and to take IA returns to rig pit. RU LRS. Circ 120 deg 9.8 ppg brine through IA. Spotted 160 deg diesel to casing cutter. Closed annular, opened OA to open-top tank and placed 100 bbls hot diesel into OA. Hot diesel pumped @ 1 bpm, 1100 psi. Allowed hot diesel to soak while intermittently moving diesel through OA. 3/13/2007 00:00 - 05:00 5.00 FISH P TIEB1 Continued moving hot diesel through OA at rate of 4-5 bbls every 15-20 minutes. Flushed hot diesel from OA with hot 9.8 ppg brine @ 5 bpm, 1800 psi. Estimate 100 bbls diesel in returns, and no Arctic Pack. RD LRS. 05:00 - 06:00 1.00 FISH P TIEB1 POH w/BHA #2. 06:00 " 06:45 0.75 FISH P TIEB1 BO/LD BHA #2. 06:45 - 07:15 0.50 FISH P TIEB1 Clear and clean rig floor. 07:15 - 08:15 1.00 FISH P TIEB1 PJSM - Pull 9-5/8" casing packoff. Spear and unland 9-5/8" casing. 08: 15 - 09:30 1.25 FISH P TIEB1 PUMU casing packoff pulling tool. BOLDS. Pull 9-5/8" casing packoff. PUW to unseat casing packoff - 26K#. POH UD casing packoff. UD casing packoff pulling tool. 09:30 - 11 :00 1.50 FISH P TIEB1 PUMU BHA #3 - 8-1/2" ITCO spear. Engage 9-5/8" casing at surface. Unland 9-5/8" casing with PUW = 100K#. 11 :00 - 12:00 1.00 FISH P TIEB1 Break tubing spool by casing head flange connection. Raise BOPE/tubing spool and remove casing slips. 12:00 - 13:00 1.00 FISH P TIEB1 Set BOPE/tubing spool on casing flange and bolt flanged connection up and torque same. 13:00 - 14:30 1.50 FISH P TIEB1 Rig up floor with casing handling equipment and tools. 14:30 - 15:00 0.50 FISH P TIEB1 Hoist spear and top joint casing to rig floor. BO/LD spear and top cut joint of 9-5/8" casing. Top cut joint = 32'. No sign of arctic pac. 15:00 - 19:00 4.00 FISH P TIEB1 POH UD 9-5/8" casing 1 x 1 through pipe shed. Did not use thread protectors. Recovered 48 full jts, top Cut off 31.26' & bottom cut jt 25.33'. Did not recover any centralizers. Pipe condition good. No sign of arctic pac throughout. 19:00 - 20:00 1.00 FISH P TIEB1 Clear & clean rig floor. RID casing tools. 20:00 - 21 :00 1.00 FISH P TIEB1 P/U spear. Break out bull nose & X/Os from spear. UD same. 21 :00 - 23:00 2.00 FISH P TIEB1 P/U & M/U BHA #4 as follows: 81/2" Bit, Bit Sub, 10 * 6 1/4" DCs, XO, 133/8" Casing scraper, Bit Sub, Bumper Sub, Jars, XO, XO. TL = 337.43'. 23:00 - 00:00 1.00 FISH P TIEB1 RIH w/ BHA #4 on 19 stands of 31/2" DP. Tagged 3' in on 20th stand. Top of stub @ 2145'. 3/14/2007 00:00 - 01 :00 1.00 FISH P TIEB1 Attempt to enter stub, could not enter wlo rotation. UD single, P/U 23' DP pup & kelly. Rotate & work thru casing stub. No torq. Work up & down several times. Still unable to go into stub wlo rotation. Con't in hole wI 3 stands + 1 single. Bottom out wI scraper on csg stub & bit @ 2639' P/U, S/O Rot Wts = 67K. Free torq & Rot torq =1900 ft-Ibs. 01 :00 - 02:30 1.50 FISH P TIEB1 Circulate bottoms up. Pumped 5 BPM @ 320 psi. Had small amt of arctic Pack & some bubbles to surface. Pumped 365 bbls. Monitor well. Set back kelly & blow down lines. Printed: 4/2/2007 11 :11 :22 AM ..-" '-' Legal Well Name: 03-01 Common Well Name: 03-01 Spud Date: 2/21/1976 Event Name: WORKOVER Start: 3/6/2007 End: 3/27/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/27/2007 Rig Name: NABORS 4ES Rig Number: Date 3/14/2007 02:30 - 03:30 1.00 FISH P TIEB1 UD 24' DP pup. POOH & stand back 24 stands of 3 1/2"DP. 03:30 - 05:30 2.00 FISH P TIEB1 Break out & UD BHA #4. Clear & clean rig floor. 05:30 - 06:30 1.00 FISH P TIEB1 P/U & M/U BHA #5 as follows: WP Shoe, 1 jt WP, Boot Basket, XO, XO, Float Sub wlfloat, XO, Bumper Sub, Jars, XO, 9 * 6 1/4" DCs, XO, XO. TL = 339.47'. 06:30 - 09:00 2.50 FISH P TIEB1 RIH w/BHA #5. Washover 9-5/8" casing stub down past collar to be backed off @ xxxx'. 09:00 - 11 :00 2.00 FISH P TIEB1 Tag 9-5/8" casing stub @ 2148'. Obtain milling parameters- 65K PUW, 65K SOW, 5.0-BPM @ 300-PSI. 80-RPM, Free torque = 90-AMPS. Rotate down over top of stub. SID rotation and RIH to casing collar @ 2168'. Could not get over casing collar with mill shoe while circulating. SID pump and ease over collar. Resume circulating @ 5.0-BPM @ 300-PSI and wash down to 2172' encountering no resistance. Pump 30-Bbl hi-vis sweep and CBU. 11 :00 - 11 :30 0.50 FISH P TIEB1 Set kelly back. Blow down lines. Prep to POH. 11 :30 - 12:30 1.00 FISH P TIEB1 POH w/BHA #5. 12:30 - 14:30 2.00 FISH P TIEB1 BOLD BHA #5. Clear and clean rig floor. 14:30 - 15:30 1.00 FISH P TIEB1 PUMU BHA #6 as follows: Bullnose, XO, 9 x 6-1/4" DC's, XO, XO, lower anchor, backoff tool, upper anchor, XO, pump out sub, XO, XO. 15:30 - 17:30 2.00 FISH P TIEB1 RIH w/BHA #6. Filling DP every stand while RIH. 17:30 - 18:30 1.00 FISH P TIEB1 Space out Back off tools. Set L. Anchor @ 2186' wI 1200 psi, Set U. Anchor @ 2158' w/ 2500 psi. Cycle Back Off tool 10 times. Got 6 full rounds of UH rotation. Connection broke @ 1400 psi, final cycle pressure 800 psi. Released anchors. Break off circulating head. 18:30 - 19:00 0.50 FISH P TIEB1 Drop dart & open Pump out sub. Dsplace fresh water in DP wI 15 bbls of 9.8 brine. Pump 3 BPM @ 410 psi. 19:00 - 20:00 1.00 FISH P TIEB1 P/U 1 jt of DP. POOH & stand back 31/2" DP. 20:00 - 22:00 2.00 FISH P TIEB1 Break out & UD BHA # 6. Set back DCs. Clear & clean rig floor. 22:00 - 22:30 0.50 FISH P TIEB1 P/U & M/U BHA #7 as follows: Bull Nose, Spear Pack Off, ITCO Spear, Spear Ext, Stop Sub, Bumper Sub, Jars, XO, XO. TL = 36.23'. 22:30 - 23:30 1.00 FISH P TIEB1 RIH wI BHA #7 on 22 stands of 31/2" DP. 23:30 - 00:00 0.50 FISH P TIEB1 P/U kelly. RIH & engage spear into csg stub @ 2148'. Swallow 11' to 2159'. P/U wI 25K over & insure set. S/O & P/U 2K over. Slowly rotate & put 6 left rounds in string. Cut off jt came free. P/U Wt, SIO Wt, & Rot WT = 46k. v 3/15/2007 00:00 - 01 :30 1.50 FISH P TIEB1 POOH & stand back 31/2" DP. 01 :30 - 02:30 1.00 FISH P TIEB1 Break out & U.D cut off jt. TL = 19.30'. UD Spear assy. 02:30 - 03:00 0.50 FISH P TIEB1 Move DCs to DP side of rig floor. 03:00 - 05:00 2.00 CASE P TIEB1 RIU casing tools & Torq Turn equip. 05:00 - 06:00 1.00 CASE P TIEB1 Hold PJSM & review running order for casing tie-back. RIH wI 9 5/8" 47#, L-80, TCII casing. Torq Turn all TCII connections to 17500 ft-Ibs. Installed turbolator on every jt except for last one in hole. 06:00 - 12:30 6.50 CASE P TIEB1 PU RIH w/9-5/8" tie-back string. 31 joints RIH @ 0930-hrs. 52 joints RIH @ 1230-hrs. AOGCC - 24-hr. notice of impending BOPE test requirement on 3/16/07. 12:30 - 13:30 1.00 CASE P TIEB1 Tag top of casing stump @ 2167'. Rotate casing string with hydraulic tongs and work triple connector cut lip guide down Printed: 4/2/2007 11: 11 :22 AM '~ '-'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 From 3/15/2007 12:30 - 13:30 1.00 CASE P TIEB1 13:30 - 14:30 1.00 CASE P TIEB1 14:30 - 15:00 0.50 CASE P TIEB1 15:00 - 16:00 1.00 CASE P TIEB1 16:00 - 18:00 2.00 CASE P TIEB1 18:00 - 19:00 1.00 CASE P TIEB1 19:00 - 20:00 1.00 CASE P TIEB1 20:00 - 00:00 4.00 CASE P TIEB1 3/16/2007 00:00 - 01 :30 1.50 CASE P TIEB1 01 :30 - 04:00 2.50 CEMT P TIEB1 04:00 - 06:00 2.00 CEMT P TIEB1 06:00 - 09:30 3.50 WHSUR P TIEB1 09:30 - 13:30 4.00 WHSUR P TIEB1 13:30 - 14:30 1.00 BOPSURP TIEB1 14:30 - 18:00 3.50 BOPSUP P TIEB1 18:00 - 18:30 0.50 BOPSUP P TIEB1 18:30 - 23:00 4.50 BOPSURP TIEB1 23:00 - 23:30 0.50 BOPSUP P TIEB1 23:30 - 00:00 0.50 CEMT P TIEB1 3/17/2007 00:00 - 00:30 0.50 CEMT P TIEB1 00:30 - 01 :30 1.00 CEMT P TIEB1 01 :30 - 06:00 4.50 CEMT P TIEB1 over stump. Tag collar looking up and screw casing in w/-11.5K ft-Ibs. torque on surface. Work pipe to transmit torque to collar connection. Rig down torque turn equipment and clear and clean floor. PIT casing to 2000-PSI for 30 charted minutes. Shear open ES cementer @ 2600-PSI. PJSM - Split stack, set casing slips and reset BOPE stack. N/D BOPE. Set casing slips with 125K hanging in slips. N/U BOPE. PIT break to 250-PSI LP and 3500-PSI HP. RlU lines & reverse circulate well. Heat up fluid until we had 82 degree returns. Pumped 3 BPM @ 150 psi. RID circulating head. Load wiper plug & install X-over & cementing head on 95/8" casing. Spot in SWS cementing equip. & begin RlU. Con't to circulate well. 3 BPM @ 150 psi. Getting 82 degree returns. Con't to RlU cementing equip. Wait on trucks to cement. Con't to wait on trucks. Circulate well wI 82 degree 9.8 brine. 3 BPM @ 150 psi. Hold PJSM & review cement procedure wI all hands. Pump 10 bbls of fresh water & pressure test lines to 4000 psi. Mix & pump 145 bbls of 15.8 ppg Class "G" wI gas blok. Pumped 5 BPM , APP 600 psi. SID & drop plug. Displace wI 5 bbls cement followed by 155 bbls of 9.8 ppg brine. Displaced 6 BPM, then dropped to 2 BPM for last 6 bbls. ADP 750 psi. Bumped plug wI 2500 psi. Held for 2 min, OK. Bled back 1 bbl. Had 18 bbls of cement returns to surface. PD @ 03.55 hrs. RID cementing equip. Break out & UD cementing head. Blow lines. Flush stack. Suck out 9 5/8" casing. N/D BOPE. Cut 9-5/8" casing wlWachs cutter. N/D tubing spool. Install new casing packott. Replaced original casing packing with undersized packing to get packott ring down on casing and into casing spool. N/U new tubing spool. Test casing packott to 3800-PSI for 30 minutes. Good test. N/U BOPE. PIT BOPE per AOGCC/BP requirements: 250-PSI LP and 3500-PSI HP. Crew Change. Check PVT alarms. Inspect derrick. Con't to test BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Test was witnessed by John Crisp wI AOGCC. Tested rams wI 31/2" & 5 1/2" test jts. No failures. RID test equip. Drain BOP stack. Pull test plug. Install Wear Bushing. Tally, P/U & M/U BHA # 8. Con't to M/U BHA #8 as foillows: Bit, 2 - Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9 * 61/4" DCs, XO. TL == 308.69'. RIH wI same. RIH wI BHA #8 on 18 stands of 31/2" DP. Tag up on cement @ 2076'. (BHA + 18 stands + single + 26'). P/U kelly & break circulation. 5.3 BPM @ 350 psi. Drill cement from 2076' to 2166'. P/U Wt, S/O Wt, Rot Wt == 60K. Torq == 1500 ft-Ibs. 75 RPMs. WOB == 4-10K. Drill out wiper plug and Printed: 4/2/2007 11 :11 :22 AM ~ '-"' Legal Well Name: 03-01 Common Well Name: 03-01 Spud Date: 2/21/1976 Event Name: WORKOVER Start: 3/6/2007 End: 3/27/2007 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 3/27/2007 Rig Name: NABORS 4ES Rig Number: Date FrÖm 3/17/2007 01 :30 - 06:00 4.50 CEMT P TIEB1 baffle plate. 06:00 - 11 :00 5.00 FISH P TIEB1 RIH to top of sand @ 2943' and cleanout 4' to 2947". Swap hole to seawater. PIT casing to 3500-PSI for 30 charted minutes. No test. Leak off rate 10.93-psi/min. over 32 minutes from 3600-psi down to 3250-psi. Bled off and circulated well a DP volume of 18-Bbls. Did not observe any air or gas in returns. Attempted retest - Leak off rate 22.2-psi/min. from 3550-psi to 3150-psi over 18 minutes. Third PIT attempt- Pressure up IA with floor safety valve closed. Leak off rate 29.1-psi/min. from 3550-psi to 3200-psi. over 12 minutes. 11 :00 - 12:30 1.50 FISH P TIEB1 POH wlBHA #8. 12:30 - 13:00 0.50 FISH P TIEB1 BOLD BHA #8. 13:00 - 13:30 0.50 FISH P TIEB1 PUMU BHA #9: jars, bumper sub, boot baskets x 2 and JRCJB. 13:30 - 15:30 2.00 FISH P TIEB1 Close blind rams. PIT 9-5/8" casing to 3500-psi for 30 charted minutes. No test. Leaked off 200-psi in 19.5 minutes. Verified visually that blind rams are not leaking. Bled off and repressured casing to 3550-psi. Pressure bled off 450 psi in 15 minutes. Bled off and repressured to 2000-psi and closed manual kill and choke valves and HRC choke and kill valves. Also closed all valves on mud manifold and isolated from mud pump. No test. Leaked off 400-psi in 22.5 minutes. Bled off pressure. Relocated pressure sensor to opposite side of inner annulus, prssured up to 3500-psi and closed manual inner annulus valve on side being pumped into and also closed Lo-Torq valve and disconnected pumping line to verify valves not leaking. No visible leaks. No test. Pressure bled off 825-psi iin 40 minutes. 15:30 - 16:30 1.00 FISH P TIEB1 Collaborate with RWO engineer and formulate plan forward. Order out HES 9-5/8" RTTS for leak hunt. Wait to arrive. 16:30 - 18:00 1.50 FISH P TIEB1 PUMU HES 9-5/8" RTTS and RIH to 2150'. 18:00 - 18:30 0.50 FISH P TIEB1 Crew change. Check PVTs. Inspect derrick. 18:30 - 19:30 1.00 FISH P TIEB1 Conb't to RIH wI RRTS to 2450'. 19:30 - 20:00 0.50 FISH P TIEB1 Set RTTS @ 2150'. Pressure up to 3500 psi down DP & test csg. Lost 400 psi in 7 1/2 min. Pressure up 9 5/8" x DP annulus to 3500 psi & test csg. Test good. bleed off & Release RTTS. 20:00 - 20:30 0.50 FISH P TIEB1 P/U single, RIH & set RTTS @ 2174'. Pressure up DP to 3500 psi & test csg. Lost 500 psi in 10 min. Pressure up 9 5/8" x DP annulus to 3500 psi & test csg. Test Ok. Bleed off & release RTTS. 20:30 - 21 :30 1.00 FISH P TIEB1 UD 3 jts. RIH & set RTTS @ 2416'. Pressure up DP to 3500 psi & test csg. DP tested Ok. Pressure up 9 5/8" x DP annulus & test csg. Lost 300 psi in 10 min. Bleed off & release RTTS. 21 :30 - 22:30 1.00 FISH P TIEB1 UD 1 jt & set RTTS @ 2385'. Pressure up DP to 3500 psi & test csg. DP lost 75 psi in 15 min.. Pressure up 9 5/8" x DP annulus & test csg. Lost 400 psi in 10 min. Bleed off & release RTTS. 22:30 - 23:00 0.50 FISH P TIEB1 UD 1 jt & set RTTS @ 2355'. Pressure up DP to 3500 psi & test csg. Lost 100 psi in 15 min. Pressure up 9 5/8" x DP annulus & test csg. Lost 250 psi in 10 min. Bleed off & release RTTS. Printed: 4/2/2007 11:11:22AM .~ ,-,.. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/17/2007 23:00 - 00:00 1.00 FISH P TIEB1 POOH 1 stand & set RTTS @ 2281'. Pressure up DP to 3500 psi & test csg. Lost 300 psi in 15 min. Pressure up 9 5/8" x DP annulus. Lost 25 psi in 15 min. Bleed off & release RTTS. 3/18/2007 00:00 - 00:30 0.50 FISH P TIEB1 Finish testing @ 2281' Release RTTS. Leaking interval is 2281-2385'. RID circulating equip. 00:30 - 02:00 1.50 FISH P TIEB1 POOH & stand back 31/2" DP. Break out & UD RTTS. 02:00 - 03:00 1.00 FISH P TIEB1 M/U Fas-Drill plug & setting tool on 3 1/2" DP. 03:00 - 04:30 1.50 FISH P TIEB1 RIH wI Fas-Drill plug on 24 stands of 31/2" DP. 04:30 - 06:00 1.50 FISH P TIEB1 Space out Fas-Drill. Break circulation 3 BPM @ 250 psi. CBU. Set plug @ 2430'. 06:00 - 07:30 1.50 FISH P TIEB1 POH UD Halco composite plug setting tool. 07:30 - 09:30 2.00 FISH P TIEB1 PUMU RIH w/DP muleshoe and 3-1/2" DP. Tag composite plug @ 2430'. UD one joint DP. PUMU RIH w/24' 3-1/2" DP pup joint and space out 3' from top of composite plug. 09:30 - 10:30 1.00 FISH P TIEB1 SLB cementers arrived @ 0930-hrs. MIRU SLB cementers. 10:30 - 14:00 3.50 FISH P TIEB1 Wait on Veco vac trucks to arrive. Vac trucks arrived at 1400-hrs. 14:00 - 16:00 2.00 FISH P TIEB1 Day crew weekly safety meeting. PJSM - Cement squeeze: All rig crew, SLB cement crew and Veco vac truck drivers. 16:00 - 17:00 1.00 REMCM-P TIEB1 Pump 10-Bbls. fresh water to warm lines. PIT lines to 800-psi LP and 4500-psi HP. Pump 22-Bbls. "squeeze-crete" cement and 2-Bbls. fresh water displacement @ 1 .O-bpm while attempting to hold 300-400-psi backpressure. SID after pumping 2-Bbls. displacement. 17:00 - 18:00 1.00 REMCM-P TIEB1 Blow down lines. POH UD 24' DP pup and 1 joint DP. POH stand back 4 stands DP in derrick. Close annular preventer. Hook up lines and reverse out DP to clean seawater returns. Reversed 25-Bbls. Open annular preventer, line up mud manifold to pump down DP, close pipe rams and begin squeezing cement in 500-psi increments. 18:00 - 22:00 4.00 REMCM-P TIEB1 Squeeze cement. Pressure up in 500 psi increments to 3500 psi. SI Pressure bled off 800 psi in 55 min. RlU to repressure wi test pump & pressure up to 3500 psi. bleeding off 300 psi every -15 min. Con't to repressure to 3500 psi. repeated for additional 1 hr, then repressured & allowed to bleed off 1000 psi in 55 min. Final squeeze pressure 2500 psi. Slowly Bled off DP & blow down lines. 22:00 - 23:00 1.00 REMCM-P TIEB1 RID circulating head pin. POOH & stand back 31/2" DP. 23:00 - 00:00 1.00 REMCM-P TIEB1 P/U & M/U BHA #8 as follows: Bit, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9 * 6 1/4" DCs, XZO. TL = 308.69'. 3/19/2007 00:00 - 02:00 2.00 REMCM-P TIEB1 WOC. service accumulator. Clean out cement in reverse line valves. Clean & maintain rig. 02:00 - 03:00 1.00 REMCM-P TIEB1 RIH wI BHA #9 to 1900'. M/U circulating equip. 03:00 - 06:00 3.00 REMCM-P TIEB1 Wait on UCA results. Circulate well 1 BPM @ 30 psi. 06:00 - 08:00 2.00 REMCM-P TIEB1 Cement UCA results @ +500-psi. RIH to tag TOC. Tag cement top @ 2232'. Break circulation and wait on orders. Discuss PIT results in morning call with all and agree to proceed with drilling out cement. 08:00 - 11 :00 3.00 REMCM-P TIEB1 Obtain drilling parameters - 60K PUW, 60K SOW, 5.0-BPM @ 500-psi, 85-RPM and 4-5K-lbs. WOB. Drill out cement from 2232' to 2282'. Cement cuttings returns very soft and liquid. Stop drilling and consult with RWO engineer. Called SLB lab for UCA analysis information - UCA = 1600-psi at 11 OO-hrs. Printed: 4/2/2007 11: 11 :22 AM ""-" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/19/2007 08:00 - 11 :00 3.00 REMCM-P TIEB1 11 :00 - 16:00 5.00 REMCM-P TIEB1 16:00 - 17:30 1.50 REMCM-P TIEB1 17:30 - 18:00 0.50 REMCM-P TIEB1 18:00 - 18:30 0.50 REMCM-P TIEB1 18:30 - 20:30 2.00 REMCM-P TIEB1 20:30 - 21 :00 0.50 REMCM-P TIEB1 21 :00 - 21 :30 0.50 REMCM-P TIEB1 21 :30 - 22:00 0.50 REMCM-P TIEB1 22:00 - 23:00 1.00 REMCM-P TIEB1 23:00 - 23:30 0.50 REMCM-P TIEB1 23:30 - 00:00 0.50 REMCM-P TIEB1 3/20/2007 00:00 - 01 :30 1.50 REMCM-P TIEB1 01 :30 - 02:00 0.50 REMCM-P TIEB1 02:00 - 03:00 1.00 REMCM-P TIEB1 03:00 - 04:00 1.00 REMCM-P TIEB1 04:00 - 04:30 0.50 REMCM-P TIEB1 04:30 - 05:30 1.00 REMCM-P TIEB1 05:30 - 06:00 0.50 REMCM-P TIEB1 06:00 - 07:30 1.50 REMCM-P TIEB1 07:30 - 09:00 1.50 REMCM-P TlEB1 09:00 - 10:00 1.00 REMCM-P TIEB1 10:00 - 12:30 2.50 REMCM-P TIEB1 12:30 - 15:00 2.50 REMCM-P TIEB1 15:00 - 15:30 0.50 REMCM- TIEB1 15:30 - 16:30 1.00 REMCM- TIEB1 16:30 - 18:00 1.50 TIEB1 18:00 - 18:30 0.50 REMCM-P TIEB1 Obtain sample of cuttings and send to SLB lab for X-Ray defraction. Resume drilling cement. Drill out to 2425'. Cement cuttings normal hardness. CBU. Set kelly back and blow down lines. Rig up for PIT casing. PIT casing to 2500-psi for 30 charted minutes. Pressure bled off from 2500 psi to 1150 psi in 32 min. RID test equip. Blow down lines. Crew Change. Check PVTs & inspect derrick. Can't to drill cement from 2425 to 2430'. Drill up Fas-Drill plug from 2430 to 2435'. P/U, SIO Wt= 60K. Rpot Wt = 65K. 5.2 BPM @ 310 psi. Torq = 1200 ft-Ibs. 40-50 RPMs. WOB 2 -15K. Circulate bottoms up. 5.8 BPM @ 380 psi. Blow down & set back kelly. POH & UD 6 jts. RIH & tag up above sand @ 2938'. P/U kelly. Dry drill up remainder of Fas-Drill plug. WOB 5K, 50-60 RPMs. Drill from 2938 to 3941'. P/U off plug & break circ every few min between dry drilling. P/U last time & stringt was plugged. Attempt to unplug string... no success. Blow down lines & set back kelly. UD 1 jt of DP. POOH & stand back 3 1/2" DP. Can't to POOH & stand back 3 1/2" DP. Pulling wet, plugged string. Break out & UD BHA. Bit was not plugged. Clean out junk baskets. Baskets contained 1/2 bucket of cement & rubber. Bottom boot basket ID was plugged wI cement & a few rubber pieces. M/U BHA #10 as follows: RCJB, 2 Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9"" 6 1/4" DCs, XO. TL = 317.32'. RIH wI BHA # 10 on 31/2" DP. Circulate & pump Hi-Vis sweep to clean hole. Pump 5 BPM @ 670 psi. Drop ball. Reverse wI RCJB & clean hole. Rig engine #3 tripped offlione due to overheat. Restored engine to service. Tag top of sand and hoover debris with RCJB. Wash down to 2950'. Could washg no further. POH w/BHA #10. BO/LD BHA #10. Clean out finger basket and boot baskets. recovered -2-gallon of composite plug material in finger basket and cement in boot baskets. Finger baskets missing one finger in each basket. Mill shoe had cracked mill face. Ordered new mill shoe and replaced finger baskets. PUMU and RIH wlBHA #11: 8-1/2" mill shoe, boot baskets x 2, 9-5/8" scraper, bumper sub, jars and 9 each 6-1/4" DC's. Tag up on fill @2940'. Rotate drill & wash from 2940 to 2958. 70 SPM @ 1200 psi. P/U, SIO wt = 71 K. 50-90 RPMs. Break up Fas-Drill plug. Blow down lines. Set back kelly. POOH & stand back 31/2" DP. Stand back DCs. Break out & clean out RCJB. Recovered remainder of Fas-Drill plug. Clean out junk baskets. Recovered cmt, rubber & plug debris. Crew change. Check PVT alarms. Inspect derrick. Printed: 4/2/2007 11: 11 :22 AM ~ "'-' Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/20/2007 18:30 - 19:00 0.50 REMCM-P TIEB1 M/U RCJB Run # 3. 19:00 - 20:00 1.00 REMCM-P TIEB1 RIH wI RCJB on 31/2" DP. 20:00 - 20:30 0.50 REMCM-P TIEB1 P/U kelly & tag up on fill @ 2958'. Wash & rotate from 2958 to 2971'. No torq on bottom. 30 RPMs, 3.5 BPM @ 710 psi. P/U & SIO wt = 71 K, Rot Wt = 74K. 20:30 - 21 :30 1.00 REMCM-P TIEB1 Circulate bottoms up & pump 10 bbl Hi-Vis sweep. 5 BPM @ 1550 psi. Had small amount of gas to surface. Recovered sand, pcs of rubber & v. small amount of fiberglass from sweep. 21 :30 - 22:00 0.50 REMCM-P TIEB1 Blow down lines. Set back kelly. 22:00 - 23:00 1.00 REMCM-P TIEB1 POOH & stand back 3 1/2" DP. 23:00 - 00:00 1.00 REMCM-P TIEB1 Break out & UD RCJB assy. No recover in basket. Recovered sand & some pcs of rubber in boot baskets. 3/21/2007 00:00 - 01 :00 1.00 FISH P TIEB1 Clear & clean rig floor. 01 :00 - 02:30 1.50 FISH P TIEB1 P/U & M/U RBP retreiving tool. RIH on 31/2" DP. Tag up @ 2974'. 02:30 - 03:00 0.50 FISH P TIEB1 Reverse down thru sand from 2974 to 2995'.5 BPM @ 700 psi. Rev out sand & debris. 03:00 - 04:00 1.00 FISH P TIEB1 Mix & pump Hi-Vis sweep Clean hole & around RBP. 51/2 BPM @ 680 psi. 04:00 - 04:30 0.50 FISH P TIEB1 P/U & put 1/2 turn in string, work torq down & release RBP wi 35K. Allow rubbers to relax. Monitor well, well static. 04:30 - 05:00 0.50 FISH P TIEB1 Circulate bottoms up 5 1/2 BPM @ 420 psi. 05:00 - 06:00 1.00 FISH P TIEB1 POOH wi RBP. Stand back 3 1/2" DP. 06:00 - 06:30 0.50 FISH P TIEB1 Service Rig. 06:30 - 07:30 1.00 FISH P TIEB1 PJSM. POOH & UD Halliburton bridge plug & running tool. 07:30 - 08:30 1 .00 CLEAN P INTERV PJSM. M/U bit & bit sub on (9) 8 1/2" drill collars 08:30 - 11 :30 3.00 CLEAN P INTERV PJSM. RIHG wI clean out BHA on 3 1/2" DP, 90 stands. 151 K up wt, 123K down wt. 11 :30 - 12:00 0.50 CLEAN P INTERV PJSM. Pick up (3) jts & (1) 24' pup. Tag up @ 8933', (11' high). 12:00 - 13:30 1.50 CLEAN P INTERV PJSM. Bring on pump & 5 bpm 1900 psi & wash down to top of tubing stub @ 8944'. 13:30 - 14:00 0.50 CLEAN P INTERV PJSM. Close bag & reverse out @ 5 bpm 11100 psi, mucho sand back. 14:00 - 14:30 0.50 CLEAN P INTERV UD 3 jts & 24' DP pup. 14:30 - 18:00 3.50 CLEAN P INTERV POOH & Stand back 31/2" DP. 18:00 - 18:30 0.50 CLEAN P INTERV Crew Change. Check PVT alarms. Inspect derrick. 18:30 - 20:30 2.00 CLEAN P INTERV Finish POOH & stand back 31/2" DP. stand back 361/4" DCs. 20:30 - 21 :00 0.50 CLEAN P INTERV Break out & UD BHA. 21 :00 - 22:00 1.00 CLEAN P INTERV P/U & M/U BHA # 13 as follows: CIL Guide, 2 - Wash pipe Ext, Drive Sub, XO, 2 - Boot Baskets, Bit Sub, Bumper Sub, Jars, XO, 9 * 6 1/4" DCs, XO. TL = 323.48'. RIH wI same. 22:00 - 00:00 2.00 CLEAN P INTERV RIH wi BHA #13 on 31/2" DP. 3/22/2007 00:00 - 01 :30 1.50 CLEAN P INTERV Con't to RIH WI BHA #13. Ran 90 stands & P/U 3 singles. 01 :30 - 02:00 0.50 CLEAN P INTERV M/U circulating pin. Break circulation. 5 BPM @ 610 psi.Tag up @ 8944'. Wash down over tbg stub from 8944 to 8955'. Pump pressure increased to 1000 psi while washing over stub. P/U wt = 168k, SIO Wt = 120k. 02:00 - 04:30 2.50 CLEAN P INTERV Reverse circulate & pump 40 bbls sweep. 5.5 BPM @ 1200 psi. At bottoms up recovered scale, black dirty sand & metal cuttings. Pumped total of 660 bbls. FCP 1020 psi. Printed: 4/2/2007 11 :11 :22 AM ~ ""-'" Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/22/2007 04:30 - 06:00 1.50 CLEAN P INTERV Break off circulating pin. Blow down lines. UD singles, POOH & stand back 3 1/2" DP. 06:00 - 06:30 0.50 CLEAN P INTERV Service rig, check crown 0 matic, pit volume totalizers, OK. 06:30 - 10:30 4.00 CLEAN P INTERV PJSM. Continue to POOH w/3 1/2" DP. 10:30 - 12:00 1.50 CLEAN P INTERV PJSM. Break down I lay down drill collars and BHA. Cleaned out junk subs, recovered approximately 3 gallons of metal shavings. 12:00 - 14:00 2.00 CASE P TIEB2 PJSM. Rig up equipment, tongs to run casing. 14:00 - 14:30 0.50 CASE P TIEB2 PJSM. Review Liner running order wI all hands. 14:30 - 00:00 9.50 CASE P TIEB2 RIH wI 7" 26#, L-80, BTC-M liner. Fill pipe every 5 jts. Install 1 free floating centralizer per jt. Ran 120 jts. 3/23/2007 00:00 - 04:00 4.00 CASE P TIEB2 Con't to RIH wIT' 26#, L-70, BTC-M liner. Ran 1 free floating centralizer on each jt. Filled pipe every 5 jts. Ran total of 167 jts + 1 jt wI landing collar. 04:00 - 04:30 0.50 CASE P TIEB2 P/U Liner Hangerl ZXP assy & M/U on 7" string. Change out tools to run DP. 04:30 - 06:00 1.50 CASE P TIEB2 RIH wI Scab Liner on 3 1/2" DP. 06:00 - 07:00 1.00 CASE P TIEB2 PJSM. RIH (21) stands DP. 200K up wt, 165K down wt. Observe shear pins shear on overshot 22' in on last single on stand. Bottom out 26' in, UD single, pick up 10' pup & 24' pup wI cement head & RIH 24', overshot now 2' up from being bottomed out. 07:00 - 09:00 2.00 CEMT P TIEB2 PJSM. Service rig, rig up Schlumberger cementers. Pre job with all personel. 09:00 - 09:30 0.50 CEMT P TIEB2 Pump 5 bbls fresh water ahead to warm up lines, pressure test lines to 4500 psi, OK. Batch up. 09:30 - 11 :30 2.00 CEMT P TIEB2 Pump 194 bbls of 15.8 ppg class G cement, average pump rate of 5 bpm 1800 psi. Take returns thru choke to pits, holding up to 800 psi back pressure to maintain 800 psi pump pressure & keep cement from running away. With 194 bbls cement pumped, shut down pump, shut in choke, 1450 psi on choke. Drop plug, displace wI seawater @ 4bpm, 150 psi, holding 1100 psi back on choke. With 13.5 bbls away observe plug clear drill pipe & latch up wiper, bring rate up to 7 bpm I 550 psi, holding 800 psi back on choke. After cement turns corner, begin backing off choke & eventually wide open, seeing pump pressure climb to 3000 psi @ 3 bpm just prior to bumping plug Plug bumped wI 280 bbls pumped, (2 1/2 bbls over). Pressure up to 3500 psi to set liner hanger, slack off drill pipe tp 25K, OK. Pressure up to 4400 psi to set ZXP packer, OK. Bleed off pressure, test floats, OK. 3.2 bbls back. Rotate drillpipe (20) turns to the right, release liner running tool, OK. 11 :30 - 12:30 1.00 CEMT P TIEB2 PJSM. Reverse circulate @ 4 bpm I 550 psi, observe cement returns back after (1) dp volume. 12:30 - 14:30 2.00 CEMT P TIEB2 PJSM. Blow down lines, rig down cementers, clean pits & haul off dirty fluids. 14:30 - 16:00 1.50 CEMT P TIEB2 PJSM. POOH wI 20 stands DP. UD running tool. 16:00 - 18:30 2.50 BOPSUF P TIEB2 PJSM. Rig up to test BOPE. 1st test plug has bad seal, Re-dress test plug & install in spool. RILDS. 18:30 - 23:00 4.50 BOPSUPP TIEB2 Perform weekly pressure test on BOPE as per BP/AOGCC reaquirements. LP 250 psi, HP 3500 psi. Chuck Sheve wI AOGCC waived witnessing test. Pipe rams would not test. 23:00 - 00:00 1.00 BOPSUP P TIEB2 Change out rams wI new VBR 31/2" x 6". Replace 1 door seal Printed: 4/2/2007 11: 11 :22 AM ."-'" \---. Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/23/2007 23:00 - 00:00 1.00 BOPSUP P TIEB2 gasket. 3/24/2007 00:00 - 00:30 0.50 BOPSUF P TIEB2 Finish changing rams & door seal. 00:30 - 02:30 2.00 BOPSUF P TIEB2 Finish pressure testing BOPE as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Tested rams wI 31/2", 4 1/2" & 5 1/2" pipe rams. No failures. RID test equip. 02:30 - 03:00 0.50 CLEAN P INTERV P/U running tool & pull test plug. Run & set Wear Bushing. (9" ID) Run in 2 lock down screws. 03:00 - 05:00 2.00 CLEAN P INTERV P/U & M/U BHA # 14 as follows: Bit, 2* Boot Baskets, Bit Sub, Bumper Sub, Jars, Pump Out Sub, 9* 4 3/4" DCs. TL = 308.28'. 05:00 - 06:00 1 .00 CLEAN P INTERV RIH wI BHA # 14 on 31/2" DP. 06:00 - 06:30 0.50 CLEAN P INTERV Service rig. Check crown 0 matic, pit volume totalizers, OK. 06:30 - 09:30 3.00 CLEAN P INTERV Continue to RIH, tag top of 7" liner 17 stands, (2) singles & 12' in @ 1998'. Able to get through without rotating. Continue in hole wI 3 1/2" DP, tag top of cement 89 stands + 8' in @ 8768'. 149K up wt, 110K down. 09:30 - 10:30 1 .00 CLEAN P INTERV PJSM. Fluid pack well bore, close pipe rams & pressure test 9 5/8" x 7" casing from surface to top of cement @ 8768' @ 3500 psi 130 minutes, charted, good test. Bleed all pressure, open pipe rams. 10:30 - 15:30 5.00 CLEAN P INTERV PJSM. Kelly up & establish parameters. 150K up wt, 11 K down wt. Bring on pump @ 5 bpm I 950 psi. Rotate @ 80 RPM, 4000 ft/lbs of off bottom torque. Mill med hard cement from 8768' to plug in landing collar @ 8848'. Mill through landing collar through med hard cement to float collar @ 8900'. Mill through float collar & med hard cement to ported crossover @ 8910'. 15:30 - 17:30 2.00 CLEAN P INTERV PJSM. Mix I pump 20 bbls Hi Vis sweep @ 5 bpm 11100 psi, surface to surface. 17:30 - 18:00 0.50 CLEAN P INTERV Set back kelly. Blow down lines. Prep to POOH. 18:00 - 18:30 0.50 CLEAN P INTERV Crew change. Check PVT alarms. Inspect derrick. 18:30 - 21 :00 2.50 CLEAN P INTERV POOH wI BHA #14 & stand back 31/2" DP. 21 :00 - 21 :30 0.50 CLEAN P INTERV Break out & UD BHA #14. 21 :30 - 22:00 0.50 CLEAN P INTERV Clear & clean rig floor. 22:00 - 23:00 1.00 CLEAN P INTERV P/U & M/U BHA 15 as follows: 5 Bladed Junk Mill, Bit Sub, 9 * 27/8" PAC DP, XO, XO, Scraper, Bit Sub, Bumper Sub, Jars, Pump Out Sub, ( * 43/4" DCs. TL = 586.04'. 23:00 - 00:00 1.00 CLEAN P INTERV RIH wI BHA #15 on 31/2" DP. 3/25/2007 00:00 - 02:00 2.00 CLEAN P INTERV Con't to RIH wI BHA #15 on 3 1/2" DP. 02:00 - 02:30 0.50 CLEAN P INTERV P/U kelly, break circulation tag up on fill @ 8910'. Establish milling parameters. 02:30 - 06:30 4.00 CLEAN P INTERV Mill & clean out landing collar & fill from 8910'. P/U wt = 154K, SIO Wt = 11 OK, Rot Wt = 130K. torq 1200 ft-Ibs. set torq limiter to 2000 ft-Ibs. WOB 2-5K, RPMs = 30-40, 5 BPM @ 2000 psi. Clean out from 8910 to 8930'. Mill thru landing collar @ 8930'. 06:30 - 08:00 1.50 CLEAN P INTERV PTSM. Continue milling I washing down from landing collar @ 8930' - 9010',88 stands, (1) single & 35' of kelly. 08:00 - 09:30 1.50 CLEAN P INTERV PJSM. Mix & pump 40 bbls Hi vis sweep I surface to surface @ 5 bpm 11100 psi. Work pipe while circulating. 09:30 - 10:30 1.00 CLEAN P INTERV PJSM. Wash on down to composite bridge plug @ 9025'. Establish paramaters, 155K up wt, 11 OK down wt, 130K rotating wt. Off bottom torque = 150 amps I 3000 ft/lbs. Set torque limit @ 210 amps = 4750 ftlbs. Mill on composite bridge Printed: 4/2/2007 11: 11 :22 AM ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Dåte 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 3/25/2007 09:30 - 10:30 1.00 CLEAN P INTERV plug wI 80 RPM I 3 - 5 K WOB, pumping 3 bpm I 500 psi. Stalled out on torque & lost all returns. 10:30 - 15:00 4.50 CLEAN N STUC INTERV Attempt to pick up, pulling heavy. Unable to go down or rotate. Pull 50K over, 75K over, 100K over & 125K over, no movement. Observe well bore staying full with pump off, packed off. Work pipe, jar up, bang down, no movement. Finally free up by torquing up & jarring down, able to rotate freely after (2) down jars. Still unable to pick up free, but continue rotating thru plug, OK. pumping 3 - 4 bpm I 500 - 750 psi. Pick up free after milling thru plug. Stand back kelly & POOH (2) stands. Note some drag, suspect maybe some junk on the 7" scraper. RBIH, OK. 15:00 - 16:30 1.50 CLEAN P INTERV RIH, pushing plug out tailpipe to 9160',7" scarper @ 8877'. 16:30 - 18:00 1.50 CLEAN P INTERV PJSM. Set Back kelly. Blow Down lines. POOH wI 3 1/2" DP & cleanout assembly, laying down drill pipe, constant hole fill wI seawater. 18:00 - 18:30 0.50 CLEAN P INTERV Crew Change. Check PVT alarms. Inspect derrick. 18:30 - 00:00 5.50 CLEAN P INTERV Con't to POOH & UDDP. Use constant fill wI seawater. 3/26/2007 00:00 - 01 :00 1.00 CLEAN P INTERV Break out & UD BHA #15. Mill was 75% worn, had junk metal in water courses & 1 pc of rubber in scraper blade. 01 :00 - 01 :30 0.50 CLEAN P INTERV P/U running tool. BOLDS. Pull & UD Wear Bushing. 01 :30 - 04:00 2.50 RUNCOMP RUNCMP RID floor. Clean floor. RlU completion handling tools & Torque Turn equip. 04:00 - 04:30 0.50 RUNCOMP RUNCMP Hold PJSM wI all hands. Review Completion running procedure & assign tasks. 04:30 - 05:30 1.00 RUNCOMP RUNCMP P/U & M/.U tubing tail pipe assys, Baker Lok all connections below S-3 Packer & RI H . 05:30 - 18:00 12.50 RUNCOMP RUNCMP RIH w/4 1/2" 12.6/1 , 13CR-80 Yam Top tubing. Torque Turn all connections to 4440 ft-Ibs. Using Jet Lube Seal Guard on all connections. Ran 121 jts. 18:00 - 18:30 0.50 RUNCOMP RUNCMP Crew change. Check PVT alarms. Inspect derrick. 18:30 - 20:30 2.00 RUNCOMP RUNCMP Con't to RIH w/4 1/2/1 13Cr-80, Yam Top tubing. Ran in hole wI 159 jts. Torque turned all connections to 4440 ft-Ibs. Used Jet Lube Seal Guard on connections. 20:30 - 00:00 3.50 RUNCOMP RUNCMP Change out tools for 5 1/2/1 tubing. M/U 4 1/2" x 5 1/2" X-over in string. RIH w/5 1/2/1 17#, 13CR-80 Yam Top HC tubing. Torque turned all connections to 6580 ft-Ibs. Ran in hole wI 36 jts. 3/27/2007 00:00 - 01 :00 1.00 RUNCOMP RUNCMP Con't to RIH w/5 1/2/1 17#, 13Cr-80, Yam Top HC tubing. Ran total of 46 jts. Torque turned all connections to 6580 ft-Ibs. Used Jet lube Seal Guard on all connections. 01 :00 - 01 :30 0.50 RUNCOMP RUNCMP P/U 1 JT, RIH & tag up. P/U re-tag, confirm & perform space out for landing string. No pups needed. P/U Wt = 125K, SIO wt = 100K. Tagged 41/2/1 x 7" X/O 28' in on jt #203 @ 9814'. 01 :30 - 02:00 0.50 RUNCOMP RUNCMP M/U landing jt & hanger. RIH & land completion. RILDS. P/U wt = 125K, SIO Wt = 100K. Back out landing jt. 02:00 - 04:30 2.50 RUNCOMP RUNCMP RlU & displace down annulus wI 180 bbls of 120 degree seawater. followed wI 325 bbls of 120 degree inhibited seawater. Pumped @ 3 BPM , 20 psi. 04:30 - 06:00 1.50 RUNCOMP RUNCMP Drop Ball/Rod. Fill tubing. Pressure up & set packer. Test to 3500 psi, 30 min. 06:00 - 07:30 1.50 RUNCOMP RUNCMP PJSM. Good test on packer I tubing. Bleed pressure off tubing to 1500 psi. Line up and fill II A with heated seawater wI Printed: 4/2/2007 11: 11 :22 AM .~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 3/27/2007 03-01 03-01 WORKOVER NABORS ALASKA DRILLING I NABORS 4ES Start: 3/6/2007 Rig Release: 3/27/2007 Rig Number: Spud Date: 2/21/1976 End: 3/27/2007 RUNCMP corrosion inhibitor, 60 bbls to fill. Pressure up I/A to 3500, test & chart, 30 minutes, OK. O/A open through out test, no indication of communication to O/A. Bleed pressure off of tubing & observe DCK-2 valve shear, OK. PJSM. Line up and pump remaining heated I inhibited seawater down I/A, thru DCK valve, taking returns uo tubing to pits. PJSM. Set 2 way check valve, test from above & below @ 1000 psi, OK. PJSM. N/D BOPE. Remove, choke & kill line valves. Make breaks in stack so as to allow easy dissassembly of stack for installation of double gate. PJSM. N/U adapter flange, test void to 5000 psi, OK. N/U tree. RU circ lines to tree. RU lubricator. Pull TWC. RD lubricator. RU LRS and tested lines to 3500 psi. Pumped 150 bbls diesel down IA @ 3 bpm and 1000 psi, taking SW returns to pits. Allow fluids in IA and tubing to U-tube. Installed BPV and tested from below with LRS to 1000 psi for 10 minutes (charted). RD LRS and secured well. DS 03 Pad Operator approved tree configuration. Released rig @ 23:00 hrs, 03/27/2007. 06:00 - 07:30 1.50 RUNCOMP 07:30 - 08:00 0.50 RUNCOMP RUNCMP 08:00 - 09:00 1.00 BOPSUP P RUNCMP 09:00 - 13:30 4.50 BOPSUP P RUNCMP 13:30 - 18:00 4.50 WHSUR P RUNCMP 18:00 - 19:00 1.00 WHSUR P RUNCMP 19:00 - 20:30 1.50 RUNCOMP RUNCMP 20:30 - 21 :30 1.00 RUNCOMP RUNCMP 21 :30 - 23:00 1.50 RUNCOMP RUNCMP Printed: 4/2/2007 11: 11 :22 AM TREE = WELLHEAD = ACTUA TOR = KB. ELèÎ::: ..- 7" CrN FMC , "u.....~.".."...~...h."..>.....""'~".~,,. AXELSON " ..... 61í PJC DRAFT ...R.o'p.";...... . .. "'_~,,~.~""'n."'..."»h"'n..."?,¡ ~_,____,.,.,_.. ."............,..........m..__.'.,__,,_ Max A~~I~:::.... . ." . .. 3~ ~..?~~~: Datum MD = 9622' "..~"~n"~' ","",,_'> ~'~nw~ Datum ND = 8800' SS 19-5/8" CSG, 47#, L-80, BTC-M, ID = 8.681" 1--1 2153' 113-3/8" CSG, 72#, MN-80, 10 = 12.347" 1-1 2720' Minimum ID = 3.725" @ 9128' HES XN NIPPLE 4-1/2" TBG, 12.6#, 13CR-80, --1 8911' VAMTOP, .0152 bpf, ID=3.958" 17" LNR, 26#, L-80, BTC-M, .0383 bpf, ID = 6.276" 1--1 8913' 4-1/2" TBG, 12.6#, L-80, --1 8953' IBT-M, .0152 bpf, ID = 3.958" 4-1/2" TBG, 12.6#, 13-CR-80, --1 . NSCClNSCT, .0152 bpf, ID = 3.958" 9150' ÆRFORA TION SUMrvtt\RY REF LOG: BHCS ON 03/13/76 ANGLE AT TOP ÆRF: 17 @ 9404 Note: Refer to Production DB for historical perf data SIZE I SPF I INTERV AL I Opn/Sqz I DA TE SEE PAGE 2 FOR ÆRFORA TIONS 1 1 1 19-5/8" CSG, 47#, L-80, ID = 8.681" 1--1 9987' I TD 1--1 10030' 03 -01 ~ ~ ~J l l J . L ~~fY NOTES: *** 4-1/2" CHROME TBG*** 1941' 1-i5-1/2" X 4-1/2" XC, ID = 3.875" 1 1996' 1- 9-5/8" x 7" BKR C-2 ZXP L TP w / FLEXLOCK LNR HGR, ID = 6.270" 2078' 1--14-1/2" HES X NIP, ID = 3.813" I 2142' 1--19-5/8" HES ES CEMENTER 1 GAS LIFT rvtt\NDRELS ST MO NO OBI TYPE VLV LATCH 6 3401 3392 16 KGB2 DCK BEK 5 4978 4815 30 KGB2 DMY BK 4 5797 5508 34 KGB2 DMY BK 3 6663 6224 34 KGB2 OMY BK 2 7488 6917 31 KGB2 DMY BK 1 8734 8020 23 KGB2 DMY BK PORT DATE o 03/27/07 o 03/27/07 o 03/27/07 o 03/27/07 o 03/27/07 o 03/27/07 8802' 1--14-1/2" HES X NIP, ID = 3.813" I 8823' 1-i7" X 4-1/2" BKR S-3 PKR, ID = 3.875" I 8847' 1--14-1/2" HES X NIP, ID = 3.813" 1 1 8911' 1-{4-1/2" WLEG, ID = 3.958" 1 I 8913' 1--17" X 4· 1/2" PORTED XO, ID::: 3.958" I 8944' 1--14-1/2" TBG STUB 1 r 8953' 1--19-5/8" X 4-1/2" UNIQUE OVERSHOT I ~ 8970' 1-14-1/2" X 5-1/2" XO, ID = 3.92" I 8972' 1-{9-5/8" X 5-1/2" TrN HBBP-T PKR, ID = 4.875" 8977' li5-1/2" X 4-1/2" XO, ID = 3.958" 1 1 DATE RBI BY COMMENTS DATE RBI BY 04/10/76 ORIGINAL COM PLETION 02/26/96 RWO 03/30/07 N4ES RWO 04/10/07 ?/ PJC DRLG DRAFT CORRECTIONS COMMENTS 9128' 1-14-1/2" HES XN NIP, ID = 3.725" I 9150' 9152' 1-14-1/2" WLEG, 10 = 3.958" 1 1--1 ELMD IT LOG NOT (XX/XX/XX)? I ???? 1--1 FISH - 4-1/2" LOCK KEY (7120105) 1 ???? I--1FISH-13.06' LONG IBP(06/01/02) 1 9620' 1--1 CMT A...UG (SET 04/21/92) 1 PRUDHOE BA Y UNIT WELL: 03-01 PERMIT No: "1750750 API No: 50-029-20187-00 SEC 10 T10N R15E 1578.57 FEL 1129.48 FNL BP Exploration (Alas ka) PERFORA TION SUMMARY REF LOG: BHCS ON 03/13/76 ANGLEATTOPÆRF: 17 @ 9404 Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 4 9404 - 9424 S 04/21/92 3-3/8" 4 9424 - 9494 0 03/27/94 4 9494 - 9501 S 04/21/92 3-3/8" 4 9522 - 9536 0 05/04/92 4 9536 - 9561 S 04/21/92 3-3/8" 4 9571 - 9592 0 05/04/92 4 9592 - 9608 S 04/21/92 4 9622 - 9658 S 04/21/92 4 9671 - 9696 S 04/21/92 4 9728 - 9742 S 04/21/92 4 9788 - 9813 S 04/21/92 03-01 l ~r / " DATE REV BY COMMENTS DATE REV BY COMMENTS 04/10176 ORIGINAL COM PLETION 02/26/96 RWO 03/30/07 N4ES RWO 04/10/07 ?/ PJC DRLG DRA FT CORRECTIONS .~ PRUDHOE BA Y UNIT WELL: 03-01 PERMIT No: '1750750 API No: 50-029-20187-00 SEC 10 T10N R15E 1578.57 FEL 1129.48 FNL BP Exploration (Alaska) Re: FW: Change to 03-01 RWO (State Sundry 307-054) . . Dave, The goal is to deliver a pressure competant wellbore. Good luck with the work, I will place a copy of this message in the file. Tom Maunder, PE AOGCC \ \s- -a'lS- Original Message ----- From: " Re em , David C ":~l3:E':E::!11pç~ªI'~<::<?r¡:<:>_ Date: Thursday, March 22, 2007 4:44 pm Subject: FW: Change to 03-01 RWO (State Sundry 307-054) To: Thomas Maunder <tom maunder@admin.state.ak.u.8> SCANNED MAR 3 0 20D7 Tom, lemme know if you have trouble opening up this proposed schematic.Thanks again. From: Roach, Frank Sent: Thursday, March 22, 2007 4:35 PM To: Reem, David C Subject: Change to 03-01 RWO (State Sundry 307-054) Dave, As we discussed, 03-01 has changed scope slightly. After cementing the new 9-5/8" to surface and drilling out the shoetrack, the pressure> test to 3500 psi failed. After a leak hunt, the leak was isolated to the lead seal casing patch from a workover performed in 1988. To isolate this leak and ensure a competent annulus for gas ift, a 7" scab liner is going to be run from the tubing cut at 8942 ft to 2000 ft, anchored in the new 9-5/8" 47# casing that has been cemented (and> successfully pressure tested to 3500 psi) . Running the 7" scab changes our tubing completion from 5-1/2" 17# chrome to 4-1/2" 12.6# chrome through the liner and then corssed over> to 5-1/2" 17# chrome above the scab liner. Attached is the new wellbore schematic illustrating the addition to the scab liner and tubing change. «03-01 PROPOSED NEW. ZIP» Let me know if there are any questions. Regards, -Frank Roach 1 of 1 3/30/2007 9:25 AM . . TREE '" ? WELLHEAD: FMC 03...01 PROP SED ACTUATOR: CW AX8..S0N KB. 8..Bf = 61' SF. ELEV = KOP= ? 1 1:: i-! 5·112" X 4·1/';''' CROSSOVER I Max Angle = 35 @ 6400' Datum MD = 9622' . 10.- H 9·518- X 7" BKR C-2 ZXP l TP w 1 FLEX.LOCK Datum 1\10 = 8800'$8 / LNR H3R. 10 = 6290" 5-112" TBG, 11#, 13-CR-80. 0.0232 bpI, 10 '" 4.892" fl ... 1 Ii 5-112" HES X NiP, 10 '" 4.562" I 19-5l8~ CSG, 40#. l·80. 10 = 8,835" I V~ - GAS LIFT MANDRElS 113-3/8' CSG. 12#. WN-80. ID'" 12.347' I 2720' r 0 5T MD TYÆ VlV - I-- 6 3410 4-112" 1" 5 4960 4·112" 1" 4 5187 4-1Il" 1" Minimum ID = 3.725" @ 9128' :} 6634 4-112" 1" 2 7469 4· HZ" 1" HES XN NIPPLE 1 8112 4-112" 1" 1- ---i H 4-112" HES X NIP. 10= 4.562" t ~ ~ ---1 7" X 4·112'" BAKER 53 PKR 10 '" 6,000" I 4·112" TBG, 126#, 13-CR-80, (10152 bpI. 10 '" 3.958" I I r CSG, 26#, l-80, 10 '" 6276" I I' . 1 - --; 4·1/2" liES X NIP. 10 '" 4,562" t \ Ì\ ÆRFORA mN SUMMARY H 4-112" \NlEG I REF lOG: BHCS ON 03/13176 .....:1 I,;- --I ANGLEATTOPÆRF: 17 @ 9401 I [ ~ 7" X 4- H2" CROSSOVER I Note: Refer to Production DB for historical perf data I -I UNOUEMACHlNECNERSHOT I SIZE SPF INTERII Al OpnlSqz DATE 4 9404 - 9424 S 04/21192 8970' -t 4-1/2" X 5-1/T XC, D= 5,5" I 3-3/6" 4 9424 - 9494 0 03127194 ~ b 4 9494 - 9501 S 04121192 F 8972' H 9-5/S" X 5-1/2" TMlHBBP-T PKR 1 3-3/8" 4 9522 . 9536 0 05104192 891T H 5-1/2" X 4-1/2" XC, [) = 4.5" I 4 9536 - 9561 5 04/21192 3-3/B" 4 9571 - 9592 0 05/04192 4 9592 - 9608 S 04/21192 4 9622 - 9658 S 04/21192 4 9671 - 9696 S 04/21192 4 9728 - 9742 S 04/21192 4 9188 - 9813 S 04/21192 9128' 4-1/2" HES XN NIP. D= 3.725' I I 4-1/2" TBG. 12.6#, 13-CR-80, 9155' I I 9150' 4-1/2" TUBNG TAL WLEG I 0.0152 bpf. D '" 3.958" I 9152' H ELMD TT LOG NOT AVALABlE I 1111 4-1/2" lOCK KEY INTBG (1120105) I T TJ 1111 IBP- 06101102 -13.16'LONG I ~ 9620' CMT PlUG (SET 04/21192) I 19-5/8" CSG. 47#, l-80. 10 = 8.681" I 9986' C!Ð 10030' DATE RéV BY COMMENTS DATE REV BY COMMENTS PRUDHOE SAY UNIT 04110176 ORIGINAL COMPLETION 07120105 KSB/PJC FISH (LOCK KEY) W8..L: 03-01 02126196 LAST WORKOVER 09126105 EZLm..H WAWER 8m NOTE DELETED PERMrr No: '1750750 02117/01 GSNfTP CORRECroN$ 05130106 DTM WELLHCAD CORRECTION API No: 50-029-20187-00 07/16/02 JlJITP !BPs 03122/01 FVR PROPOSED fWVO see 10 nON R1SE 1578,57 FEL 1129.48 FNL 08112102 SDFIKK PUlL IBP 03110103 JMPfTP WAWERSAFETY NOTE BP exploration (Alaska) . . SARAH PALIN, GOVERNOR AIfA~1iA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 David Reem Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 03-01 Sundry Number: 307-054 \1,-015" 8/.:ANNED fEB 1. 3 2007 Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this !l day of February, 2007 Encl. nc raru:¡ 1. Type of Request: o Abandon o Suspend o Operation Shutdown o Perforate o Time Extension o Alter Casing 181 Repair Well o Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program 181 Pull Tubing o Perforate New Pool o Waiver o Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. IZI Development D Exploratory 175-075 ./ 3. Address: D Stratigraphic D Service 6. APINumbe~ / P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20187 -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: PBU 03-01 / Spacing Exception Required? DYes IZI No 9. Property Designation: / 110. KB Elevation (ft): 11. Field / Pool(s): / ADL 028328 61' v Prudhoe Bay Field / Prudhoe Bay Pool 12. PRESENT WELL CONDITION SUMMARY . .. .... , Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10030 , 9251 ' 9620 8859 9620 Yes, Unknown Casino Lenoth Size MD TVD Burst CollaDse Structural Conductor 80' 20" 80' 80' 1530 520 Surface 2720' 13-318" 2720' 2720' 5380 2670 Intermediate Production 9~87' 9-5/8" 9987' 9210' 6870 4760 Liner Perforation Depth MD (ft): I Perforation Depth TVD (ft): I Tubing Size: Tubing Grade: Tubing MD (ft): 9424' - 9592' 8671' - 8832' 7",26# x 5-1/2", 17#X 4-1/2",12.6# 13Cr80 9155' Packers and SSSV Type: 9-5/8" x 5-1/2" TIW 'HBBP-T' packer I Packers and SSSV MD (ft): 8972' 13. Attachments: 14. Well Class after proposed work: IZI Description Summary of Proposal D BOP Sketch D Exploratory IZI Development D Service D Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencina ODerations: February 28, 2007 IZI Oil DGas D Plugged D Abandoned 17. Verbal Approval: Date: DWAG DGINJ DWINJ D WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact David Reem, 564-5743 Printed Name~eem Title Drilling Engineer Frank Roach, 564-4373 Date 2.17/0" Prepared By Name/Number: Signature ~ Phone 564-5743 Terrie Hubble, 564-4628 Commission Use Onlv I Sundry Number: c ~ 7 - 05"9 Conditions of approval: Notify Commission so that a representative may witness D Plug Integrity QBOP Test D Mechanical Integrity Test D Location Clearance Other: 'š.'5()O\>~\ ~~Q ~c,.~ RBDMS 8Ft 1 ~), 20D7 . .--./') SubsequentFormRequored; '-\1:)'-\ é D 'Þ.ó APPROVED BY Date ~'fJ r- Approved By: __ u....COMMISSK>NER THE COMMISSION Form 10-403 Revised 06/2006 V '---" Submit In Duplicate \ /'Qì \"/ ¿f~1 KI::t,;I::JVI::LI r..f 7- ¿..q-tJ /' ~_. . STATE OF ALASKA _ ~;¿r-p, ALASKA Oil AND GAS CONSERVATION COM~ION k~{~ FEB ,0 7 2007 APPLICATION FOR SUNDRY APPROVAL Alaska Oil & Gas Cons. Commission 20 AAC 25 280 A hò ORIGINAL . . 03-01 Rig Workover Scope of Work: Pull tapered 13Cr-80 completion, cut and pull 9-5/8" casing above ECP, tie-back w/new 9-5/8" casing, replace 9-5/8" hanger with emergency slips and primary pack-off, and run 5-%" 13Cr80 completion. MASP: 2419 psi Well Type: Producer Estimated Start Date: February 28, 2006 Pre-Ri S 1 E 2 F 3 0 4 0 5 Drift for 4-1/2" composite bridge plug to -9050'. Set composite bridge plug @ -9020' (first full 'oint below TIW packer. Ref 2/22/96 tubin summa . MIT-T to 3500 si to confirm barrier. Chem cut @ -8940'. (Ref: 02/22/1996 tubing summary). Chem cut desired to be in the middle of the 151 full 'oint above the 5-%" x 4-%" crossover. Circulate well with seawater and FP w/ diesel thru the cut. CMIT TxlAxOA to 2000 psi to confirm mechanical barrier and casin inte rit . Bleed WHP's to 0 si. PPPOT-T, -IC, check all LDS. Set a BPV in the tubing hanger. Remove the wellhouse & flow line. Level the pad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE with 3-%" x 6" VBR's and blind rams to 3500 psi. Circulate out freeze protection fluid and circulate well to clean seawater through the cut. 2. Pull and LD tapered tubing string to the cut. 3. RU wireline and run USIT from cut to surface. 4. Run 9-5/8" RBP and set at -1 OOO'md below TOC determined from USIT. PT RBP to 1000 psi to prove up barrier. Stack -50 ft of sand on RBP. 5. Mechanically cut 9-5/8" casing in 2nd full joint above casing packer. Circulate out Arctic Pack. Pull casing thru stack. Back-off 9-5/8" stub and pull same. Note: VBR's will not be changed to 9-5/8" pipe rams as the well has two tested barriers (composite bridge plug and RBP) to the reservoir. 6. Screw back in with new 9-5/8",40#, L-80 casing and land on new emergency slips with new primary pack-off. PT 9-5/8" pack-off to 2500 psi. Cement new 9-5/8" casing to surface. 7. Run 5-%" 13Cr80 stacker packer completion with Baker S-3 packer. Position packer at -8850' MD. 8. Displace the IA to packer fluid and set the packer. 9. Test tubing and IA to 3500 psi. Freeze protect to 2200' MD. 10. Set BPV. ND BOPE. NU and test tree. RDMO. .TREE = , , WELLHEAD = ACTUA TOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumlVD= ? FI\£ CJIN AXELSON 61' 03-01 TES: *** CHROME TBG*** ? 35 @ 6400' 9622' 8800' SS - 2153' -i 7" CAMCO BAL-O SSSV NIP, ID = 5.937" 113-3/8" CSG, 72#, MN-80.10= 12.347" 17" TBG. 26#, 13-CR-BO, 0.0383 bpf, ID = 6.276" I 2962' -i 7" X 5-1/2" XO, ID = 5.5" I 15-1/2" TBG, 17#, 13-CR-BO, 0.0232 bpf, 10 = 4.892" H 3004' TOPOF4-1/2"TBG H 3004' PERFORA TION SUI\IIv1A RY REF LOG: BHCS ON 03/13n6 ANGLE AT TOP PERF: 17 @ 9401 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9404 - 9424 S 04/21/92 3-3/8" 4 9424 - 9494 0 03/27/94 4 9494 - 9501 S 04/21/92 3-3/8" 4 9522 - 9536 0 05/04/92 4 9536 - 9561 S 04/21/92 3-3/8" 4 9571 - 9592 0 05/04/92 4 9592 - 9608 S 04/21/92 4 9622 - 9658 S 04/21/92 4 9671 - 9696 S 04/21/92 4 9728 - 9742 S 04/21/92 4 9788 - 9813 S 04/21/92 OATE 04110/76 02126/96 02/17/01 07/16/02 08/12/02 03/10/03 Minimum ID = 3.725" @ 9128' HES XN NIPPLE 3004' -i 5-1/2" X 4-1/2" XO, ID = 4.5" I GAS LIFT MANDRELS ST MD lVO OEV TYÆ VLV LATCH PORT DATE 1 3416 3406 16 TB T-2 2 5799 5510 34 TB T-2 3 6879 6404 33 TB T-2 4 7593 7006 31 TB T-2 5 8148 7490 26 TB T-2 6 8703 7992 23 TB T-2 4-1/2" X 5-1/2" XO, 10 = 5.5" I 9-5/8" X 5-1/2" TJIN HBBP-T PKR I 5-1/2" X 4-1/2" XO, ID = 4.5" I 9128' -i 4-1/2" HES XN NIP, 10 = 3.725" I 4-1/2" TBG. 12.6#, 13-CR-80, -i 0.0152 bpf, ID = 3.958" 9150' 9152' -i 4-1/2" TUBING TAIL WLEG I H ELMO TT LOG NOT A V AILABLE I 9155' ???? -i 4-1/2" LOCK KEY IN TBG (7/20/05) I 19-5/8" CSG, 47#, L-80. ID = 8.681" I CMT PLUG (SET 04/21/92) I IBP- 06/01/02 - 13.16' LONG ŒJ REV BY PRUDHOE BAY UNrr WELL: 03-01 ÆRMrr No: '"1750750 AA No: 50-029-20187-00 SEC 10 T1 ON R15E 1578.57 FEL 1129.48 FNL COWMENTS ORIGINAL COMPLETION LAST WORKOVER CORRECTK>NS IBPs PULL IBP WAIVER SAFETY NOTE DATE 07120/05 09/26/05 05/30/06 REV BY COMMENTS KSBIPJC FISH (LOCK KEY) EZLlTLH WAIVER SFTY NOTE DELETED DTM WELLHEAD CORRECTION GSNITP JLJfTP SOF/KK JMPITP BP Exploration (Alaska) TREE = . LHEAD = ACTUA TOR = KB. B.EV = BF. B.EV = KOP= ? Max Angle = 35 @ 6400' Datum tJI) = 9622' Datum lVD = 8800' SS 9-5/8" CSG, 40#, L-80, ID - 8.835" 113-3/8" CSG, 72#, MN-80, ID = 12.347" . ? FMC CPN AXB.SON 61' 03-01 PROPOSE Minimum ID = 3.725" @ 9128' HES XN NIPPLE 15-1/2" TBG, 17#, 13-CR-80, 0.0232 bpf, ID - 4.892" I DATE 04110/76 02126/96 02/17101 07/16/02 08/12/02 03/10/03 PERFORA TION SUWMARY REF LOG: BHes ON 03/13/76 ANGLE AT TOP PERF: 17@9401 Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4 9404 - 9424 S 04/21/92 3-3/8" 4 9424 - 9494 0 03/27/94 4 9494 - 9501 S 04/21/92 3-3/8" 4 9522 - 9536 0 05/04/92 4 9536 - 9561 S 04/21/92 3-3/8" 4 9571 - 9592 0 05/04/92 4 9592 - 9608 S 04/21/92 4 9622 - 9658 S 04/21/92 4 9671 - 9696 S 04/21/92 4 9728 - 9742 S 04/21/92 4 9788 - 9813 S 04/21/92 4-1/2" TBG, 12.6#, 13-CR-80, 0.0152 bpf, ID = 3.958" 5-1/2" HES X NIP, ID = 4,562" GAS LIFT MANDRELS ST MD TYÆ VLV 6 3001 5-1/2" 1-1/2" 5 4655 5-1/2" 1-1/2" 4 5788 5-1/2" 1-1/2" 3 6693 5-1/2" 1-1/2" 2 7586 5-1/2" 1-1/2" 1 8760 5-1/2" 1-1/2" 8970' 8972' 8977' 9128' 9150' 9152' 5-1/2" HES X NIP, ID = 4.562" I 9-5/8" X 5-1/2" BAKER S3 PKR, ID = 6.000" 5-1/2" HES X NIP, ID = 4.562" I 5-1/2" HES XN NIP, ID = 4.455" I UNIQUE MACHINE OVERSHOT 4-1/2" X 5-1/2" XO, ID = 5.5" I 9-5/8" X 5-1/2" TPN HBBP- T PKR I 5-1/2" X 4-1/2" XO, ID = 4.5" I 19-5/8" CSG, 47#, L-80, ID = 8.681" I ~ REV BY COWÆNTS ORIGINAL COMPLETION LAST WORKOVER CORRECTIONS IBPs PULL 8P WA IVER SAFETY NOTE GSNITP JLJITP SDF/KK JMPITP DATE 07120/05 09/26/05 05/30/06 -1 4-1/2" HES XN NIP, ID = 3.725" I -f 4-1/2" TUBING TAIL VVLEG I H B.MDTTLOGNOTAVAILABLE I 1111 -i 4-1/2" LOCK KEY IN TBG (7/20/05) REV BY COM\1ENTS KSBIPJC FISH (LOCK KEY) EZLITlH WAIVER SFTY NOTE DELETED DTM INB.LHEAD CORRECTION IBP- 06/01/02 -13.16' LONG GMT PLUG (SET 04/21/92) I PRUDHOE BA Y UNIT WELL: 03-01 ÆRMIT No: "1750750 API No: 50-029-20187-00 SEC 10 T10N R15E 1578.57 FB. 1129.48 FNL BP exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ SAND PLUG ! CMT CAP Pu, tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 61 feet 3. Address ~ Explorato~.__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3263' FNL, 4617' FEL, Sec. 11, T10N, R15E, UM (asp's 713903, 5938075) 03-01 At top of productive interval 9. Permit number / approval number 1297' FNL, 1491' FEL, Sec. 10, T1 ON, R15E, UM (asp's 711692, 5939980) 175-075 At effective depth 10. APl number 1246' FNL, 1515' FEL, Sec. 10, T10N, R15E, UM (asp's 711666, 5940030) 50-029-20187-00 At total depth 11. Field / Pool 1137' FNL, 1583' FEL, Sec. 10, T10N, R15E, UM (asp's 711598, 5940142) Prudhoe Bay Field/Prudhoe Be)/Pool 12. Present well condition summary Total depth: measured 10030 feet Plugs (measured) Estimate Top of CMT Plug @ 9548' (06/30/2002) true vertical 9251 feet TOS @ 9551 (06/22/2002) Effective depth: measured 9584 feet Junk (measured) true vertical 8832 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 80' 20" 300 sx PF II 113' 113' Surface 2687' 13-3/8" 5400 sx PF 2720' 2720' Production 9953' 9-5/8" 1000 sx Class 'G', 105 sx 9986' 9209' PF II Perforation depth: measured Open Perfs 9424'-9494', 9522'-9536', Below CMT Cap 9571'-9592' Sqzd Perfs 9404'-9424', 9494'-9501 ', 9536'-9561', 9592'-9608' Sqzd Perfs below CMT Plug 9622'-9658', 9671'-9696', 9728' - 9742', 9788'-9813' true vertical Open Perfs 8677' - 8747', 8773' - 8787', Below CMT Cap 8820' - 8840' Sqzd Perfs 8652'-8671', 8738'-8745', 8779'-8802', 8832'-8847' Sqzd Perfs below CMT Plug 8861 '-8895', 8908'-8932', 8962'-8975', 9019'-9043' Tubing (size, grade, and measured depth) 7" 26# 13CR-80 @ 2962'. 7" XO 5-1/2" @ 2962'. 5-1/2" 17# 13CR-80 @ 3004'. 5-1/2" XO 4-1/2" @ 3004'. 4-1/2" 12.6# 13CR-80 @ 8970'. 4-1/2" XO 5-1/2" @ 8970'. 5-1/2" 17# 13CR-80 @ 8977'. 5-1/2" XO 4-1/2" @ 8977'. 4-1/2" 12.6# 13CR-80 @ 9150'. Packers & SSSV (type & measured depth) 9-5/8" x 5-1/2" TIW HBBP-T Packer @ 8972'. 7" Camco BAL-O SSSV Nipple @ 2153' MD. R E C E !V E D 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) JU] ~ ~00~_ Treatment description including volumes used and final pressure -- 14. Representative Dailv Averaae Producti~)~_o[.Iz3ia~tien, Qata,,,,,, I'nrnml_q.e, il3[~ OiI-Bbl Gas-Mcf ..... Water-Bbl.-,~'- w-Anehorat~sing Pressure Tub ng Pressure Prior to well operation Shut-In Subsequent to operation 07/05/2002 420 1772 11106 265 , 15. Attachments 16, Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true ,~nd correct to the best of my knowledge. Title: Technical Assistant Date July 09, 2002 ~ DeWayneR. Schnorr" ~, ~-~ ~ t ~ ! ~, I A ! PreparedbyDeWa)/neR. Schnorr564.5174~ Form 10-404 Rev 06/15/88 · ORiGiNAL SUBMIT IN DUPLICATE 04/14/2002 04/16/2002 04/18/2002 05/30/2002 06/01/2002 06/13/2002 06/21/2002 06/22/2002 06/30/2002 04/14/O2 04/16/02 04/18/O2 O5/3O/O2 O6/O 1/02 03-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS PPROF W/DEFT: DR]'FT/TAG PPROF W/DEFT: PRODUCT[ON PROF]'LE W/DEFT ANN-COIVllVl (AC-EVAL AND REPA]'R): AC-M]'TOA; AC-TI;FL PACKERS/BR]'DGE PLUGS/POGLMS: DRTFT/TAG PACKERS/BRIDGE PLUGS/POGLMS: ]'NFLATABLE BRIDGE PLUG SAND PLUG: ]~NFLATABLE BRIDGE PLUG SAND PLUG: SAND PLUG SAND PLUG: SAND PLUG SAND PLUG: DUIVlp BA]'L EVENT SUMMARY DRIFTED TUBING INTO LINER TO 9579' ELMD CORRECTED WITH A 3.5" CENTRALIZER, TTL AND S.BAILER. SB CAME BACK EMPTY. RDMO. GIVE WELL BACK FOR PRODUCTION.-NOTIFY DSO- COMPLETED PPROF WITH DEFT. PINCHED WELL BACK AT WING TO GET TOOLS DOWNHOLE. ATTEMPTED GAS LIFT SURVEY WHILE RIH. STOPPED BELOW TT OPENED WING AND LET WELL STABILIZE. LOGGED DOWN PASSES AT 40/80/120/160 FPM, ONE 80 FPM REPEAT, AND AN 80 FPM UP PASS. PERFORMED STOP COUNTS ABOVE AND BELOW PERFS. FIELD SPLITS: 9% 9404-9501', 75% 9522-9561' (PRIMARILY FROM THE SQUEEZED PERF), 16% FROM 9571' AND BELOW. <<<WELL LEFT FLOWING.>>> TIFL PASSED/MITOA PASSED. (waiver compliance) DRIFT TBG W/3-3/8" DMY GUN 12' LONG TO 9587' ELMD. BOTTOM OPEN PERF = 9592' = 5' FILL. TOP PERF = 9424' = 163' RAT HOLE. TARGET DEPTH FOR CIBP = 9538'. OBTAINED SAMPLE OF SMALL GRAVEL/FORMATION SAND - -- RDMO. <<<WELL RETURNED TO OPERATOR TO POP>>> KILL WELL FOR E-LINE. RIH W/3-3/8" BAKER IBP, TIE INTO TUBING TAIL, TAG PBTD @ 9577' ELMD. ATTEMPT TO SET IBP @ 9538' (CENTER OF ELEMENT) 2' INTO SQUEEZED PERFS. INFLATABLE APPREARS TO HAVE BURST, IBP ONLY PARTIALLY SET AND NOT DISCONNECTED. STICKY PULLING UP. RU PUMPERS, PUMP IBP BELOW OPEN PERFS AND FREEZE PROTECT TUBING. STILL CONNECTED TO IBP. PULL TO 2000# INTO TT AND PULL OFF BAKER WEAK POINT. LEAVE PLUG @ 9151' ELMD. POOH, FREEZE PROTECT FLOW LINE, RDMO, NOTIFY DSO, LEFT WELL SI. <<<JOB INCOMPLETE>>> FISH NECK OD 1.375" FISH LENGTH IS - 13.16' *** 06/13/O2 PULLED 3 3/8" IBP 13.6' LONG 1.375" FN .... DRIFT AND TAG TD W/3 3/8" X 10' DUMMY GUN, TEL, SB TO 9583' COR ELM, NO SAMPLE --- <<< LEAVE WELL SHUT IN PRE E-LINE >>> Page 1 03-01 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 06/21/02 MIRU CTE #3. KILL WELL. RIH. TAG TD @ 9586' CTMD. LAY IN FIRST STAGE SAND SLURRY. TAG TD @ 9570' AFTER I HOUR WAIT. MIX SECOND STAGE AND PUMP DOWN TO PERFS. TAG TOS @ 9560' AFTER I HOUR WAIT. MIX AND LAY IN THIRD STAGE SAND SLURRY. TAG TOS @ 9558' AFTER WAITING 1.5 HOURS. MIX AND PUMPED FOURTH STAGE OF SAND SLURRY DOWN TO PERFS. WAIT 1 HOUR TO TAG SAND. 06/22/02 RIH TAG TOS @ 9551'. CORRECTED TO E-LINE TAG. WELL READY FOR CEMENT CAP. RDMO. O6/30/O2 ( WELL SHUT IN ON ARRIVAL ) D/T W/3.625 CENT TEL SB DUMP 15 GALLONS CEMENT RDMO ( LEAVE WELL SHUT IN FOR 72 HRS. MIN. ) Fluids Pumped BBLS 2 PRESSURE TEST SURFACE PRESSURE CONTROL EQUIPMENT WITH DIESEL ( 2 TESTS) 105 METHANOL 24 50/50 METHANOL WATER 30 DIESEL 91 CRUDE 468 2% NON-SLICK KCL WATER 270 WATER 0.3 CEMENT 990.3 TOTAL Page 2 I 75'o MEMORANDUM TO: THRU: Julie Heusser, Commissioner Tom Maunder, ~-~~ P. I. SuPervisor ox[~--o ~ State of Alaska ~ Alaska Oil and Gas Conservation Commission DATE: January 15, 2001 FROM: John Crisp, SUBJECT: Petroleum Inspector Safety Valve Tests Prudhoe Bay Field Drill Site 03 January 15~ 2001: I traveled to BP's Prudhoe Bay Field to witness Safety Valve System tests on DS 03. Mark Womble was BP representative in charge of testing DS 03. Testing had been canceled on DS 03 1-14-01 due to blowing snow & chill factor of-50 degrees. Testing was condUcted in a safe & efficient manner. Two failures were witnessed. The AOGCC 'test report is attached for reference. 21 wellhouses were inspected during SVS tests. Wellhouses are in fair condition considering these were inspected after our recent blow. No heat or lights are installed in wellhouses-for producing wells. SUMMARY: I witnessed SVS tests in PBU on DS 03. 21 wells, 42 components tested. 2 failures witnessed. 4.8% failure rate. 21 wellhouses inspected. Attachments: SVS PBU DS 03 1-15-00jc cc; NON-CONFIDENTIAL SVS PBU DS 03 1-15-0ljc.doc Alaska Oil and Gas ConserVation Commission . Safety Valve SyStem Test RepOrt Operator: BPX Submitted By: John Crisp Date: 1/1 $/01 Operator Rep: Mark Womble ~ Field/Unit/Pad: Prudhoe Bay Field DS 03 AOGCC Rep: John Crisp Separator Psi: LPS 185 HPS 690 Well Permit Separ Set L/P· Test Test Test Date OiI, WAG, G~J, NUmber NUmber PSI PSI Trip ·Code· Code Code Passed GASorCYCLE 03.01 1750750 185! 150 100 P P OIL 03-02. · 1760240 185i 150' 120' P P OIL 03-03 1760390 185 150 110 P P OIL 03-04 1760510 03-05 1760570 ~ 03-06 1760600 03-07 1760530 ·· 03-08 17607'30 ' 18'5 150 130 -P P OIL 03-09 1790220 185 150 100 ·P P OIL 03-10 ' 1790210 ' '. · · 03-11 ' 1790470 ' · , · 03-12 · 1790580 ' ' 03-13 1790710 03-14 1790820 185 150 100 ~P P OIL 03-15A 1930150 185 '150 100 P P OIL 03-16A :1970330 - 03-17. 1791020 03,18A 1930420 , 03-19 1830920 185 150.. 90 P P OIL 03-20A 1930470 185 150 100 P' P OIL 03-21 1831120 185 150 100 P P OIL 03-22 1831230. 690 600 420 P P OIL 03-23 1831270 185 150 0 1 P OIL 03-24A 1980060 690 600 530 P P OIL 03-25A 1930230 03-26 1831510 ' 1'85 ' 150 . I10 P P OIL 03-27 1840620 185 ' 150 100 P P OIL 03-28 ' 1840720 03-29 1840790 185 150 110 P ' P OIL · 03-30. 1840830' 185' 150 90 P ' P OILi 03-31 1840920 185 150 140 P P OIL 03-32A 1940540 185 150 :110 P P OIL 03-33A 1970390 03-34B' 2000110 185 150 0 1 P OIL 1/18/01 Page 1 of 2 SVS PBU DS 03 1-15-01c.xls Well Permit Separ Set L~ Test Test Test Date Oil, WAG, GINJ, Number Number 'PSI PSI Trip . Code Code Code Passed CAS or CYCLE (~3-35 I 1910800 185 150 90 P P OIL 03-36 1930190 Wells: 21 Components: 42 Failures: 2 Failure Rate: 4.8% Uloo var Remarks: 1/18/01 Page 2 of 2 SVS PBU DS 03 1-15-01c.xls r '~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ~ Plugging Pull tubing _ _ Alter casing __ Repair well ~ Perforate Other ~ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 2017' NSL, 665' EWL, SEC. 11, TION, R15E At top of productive interval 1297' SNL, 1491' WEL, SEC. 10, TION, R15E At effective depth At total depth 1137' SNL, 1583' WEL, SEC. 10, TION, R15E 5. Type of Well: Development Exploratory Stratigraphic Service ORIGINAL 6. Datum elevation (DF or KB) KBE = 61 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 03-01 9. Permit number/approval number 75-75 10. APl number 50- 029-20187 11. Field/Pool Prudhoe Bay Field~Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 10030 feet Plugs (measured) 9251 feet 9584 feet Junk (measured) 8832 feet Fill at 9584' MD Casing Length Structural -- Conductor 80' Surface 2661' Size Cemented Measured depth 20" 300 sx PF II 80' 13-3/8" 5400 sx PF 2720' True vertical depth 80' 2720' Intermediate -- Production 9925' Liner 9-5/8" 1000 sx 'G', 105 sx PF II 9986' RECE f' ED Perforation depth: measured 9424'- 9494', 9522'- 9536', 9571'- 9592' APR 0 9 1996 true vertical 8677'- 8747', 8773'- 8787', 8820'- 8840' Alaska 0il & Gas Cons. Commissior Anchorage Tubing (size, grade, and measured depth) 7", 26#, 13Cr80 at 2964'; 5-1/2", 17#, 13Cr802964'- 3004'; 4-1/2", 12.6#, 13Cr80 3004'- 8970'; 5-1/2", 17#, 13 Cr80 8970'- 8977'; 4-1/2", 12.6#, 13Cr80 8977'- 9150' Packers and SSSV (type and measured depth) 7" Camco BaI-O SSLN at2153'; TIW HBBP-T packer at 8972' 13. Stimulation or cement squeeze summary Intervals treated (measured) · Treatment description including volumes used and final pressure 14. Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcf Water, Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby/~y that th~e~ is true and correct to the best of my knowledge. I/ Signed ~,~,x'~ ~~'~ .... Title Senior Drilling Engineer Form 10-~t~'~ Rev 06/1~/8~ Date ,~--~-~Z' SUBMIT IN DUPLICATE SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX ! ARCO Well Name: 03-01 RWO Rig Name: Doyon 16 AFE: Accept Date: 02/1 4/96 Spud Date: N/A Release Date: 4J9053 O2/24/96 Feb 14 1996 (1) Rig moved 50 %. Rig moved 50 %. Rig moved 98 %. Feb 15 1996 (2) Repaired Rig services. Repaired Additional services. Rig moved 100 %. Fill pits with Seawater. Held safety meeting. Removed Hanger plug. Held safety meeting. Circulated at 8907 ft. In- stalled Hanger plug. Removed Xmas tree. Rigged up BOP stack. Feb 16 1996 (3) Rigged up BOP stack. Tested BOP stack. Removed Hanger plug. Pulled Tubing on retrieval string to 5300 ft. Circulated at 6000 ft. Laid down Tubing to 40 ft. Tested BOP stack. Held safety meeting. Removed Emergency seal assembly. Installed Seal assem- bly. Rigged down BOP stack. Removed Casing spool. Installed Seal assembly. Installed Casing spool. Tested Seal assembly. Rigged up BOP stack. Feb 17 1996 (4) Circulated at 6745 ft. Laid down Tubing to 3008 ft. Rigged down sub-surface equipment - SCSSSV nipple assembly. Laid down Tubing to 6745 ft. Rigged down Tubing handling equipment. Held safety meeting. Rigged up Wireline units. Set downhole equipment (wireline). Held safety meeting. Prepared & fired cutting charge at 8876 ft. Rigged down Wireline units. Made up BHA no. 1 . Singled in drill pipe to 1505 ft. Rigged up Kelly. Feb 18 1996 (5) Rigged up Kelly. Held safety meeting. Singled in drill pipe to 6706 ft. Fished at 6754 ft, Circulated at 8876 ft. Pulled out of hole to 4875 ft. Held safety meeting, Pulled out of hole to 0 ft. Rigged up Tubing handling equipment. Laid down Tubing to 2151 ft, Rigged down Tubing handling equipment. Made up BHA no. 2 . R.I.H. to 6709 ft. Singled in drill pipe to 8897 ft. Fished at 8897 ft. Operations Summary for: 03-01 RWO Feb 19 1996 (6) Fished at 8896 ft. Circulated at 8896 ft. Pulled out of hole to 0 ft. Laid down Tubing to 70 ft. Made up BHA no. 3. R.I.H. to 3285 ft. Serviced Block line. R.I.H. to 5610 ft. Held safety meeting. R.I.H. to 8962 ft. Fished at 8962 ft. Circulated at 8962 ft. Pulled out of hole to 0 ft. Made up BHA no. 4 . R.I.H. to 3798 ft. Feb 20 1996 (7) Held safety meeting. R.I.H. to 8962 ft. Washed over string at 8962 ft. Milled Permanent packer at 9011 ft, Circulated at 9011 ft. Singled in drill pipe to 9115 ft. Pulled out of hole to 4724 ft. Held safety meeting. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 5. R.I.H. to 9115 ft. Fished at 9115 ft. Pulled out of hole to 0 ft. Laid down fish. Feb 21 1996 (8) Laid down fish. Tested Casing. Made up BHA no. 6. R.I.H. to 9274 ft. Reamed to 9274 ft. Circulated at 9279 ft. Pulled out of hole to 8125 ft. Held safety meeting. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 7. R.I.H. to 7890 ft. Ser- viced Block line. R.I.H. to 9275 ft. Milled Debris barrier at 9275 ft. Circulated at 9292 ft. Feb 22 1996 (9) Held safety meeting. Pulled out of hole to 0 ft. Pulled BHA. Made up BHA no. 8. R.I.H. to 9283 ft. Washed to 9305 ft. Re- verse circulated at 9305 ft. Pulled out of hole to 6701 ft. Held safety meeting. Pulled out of hole to 0 ft, Pulled BHA. R.I.H. to 2800 ft. Tested Casing. R.I.H. to 9010 ft. Tested Casing, Circulated at 9010 ft. Feb 23 1996 (10) Held safety meeting. Pulled out of hole to 5290 ft. Pulled out of hole to 2798 ft. Tested Casing. Pulled out of hole to 0 ft. Pulled out of hole to 0 ft. Rigged up Tubing handling equipment. Held safety meeting. Ran Tubing to 189 ft (4.5 in OD). Held safety meeting. Ran Tubing to 6997 ft (4.5 in OD). RECEIVED APR 0 9 199G Alaska 0il & Gas Cons. Commission Anchorage Page Operations Summary for: 03-01 RWO Feb 24 1996 (11) Held safety meeting. Ran Tubing to 9149 ft (7 in OD). Rigged up sub-surface equipment - SCSSSV nipple assembly. Ran Tubing to 9149 ft (7 in OD). Tested Dual control line. Ran Tubing on landing string to 9149 ft. Held safety meeting. Circulated at 9149 ft. Set Permanent packer at 8972 ft with 4000 psi. Rigged up sub-surface equipment- Other sub-surface equipment. Rigged down BOP stack. Feb 25 1996 (12) Held safety meeting. Installed Tubing hanger. Removed Adapter spool. Installed Xmas tree. Removed Hanger plug. Held drill (Spill). Rigged up Fluid system. Rigged down Fluid system. RECEIVED APR 0 9 1998 Alaska Oil & Gas Cons. Commission Anchorage Page 3 GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 A~I'N: Sherrie NO.-9946 Company: 1 2/21/9 5 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 1-9A ~,_~(L~ ~'_.~ PR~)DPROFILE .. 951125 '1 I -- D.S. 2-02 ~ ~ PROD PRORLE 9511 23 1 , ,, 1 ..... D.S. 3-01 ~ ~ '~ ,,~f LEAK DETECTION 9 51 1 2 4 1 1 D.:S.. 3-21 ~f~ ~ ! I ?--, ... STATIC PRE,~ SURVEY & JEWELRY 9511 20 I I ' D.S. 3-28 .... (~ L// 7 0-.-- LEAK DETECTION 95112 4 I 1 ' D.S. 5-06A ~ ~-' ~ PROD PROFILE 951123 1 1 O.S. 7-19 2-. ~---I'~ PROD PROFILE 951124 1 1 " - D.S. 14-15 ~ ~'~ DUAL BURST TDT-P BORAX 9.51121 I I ' ., · , , ,, . ,. , , _ .... , _ SIGNE Please ~ r r n f th~ tal to Sherrie at the above address. Thank you. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9186 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 1/13/95 Field: Prudhoe Bay Floppy ' Well Log Description BL RR Sepia RF Sepia Mylar Disk PWDW 3-1 ~-.~)~ INJEC PROFILE (12-20-94) 1 1 D.S. 4-25 ~)~ ~o (~ ~C] STATIC PRESS SURVEY (12-14-94) 1 1 D.S. 9-23 ~-~--~(~_~ RESERVOIR SATURATION LOG (12-18-94) 1 1 D.S. 12-2 '7 ~' ~--~ STATIC PRESS SURVEY (12-15-94) 1 1 D.S. 12-27 ~/-~--d)~ STATIC PRESS SURVEY (12-16-94) I 1 O.S. 13-3 -7 ~'-" ~,~--- STATIC PRESS SURVEY (12-16-94) I 1 D.S. 15-30 ~:~--(~'7~," PROD LOG (CTU E-LINE) (12-17-94) I 1 D.S. 16-21 <~ ~"'" ~/'7...- LEAK DETECTION (12-17-94) I 1 . SIGNED: ............. Please sign and return one copy of this transmittal to Sherrie at the above address. DATE: Thank you. ARCO Alaska, Inc. Date: Subject- From/Location- Telephone: To/Location- September 12, 1994 Kinley Caliper Survey's Karla Zuspan/ATO- 1529 (907) 263-4310 Distribution P.O. Box 100360, ~horage, AK Transmittal #: 94106 99510,~ ~, Well Log Date Tool Type I Contractor Number (M-D-Y) 03-01 08-07-94 Caliper Survey/ Kinley 03-28 08-07-94 Caliper Survey f Kinley 09-02 08-08-94 Caliper SurveyI Kinley ~--- i 12-15 08-05-94 CaliperSurve¥ I Kinley 17-07 08-06-94 Caliper Survey Kinley Number of Records: Karla Zuspan Distribution: Central Files ANO-8 Geology BPX ,,~ Exxon State of Alaska Pledge .~~~'.y.~__ning and returning a copy of transmittal. B/y5 / f~.~. ~,~'~ Date: ARCO Alaska, Inc. Is a Subsidiary of At]antlcRIchfleldCompany GeoQuest r~x] W. inlemational Airport Road Ar~horage, AK 99618-1199 ATTN: Sherrle NO. 8923 Company: Alaska Oil & Gas Cons Cc>mm , Mtn: Larry Grant t 3001 Porcupine Drive Anchorage, AK 99501 9/12/94 Field: Prudhoe Bay Well Log De~--ription BL RR Sepia RF Sepia Mylar q~ ' (~ D.$. 1-6 PRoD PROFILE (8-2,0-94), , 1 1 ~-c>-5 ID.S. 2-13 PERF RECORD (8-2,1-94) 1 1 ~ D.S. 3-1 PROD PROFILE (8-19-94) 1 1 ~ D.S. 4.4 PROD PROFILE (8-25-94) .... 1 ' ,1 ....... ~,3- ~,~'~, D.Si 4.5A' ~PROD PRO~LE (8-19-94) 1 1 ~ ~'~ D.S. 4-~ :INJEC PROFILE (8-19-94~ ... 1 . 1 . ~e-?~ D~. 6-10 PROD PROFILE (8-20-94}, 1 . 1 2~G~ D.S. 6-15 ~PERFRE~RD(8-20-94) 1 ' ,.,, ' 1 ,,, ~V- ~ D.S, 9-26 LE~ D~ON (8-23-94) 1 1 ~-~"~D.S. 11-24A DU~BU~T,~T-P~8-19~94) I ,, , I ~ D.S. 11-~ DUAL BU~T ~T-P (8-25-9~ , ,,1 1 ~- ~/ D.S. 12L3 PERF R~ORD (8-~-94) 1 1 ~ D.S. 14-15 PERF R~RD (8-20-94) 1 I _ ~/' ?~.D.S. 14-~ PROD PROFILE (8-24-9~ 1 1 AIn~kn ~il ~ G~s ~ns 'ED )94 SIGNED: Please sign and retum ~ copy of this trcmsndttal to Sherrle at the above address. 1hank you. DATE: Anchorage Commission ,,...,, STATE OF ALASKA ~-.,, ALASKA 'AND GAS CONSERVATION CC MISSION REPORT OF SUNDRY WELL OPEl-rATIONS 1. Operations performed: Operation shutdown Stimulate , Plugging Perforate X.~ Pull tubing Alter casing Repair well ,. Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2017' FSL& 665' FWLof Sec. 11, T10N, R15E, UM At top of productive interval 1297' FNL & 1491' FEL of Sec. 10, T10N, R15E, UM At effective depth At total depth 1137' FNL & 1583' FELof Sec. 10, T10N, R15E, UM 5. Type of Well Development X Exploratory Stratigraphic ,., Service 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-1 9. Permit number/approval number 75-75 10. APl number 50 - 029-20187 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10030 feet 9251 feet Plugs(measured) Fill @ 9584' MD Effective depth: measured true vertical Casing Length Conductor 80" Surface 2661' Production 9925' 9584 feet 8832 feet Junk(measured) Size Cemented 20" 300 sx PF II 13-3/8" 5400 sx PF 9-5/8" 1000 sx CIG & 105 sx PF II Measured depth 80' 2720' 9986' True vertical depth 80' 2720' 9209' RECEIVED Perforation depth: measured 9424-9494'; 9522-9536'; 9571-9592' true vertical 8677-8747'; 8773-8787'; 8820-8840' SEP-1 1994 Alsska Oil & Gas Cons. Commission Anchorage Tubing (size, grade, and measured depth) 7", 26#, L-80, Tbg @ 3008' MD; 5-1/2", 17#, L-80, Tbg @ 9133' MD Packers and SSSV (type and measured depth) Baker FB-1 Packer @ 9018' MD, 7" Camco BaI-O SSSV @ 2211' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. 14. Treatment description including volumes used and final pressure Represeqtative Daily Aver~0e Production or In!ection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 1288 4493 7494 -- Subsequent to operation 1478 4450 8807 -- Tubing Pressure 293 286 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~~~'~--" ~ ~ Title Engineering Supervisor Date Form 10-404 Rev 06/15/88 t t O71t Ct ~,~' 14'7 ItAll~ SUBMIT IN DUPLICATE/~ 3-01 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/30/94.' MIRU & PT equipment. RIH w/perforating gun & tagged PBTD at 9582' MD, then PU & shot 8' of reperforations as follows: Reperforated: 9571 - 9579' MD (Z3) Ref. Log: BHCS 3/13/76. Used a 3-3/8" carrier, & shot 4 spf, at 60/120 degree phasing, at underbalanced pressure. POOH w/perf gun. Noted ali shots fired. Rigged down. 3/26/94: RIH & tagged PBTD at 9584' MD. 3/27/94: MIRU & PT equipment. RIH w/perforating guns & shot 56' of reperforations as follows: Reperforated: 9424 - 9480' MD (Z4) Ref. Log: BHCS 3/13/76. Used 3-3/8" carriers, & shot 4 spf, at 180 degree phasing, at underbalanced pressures. POOH w/perf guns. Noted all shots fired. Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. ARCO Alaska, Inc. Date- Apr 14, 1994 P.O. Box 100360, . .horage, AK Transmittal #: 94034 99510,d~ ~' Subject: ARCO Cased Hole Finals From/LOcation: Telephone: To/Location- John- E. DeGrey/ATO- 1529 (907) 263-4310 Distribution i Well !Number ,9t~--~.~ 01-09A I ~-17.3 01-33 o3-ol /7~-~.q i 03-02 l S.5-'~7..! 03-19 '~'q-'FI ~ 03-29 .'.%03-29 03-31 ! /04-43 i ~,04-43 04-44 04-45 o5-o8 o6-19 07-08 07-23 09-01 09-02 Log Date J Tool Type (M-D-Y)! 04-02-94 i,/' Perf Record 03-25-94 ] 'TDT-P 03-28-94 iv,, TDT-P i,,' Perf Record 09-03 09-19 - 09-27 11-04 11-17 11-24A 14-03 ~ 14-23 4-28 14-28 \14-28 I§5-1~tZ_-'' 14-35 ~Z-~5~ 16-04A 1~5- 7~q~ 16-18 ~7..- ~2.. i 16-28 i 18-08 03-27-94 03-22-94 Leak Detection 03-22-94 .~, Bridge Plug 03-18-94 iv' Leak Detection 03-27-94 i/ Bridge Plug 03-27-94 i."' Bridge Plug 03-29-94 iv/ TDT-P 03-29-94 i/ CNTG 03-10-94 i ,/' USIT 03-13-94 !v, USIT 03-29'94 !./ USITCement Run, Scale 1,5" , 5II 1 5" 1 5" 1 2" 1 5" 1 5" 1 5" { Il .. 1,5 i 1 5" i 1 5" 1 5" 1.5" 1 5" 03-14-94 !'/ Prod Profile i I 5" 03-18-94 j,/ Perf Record i 1, 5" 04-03-94 !~ Perf Record !' 1, 5" 03-21-94 !,/ Brid~e Plu~ [ 1, 5" 03-30-94 i,- Prod Profile ! 1. 1"&5" 03-17-94 !./ Prod Profile i 1.5" 03-29-94 !/ Prod Lo~ i I 1"&5" 04-01-94 1," Perf Record ~ 1, 5" 03-16-94 j/ Prod Log 03-22-94 t / Perf Record 03-16-94! ,' Patch setting 03-29-94 1,/ Perf Record 03-18-94 Prod Profile 03-15-94 j,- Leak Detection 03-28-94 i" CNL 03-19-94 t .~ Prod Profile 03-15-94 !¢' Leak Detection I 1, 5" 03-28-94 iv' Patch Setting ! 1 5" 03-21-94 i~ Bridge Plu~ i 1, 5" 03-17-94 iv~ CNL i 1, 5" 03-15-94 i,,'- Perf Record i 1, 5" 03-14-94 i/Leak Detection i 1. 2"&5" ~ 511 03-14-94 ~ ~ Perf Record i 1, 03-20-94 i,/ TDT-P ~ 1.5" Contractor Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch ., Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Number of Records: 38 ARCO Alaska, inc. Is a Subsidiary of AIJantlcRIchfleldCompany ARCO Alaska, Inc. Date: Subject' From/Location: Telephone: To/Location: P.O. Box 100360, i .horage, AK Mar 17, 1994 Transmittal #: ARCO cased hole Magnetic tape(s) John E. DeGrey/ATO-1529 (907) 263-4310 Distribution 94030 99510,j~ ~, qO-- 21 IWell · Number i01-33 I02-08 I02-29A I03-01 I06-02 Log Bate (M-D-Y) 1-05-94 1-09-93 1-18-94 2-5-94 12-27-93 Tape Type ~ CNTD b~C~ b CNL ~o~ ~'~ CNL ibO'4~' CNTD CNL Run, Footage ~9980- 9425 ~ (,~)9844- 9560 ~ 9671- 9250 ~ 9576- · 9250 q1J 0618- 10000 Contractor SCHI SCHI SCHI SCH ~ SCHI Number of Records: 5 John E. DeGrey Distribution: Central Files Phillips BPX Exxon 'State of 'Alaska Please acknowledge receipt by signing and returning a copy of transmittal. By: _' _ = _~..~, .~ Date: .~ncho~a~e ARCO Alaska, Inc. Is a Subsidiary of AtJ&ntlcRIchfleldCompany ARCO Alaska, Inc. Date: Feb 16, 1994 P.O. Box 100360, , iorage, AK Transmittal #: 94023 99510,~ ~. Subject: ARCO Case_~d Jd.eJe_Eina~ From/Location: - John E. DeGrey/ATO-1529 Telephone: (907) 263-4310 To/Location: Distribution Number of * DS# 1-24ST the correct well name is 1-24A ** DS# 11-16ST1 the correct APl# is 50-029-2158i -00 Records:32 Well l Log Date Tool Type I Run, Contractor Number (M-D-Y) Scale ~ 1-24A i 12-24-92 PFC/GR 1, 5" Atlas ~,~ PWDW 01-24-94 Static press/Temp 1, 5" Sch ~'-+~ .~3-1 1-30-94 Perf Record f 1, 5" Sch ~t- ~'~ 3-1 I 2-5-94 CNL 1, 5" Sch · .~{'/ ~ 3-20AI 2-2-94 Perf Record 1, 5" Sch itl f 3-21 ~ 2-4-94 CompIRecord 1, 5" Sch 7.'5 3-25A ! 2-4-94 CompI Record 1, 5" Sch ~'7_ 3-27! 2-3-94 Prod Profile 1, 1"&5" Sch ~o~ 3-32 I 1-25-94 ~t Bridge Plug ~c. 1, 5" Sch ~-5 4-5 ~ 1-26-94 Tubing Cutter t~ 1, 5" Sch (0~{ I , 4-:~2 ~ 2-2-94 CompI Record 1, 5" Sch ~.~ [//4-46 t 2-6-94 USlT/Cement 1, 5" Sch ~ 4-46 t 2-6-94 PDC & Jewerly 1, 5" Sch [o~ ;'5-35! 2-7-94 L~ak Detec 1, 2" Sch ~ j,//9-9 ~ 2-7-94 Leak Detec 1, 2"&5" Sch ~'",,, 9-9 ! 1-26-94 Leak Detec 1, 1"&5" Sch p)d. 9-11t 1-24-94 Bridge PlugS~t~, ?.~.c,1, 5" ('(5~i;,'~ Sch O~ 9-13 i 1-29-94 {)~ Bridge Plug ~ 1, 5" Sch uti 9-20~ 1-24-94 Mi Inj Profile 1, 5" Sch ~R 9-34 f 1-25-94 ~! Bridge Plug ~v~ 1, 5" Sch · * 11- 2-3-94 Ib~ Bridge Plug~.~ 1, 5" Sch ~ 11-17 2-5-94 Leak Detec 1, 1 "&5" Sch t~ 12-16A 2-2-94 Perf Record 1, 5" Sch ~;~ ~14-2B 2-3-94 USIT/Cement 1, 5" Sch %,14-2B 2-4'94 Perf Record 1, 5511 Sch ~ ~ 14-31 2-4-94 Prod Profile 1 ~ Sch I~P) 15-9A 2-6-94 Perf Record 1, 5" Sch q~ 15-22 2-6-94 Perf Record 1, 5" Sch Z~ 16-7 6-16-92 Casing Collar (~.~"/ 1, 5" Atlas $~ 16-22 2-3-94 Gas lift survey 1, 1" Sch (o~ 16-2gA I 1-31-94 Prod Log 1, 1"&5" Sch John E. DeGrey ARCO AlasKa, lite. Is m 8ul~idlary of AtlantlcRlehfleidCol.lxlny ARCO Aluka. Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 4-22-03 REFERENCE: ARCO CASED HOLE 1.?-"7%-17 2-2o-93 Leak Detect Run 1, 5" x2-22-o2 Per/' Record Run 1. 5" 3-18-93 Prod Profile Run 1, 5" 1-10-"7,~1~3 3-5-93 Prod Profile Run 1, 5" . 1-24A 2-8-93 P TS Run 1. 5" 2-11-- -}"]-~ 2-23-93 Prod Profile Run 1, 5" ~'0--0~ --2-13 ~_ 2-13-93 Perf Record Run 1, 5" 3-1--~ 1-8-93 Prod Profile Run 1, 5" '~C~ ~ --3-9 11-12-92 Peri Record Run 1, 5" 3-34A _c~_~ 1-28-93 Prod Profile Run 1, 5" ~--- ~ ---4.12.._ .~[ 0.10.92 Collar Log Run 1, 5" · 4-24 ~-. 3-6-93 Leak Detection Run 1, 2"&b~ '7~--~/~ --5-6 2-13-93 Prod Profile Run 1, 5" 5-11--']~'~ 8-13-92 TMD Run 1, 5" ~c~._ {0~ -- 5-22 V~ 2-9-93 Perf Record Run 1, 5~ 6-3--']~- 1-22-93 Perf.Record Run 1, 5" '-~--- 7~ -.6-10 2-16-93 Prod Profile Run 1, 5" O18:- 2-22-93 Prod Profile Run 1. 5"" ~:~[\L~ --6-19 2-16-93 Prod Profile Run 1, 5" - 2-15-03 Prod Profile Run 1, 5" 9-7--'7/~-~ 3-9-93 Prod Profile Run 1, 5. ?'~ ~-7 -'0-16 3-9-93 hj Profilc Run 1, 5" qa-'l%~ 9-42-c~0"~5c~ 2-20-93 Temperature Log Run 1, 5" --0-40 2-6-93 Prod Profile Run 1, 5" 11-1A~-I~7_2*14-93 GR/Collar Run 1. 5" 11-1A; 3-19-93 GR/Collar Run 1, 5" ~'~-- I.O ~ --13-30 2-19-93 Prod Profile Run 1, 5" 13.33~*A:~-1l~12-14-92 Tracerscan Run 1, 5" C~o~_~ [ 13-33/ ..... 12-14-92 Tracerscan LOg Run 1, 5" --14.5A 3-10.93 PITS Run 1, 5" ~/14-28 3-2-93 Baker'IBP/Collar Run 1, 5" ~-' I~-- ''~14-28 3-8-92 Baker IBP/Collar Run 1, 5" * 14-34-~-~12-10-91 TMD Run 1, 5" ~-~ ~ -~16-25 - 2-26-93 Prod Profile . Run 1, 5" 16-28-~-~2-28-93 Prod Profile Run 1. 5" · ~--(~ --16-28 . 2-28-93 Prod Profile Run 1, 5" *' 16-29A c~-~3-1-93 Prod Profile Run 1, 5~ ~L-~ --17-15 11-16-92 Perf Record Run 1, 5" /17-16 1-12-93 Perf Record Run 1, 5" Please s~n and r~turn t~e attached copy as~:eeetpt of data. Have ANice Dayl ~ Sonya Wallace ATO-1529 APPROVED_~_ Trane# 93049 C~lCO HLS Camco Camco Camco Camco HI~ Camco HIS Camco HIS Camco Camco HIS HIS HLS Camco HIS Ca. co Camco HIS Camco Camco Camco Camco Camco Camco Camco Camco Camco HIS HIS Camco Camco Camco HIS Camco Camco Camco Camco HIS HIS # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLn~ #]3PX # STATE OF ALASKA The correct APl# for 14-34 is 50-020-21010-00. The coorect well name for this log is 16-29A. ~ STATE OF ALASKA ALASKA~--"\ AND GAS CONSERVATION C¢"-'"~'11SSIO~ REPORT SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate ..--. Plugging ~ Perforate X.~ Pull tubing Alter casing Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service X 4. Location of well at surface 2017' FSL & 664' FWL of Sec. 11, T10N, R15E, UM At top of productive interval 1297' FNL & 1491' FEE of Sec. 10, T10N, R15E, UM JUN - 2 992 At effective depth Alaska 0il & Gas Cons. At total depth r h0rage 1137' FNL & 1583' FEL of Sec. 10, T10N, R15E, UM 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-1 9. Permit number/approval number 75-75 10. APl number 50 - 029-20187 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10030 feet 9251 feet Plugs(measured) Cement Plug @ 9632' MD Effective depth: measured 9908 feet true vertical 9134 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80" 20" 300 sx PF II 80' 80' Sudace 2661' 13-3/8" 5400 sx PF 2720' 2720' Production 9925' 9-5/8" 1000 sx CIG & 105 sx PF II 9986' 9209' Perforation depth: measured 9480-9494'; 9522-9525'; 9525-9536'; 9571-9572'; 9572-9592' true vertical 8733-8747'; 8773-8776'; 8776-8787'; 8820-8821 '; 8821-8840' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 to 9033' MD Packers and SSSV (type and measured depth) 7" Camco BaI-O SSSV @ 2211' MD, Baker FB-1 Packer @ 9018' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Daily AYeraae Production or Iniection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Prior to well operation 289 7546 14122 -- Subsequent to operation 1910 369 239 -- Tubing Pressure 279 323 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x...~_ Gas...._ Suspended..._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _ Title Sr. Area Operations Engineer Form 10-404 Rev 06/15/88 R.3R/R BHR cc.: ~W. JWP Date ~////~_. ~'//~ Z.,- SUBMIT IN DUPLICATE 3-1 DESCRIPTION OF WORK COMPLETED CTU CEMENT SQUEEZE FOR WATER & GAS SHUT OFF 4121/92: An Acid Wash & CTU Cement Squeeze for Water & Gas Shutoff were performed as follows: MIRU CTU & PT equipment to 4000 psi. Loaded wellbore w/Hot Inhibited Seawater & Diesel, then RIH w/CT and acid washed the perforations at: 9404 - 9481' MD (Z4) 9481 - 9501' MD (Z4) 9525 - 9561' MD (Z4) 9572 - 9608' MD (Z3) 9622 - 9658' MD (Z3/2) 9671 - 9696' MD (Z2) 9728 - 9742' MD (Z2) 9788 - 9813' MD (Z2) Ref. Log: BHCS 3/13/76. Reciprocated 130 bbls of 12% HCl w/10% Xylene, followed by 130 bbls 12% HCl - 1.5% HF, followed by 150 bbls 3% NH4Cl Water Flush. Pumped 5 bbls 1% KCI Water spacer, & proceeded pumping 5 bbls Neat Cement, followed by 80 bbls Cement w/Aggregate, followed by 5 bbls Neat Cement, squeezing the perforations (listed above). Placed 35 bbls of cement behind pipe at 3500 psi maximum squeeze pressure, held for I hour. Contaminated cement w/biozan & jetted contaminated cement from wellbore down to 9620' MD. Left a cement plug in the wellbore below 9620' MD. POOH w/CT. Rigged down. 5/4/92: RIH & tagged the top of the cement plug at 9632' MD. Reperforated: 9480 - 9494' MD (Z4) 9525 - 9536' MD (Z4) 9572 - 9592' MD (Z3) Ref. Log: BHCS Added Perforations: 9522 -9525' MD (Z4) 9571 - 9572' MD (Z3) Ref. Log: BHCS 3/13/76. 3/13/76. Returned the well to productiOn & obtained a valid production test. EE¢£1V D J UN - 2 1992 Alaska 0il & Gas Cons. comm'tss'to~ Anchorage ARCO ~l~_~k~; Inc. P.O~Box 100360 Anchorage, Alaska 99510 DATE: 5-15-92 REFERENCE: ARCO CASED HOLE FINALS 2-26 4-28-92 CCL (Per/) R!m 1, 5" 3-1 5-4-92 Perf Record R~m 1, 5" 4-30ST 4-26-92 Completion Run 1, 5" 12-26 5-5-92 Completion R-n 1, 5" 15-1 4-28-92 CCL (Per/) Run. 1, 5" 16-20 5-5-92 Perf Record Run 1, 5" 17-11 4-30-92 Perf Record R-~ 1, 5" Please sign and return the attached copy as receipt of data. RECEIVED BY___/~~ ~ Have A Nice Day! Sonya Wallace ATO-1529 APPROVED_ Trans# 92100 ' \ Atlas Sch Sch Sch Aths Sch Sch # CENTRAL FILES # CHEVRON D&M # EXTENSION EXPLORATION # EXXON MARATHON # MOBIL # PHILLIPS PB WELL FILF.~ R&D # BPX # STATE OF ALAS~ TEXACO ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-6-92 REFERENCE: ARCO CASED HOLE FINALS 3-2 1-23-92 1-18-92 1-24-92 1-18-92 2-8-92. 1-26-92 1-26-92 1-20-92 2..7-92 2-~92 r,. _/2./ 13-6 13-16 ,~/-,,'F o 13,-19 2-9-92 2z-? 13-2o ~ Production Profile Prod Profile hJ Prome Prod Profile Prod Prof/aewelry Prod Profile Prod Profile hd m,o~e InJ 2ro~e ~,,J h~J motile ~nJ m.o~e Prod Profile Prod Profile Run 1, 5' Camco l~m 1, 5' Camco Run 1, 5' Camco Run 1, 2'&~' Camco Run 1, 2'&~' Camco l~m 1, [~' Camco l~m 1, [~' Camco ~ 1, ~'&lO' Camco ~ 1, 5" Camco Run 1, [~' Camco l~m 1, 5' Camco Run 1, ~' Camco Ran 1, ~' Camco Run 1, [~' Camco Run 1, ~' Camco l~n 1, 5" Camco Ibm 1, 5" Camco l~m 1, 5" Camco Please RECEIVED BY Have A Nice Day! Sonya Wallace ATO- 1529 and return the attached copy u receipt of data. RECEIVED - ; ...,~PR~.F 0 1 1992 ~Oil & Gas cons. Commission APPROVED _'-~ff_' Anchorage Trans# 9~-05~-F-- CENTRAL FILES CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON MOBIL * The R!m Date on this log is 1-23-92. # 1,m~.T.rPS PB WELL FILES R&D #BPX # STATE OF ALASKA TEXACO STATE OF ALASKA ALASKA · ': AND GAS CONSERVATION CO'~-~ISSION REPORT OF SUNDRY WELL oPr-HATIONS 1. Operations performed: Operation shutdown ~ Stimulate .--..- Plugging ..-- Perforate X~ Pull tubing Alter casing ~ Repair well .---. Other 2, Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2017' FSL & 664' FWL of Sec. 11, T10N, R15E, UM At top of productive interval 1297' FNL & 1491' FEL of Sec. 10, T10N, R15E, UM At effective depth At total depth 1137' FNL & 1583' FELof Sec. 10, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic 6. Datum of elevation(DF or KB) 61 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 3-01 g. Permit number/approval number 7-820 10. APl number 50 - 029-20187 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 10030 feet Plugs(measured) 9251 feet Effective depth: measured 9908 feet true vertical 9134 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80" 20" 300 sx PF 11 80' 80' Sudace 2720' 13-3/8" 5400 sx PF 11 2720' 2720' Production 9986' 9-5/8" 1000 sx Cl G & 105 sx PF 11 10030' 9251' Perforation depth: measured 9404-9481 ', 9481-9501', 9525'-9561', 9572-9608', 9671-9696', 9728-9742', 9788-9813', 9572-9608', 9622-9658' true vertical 8591-8665', 8665-8684', 8707-8742', 8813-8848', 8846-8870', 8901-8914', 8958-8982', 8752-8786', 8800-8834' Tubing (size, grade, and measured depth) 5-1/2", 17#, N-80 to 9065'; 4-1/2", 12.6#, N-80 tail to 9192' MD Packers and SSSV (type and measured depth) BaI-O SSSV @ 2115' MD, SAB Packer @ 9053' MD _,, ~g 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Repre~entatiYe Daily Averaae Production oe~etqe~rData OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 4773 11207 10246 1000 379 5537/'- 13231 11443 1000 356 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run Daily Report of Well Operations X Oil X Gas Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Service Sig ned (7~D~ij~___j~j~,_ Form 10-404 Rev 06/15/88 Title Sr. Area Operations Engineer SlJN/nh-6/g I Date ""?/~/~ / SUBMIT IN DUPLICATE SUMMARY OF WELL OPERATIONS ARCO Alaska, Inc. perforated DS 3-1 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay Unit on 3/17/91 (9572-9608' MD, Ref Log: BHCS 3/13/76). Produced fluids were in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. The SSSV was installed at the conclusion of the perforating and clean-up operation. A short summary of the work is given below. - Began perforating operation on 3/17/91. - RU perforating unit and pressure tested equipment to 3000 psi. - RIH w/ gun #1, tied-in, and shot 9592-9608' MD @ 2 spf. - SI well. - POOH. All shots fired. - RIH w/gun # 2, tied in, and shot 9572-9592' MD @ 2 spf. - SI well. - POOH. All shots fired. - Secured well. RD. JUL - 9 AJasP, a 0ii.& Gas Cons, t;ommJssion Anchorage JLB 6/28/91 F:' ~ O~ .i?, 0 ;:<. i <')(')','": ~: (;, ~ A N C'. I-'10 F:,' A [.; ii!:, A I.. A ;:;: K A 9 9 5 i (') C: [) L.. L. A R /I" I::. i-, F F' R O D U C'F I 0 N F:' R 0 F:' I I... E t::' R 0 D LJ [:: T I 0 N F:' R 0 I:: I I_ E · " "' ~ ~1 ,' "~ ..... C U L.. I.. r.~ i',. / I', t::. I", F:' I N J. PF:.'. 0 I::' I L.. E C 0 I.. I... A R/" F:' Iii: F;.'. I:: F' F;,' 0 I) U C '1" ]i 0 i'"..!. F:' R 0 I::' i[L.. t:il '1" E M P Ii"' R ~ i" U R lie L.. Iii: A t< D E: T E C: '1" I (] N I N,J F:' R 0 F:' I !... E F:'I:;.: 0 D tJ C T I 0 N F:' R 0 F:' I L.. E I N,..i P R 0 F' i L..IE I... E A K D E T E: C T I 0 N C 0 L_ L A R / P I!:' R F: F:' R 0 D U C T ]: 0 N F' R 0 F I !... E J Ii:- W Ii/. I.. F~'. Y F:' R r) D U C T I 0 i',l !-':' R 0 F I I... E F'I~ODIJCTI lIN F'ROF'I L.E F:'F;: I ,.S' M ANAL Y,S' I ,i' I_[-"Ai( DF'rFCTI ON I...E AK DETECTTON F'I:;:ODUCTI ON PF(OF I LIE: F:'I_E:ASE .'.;/I[~NAND I:;,'E:I'URN THE ATTACHED COF'Y F;:li:.' C E I V Ii:' D B Y ...~ I..IAVE A NICE DAY! ,S'i.,tAF~ ON W:[ L..SC~N A'i'O-.. i 5 ~'.9": R U N t:;~ t.J N FL' U N R U N i:;: t..I N F;.'. U N R t..I N R tJ N F;,' U N F;,' UN FkUN i:;: U N F;,' U FI fi,' U N R U N RUN I:~UN I:;,' tJ N RLJN RUN RUN R IJ N i, '5" A "f' I... A,:-:,' I, '.5" C: A ct C 0 ! , '.5" CAfqCO t , 5'" A'T' !... A ;~,' i , 2",.:..=:' ....':::" rt... A M C 0 i , 5'" A'i" I... r::; ;ii: i , 5:" C; A ~"'i C 0 t., 5" C A i'-.iC C) i , 5;" C: A i"i C i., 5" C. AMC9 i , ...:.'::'" [; A t:i .'...: Fi... i, :5" C,':', f,1C t) i, i"&5" CAr'iCO i , 5:" ¢:'-', t'I...AS i , I".5'." C ,'.:~ r.'i (; 0 t , '.5" C r::'~ H C 0 r.,..,L i , 5:" CA''~''' i, 5" CAMt;O 5: ' A T I... A t , I "&5" CAMCL) c:.: m "' "'~' I"' '" t ~ .., t.,f:..Iq..,tJ t, ,5" t:; r::'~["i C O A S R E C E I F:' T 0 I::' D A '1' A ,. A PF'RO VEI)~ -' ''''~ 'rl;:AN.~":,T- 91 (-)82 ....... DISTRIBUTION · .,."CENTRAl. FILES · ,,."" C I..i E: V R 0 N · '",,: E:XTENSION EXF'LOI:;tAT I ON :~ E: X X 0 N i"tARAI'HON :~ M 0 B I I_ F' I"11 L L. I F' S P B W E L. L F' II..E...:," '~'' R & D · ,- B F:'X '"' S'I"AI'F:- OF ALASI<A T E X A C: 0 ;'"' THE CUI',,F;:ECTE:I) AF:']::~: FOR i S"-5 3:,~, .,0-029-20626 :,~. .... -',~- T I.'! IF m?.. [']. F;.'. F'. I::' .... f".. 'f' !::'... D. A F' I :'~ F-' [3 R t 4 -2:3 I $ 5 (') -n,., ,.') ~;', -"~,~. ~:".., "-~, '5 .... ,' , ARC(] ALASKA, INC. F'.O. BOX 100360 ANCHORAGE, ALASKA 995 i t) DATE' 7-t0-89 REFERENCE' ARCO CASED HOLE FINALS i -25 6/23-24/89 Z~-t 6-i 4-89 :~ ~' 6-2 -89 S-S4 6-i $-89 S-S4 6-i 9-89 4-t 9 6-i 5-89 4-3 i 6- i 4-89 9-i 6 6-J 8-89 i i -i 6-i 6-89 i i -24 6-i 7-89 i 3--6 6-23-89 i 4--27 -6-25-89 i 4-37 6-26-89 i 4-38 6-23-89 i 6-9 6-22-89 LEAK I)ETECTION PRODUCTION F'ROF'I I_E F'R. ODUCTI ON PROFILE PRODUCTION F'ROF£LE F'ZT$ I NJI:'C'FI ON PROFILE TEMF' INJECTION PROFILE F'RODUCTION PROFILE PRODUCTION F'ROFILE INJECTION F'RfiFILE PRODUCTION -PROFILE F'RODUCTION PROFILE PRODUCTION PROFILE PRODUCTION F'ROFILE ' "' I -,' PLEASE SIGN AND REFiJRN THE A1-TACHED COPY RL;N i, RUN i, 5' RUN i, 5' RUN t, 5' RUN i, 5" RUN i, '5' RUN i, 5' RUN I, ~' RUN i, 5' RUN ~ , S' RUN i , 5' RUN t , 5' RUN i , 5' RUN t, 5" RUN i, 5' AS RECEIPT OF DATA. CAMUO C A ~,~ C 0 CAMCO CAMCO CA~-,iCO CA~,~CO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO RECEIVED BY ~ALLY HOF'FECKER ~ ED __ 'I'RANS~- 89.86 CENTRAL FILES CHEVRON D' &-H ~ ..... ':::'"' " EXTEN£IO~ EXPLORATION EXXON.- ' MARATHON:'.. MOBIL - '"' P.H I L L :[ P $ 1' F'B WELL FILES R & D B F'X S!'AI'E OF ALA~'KA I'EX~CO ARCO ALASKA, INC. '~' F'.O. BOX JOO3&e ANCHORAGE, ALASKA 995J0 REFERENCE: ARCO CASED HOLE FINALS ~i-7 .... 2-5-89 3-J. 2-9-89 3-26 2-J -89 4-3 2-t 0-89 4-8 2-J 0-89 4-28 2-J J-87 5- J 2 2-2-89 t 1-;~ J-2~-87 COLLAR/PERF :NOISE LOG COLLAR/PERF PERF RECORD SPINNER SURYEY SPINNER SURVEY COLLAR/PERF PDK/CNL OVERLAY .. RUN J, 5" RUN 1, 2" RUN ~, 5' RUN J, 5' RUN ~, 5' RUN t, 5' RUN ~, 5' RUN t, 5' F'LEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. HL$ SCH HL$ SCH ' OTIS OTIS HLS ATLAS RECEIVED BY ~" HAVE A NICE DAY! SALLY HOFFECKER TRAN$ ~8?~',ij'& .. APPROVED'~ DISTRIBUTION CENTRAL FILE2 CHEVRON D&M EXTENSION EXPLORATION EXXON MARATHON .... MOBI'L 'PHILLIPS F'B WELL FILES R & D SAF'C STATE OF ALASKA ...TEXACO ARCO AL. AI.'KA: INC. F', 0, BOX i ,3'~36':') /~'% ANCHORAGE: ALASKA 995i. DATE ' i -'~3-89-. REFERENCE' ARCO CA~ED HOLE FINALS i-3 t-4-89 PRODUC,'TION PROFILE RUN i, t-6 i-5-89 PRODUCTION PROFILE RtJN i i-i 4 i-9-89 PITS RUN i , t-2t i-7-89 PRODUCTION PROFILE 'RtJN t, i-~.'') i-8-89 PRODUCTION F'ROFILE RUN i 3-t t'~..-29--88 PRODUCTION PROFILE RtJN i 3-i(~ i2-29-88 INJECTION PROFILE RUN i 3-25 i'2-3i-88 F'RODUC, TION PROFILE RtJN 1, 5-3 i-5-87 PITS RUN i 5-i'2 i-2'-89 PRODUCTION PROFILE RtJN t, 9-4 i,.,. 3()-88 F'RODtJCTION PROFILE RUN 9-3t i2-3e-88 PRODUCI'ION PROFILE RUN i, i i -i :5 i 2--28-88 LEAK DETECTION RUN I , i i -t 5 i -t -89 LEAl,'; DETECTION RU~.. -- 'i ql r~ i2-9 i 7-.89 FRODIJ~,TION F'ROFILE ._ RUN 2, t2--2'~ i-8-89 INJECTION PROFILE RUN t i~--6 i-6-89 INJECTION PROFILE RUN i, i S-Se i-i i -89 PRODUCTION RUN PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIPT OF' DATA. 5" 5' 5" 5" 5' 5" 5' 5' 5' 5' 5' 5' 5" CAMCO CAMCO CAMCO CAMCO C A M C 0 (]AMC(] CAMCO CAMCO CAMC[) .'..,AHCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO $' f..~ i--t RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER AT0-i529 TRANS ~89~4~ AF'R'ROVED._.t~___ DISTRIBUTION CENTRAL FILES CHEVRON D & M EXTENSION EXPLORATION EXXON MARATHON MOBIL PHILLIPS F'B WELL FILES R & D SAF'C S'T'A'T'E OF ALASKA TEXACO ARCO AL. ASKA, · .,/ F',~O· BOX t00:360 ANCHORAGE, ALASKA 995~ DATE: 9-30-88 RE:FE:.KLNCF: ARCO C;A.S'ED FIOLE F'INAL..S --te -22 s- t :3-4 3....20 :3-22 3-..~. r :5-..:3 5-..~ 6-.t~ 7 .... t :3 9-9 t 5-.9 i 5-.i OA J 5'-'J 2 J 5-'25 J6-4 J 6-'J2 J 9-J 0--88 9.-26-88 9-27-88 9-2:3.-88 9 .... J -88 9-:3-88 9-2-88 9-t -88 9-2-88 9-9-88 ~.'-~-88 ~'-4-88 ~--23-88 9-~---88 9-2t -88 9-2t -88 9-- J 4.-88 ~--':3-'88 ~.-20-88 9 -. 2 - 88 9 - 5 - 88 9-J 0-88 9"'~ J -88 I NJEC'II" I ON F'ROF:' I LE PERF RECORD AMENDMENT TO ACBL.. OF 5-'t8-82 F:'FC F:'I'~:OI)UCI'I ON F:'ROF I L..E INJEC'i'ION F'ROFILF- F-'RCJI)UCTI ON F:'ROFI L.E F'RO DUC T I ON PF;'.OF T LE P R 0 D LJ C T I 0 N F' R 0 F I L.. E F:'R[)DUCT T ON F'ROFILE F'ROI)UCT I ON F'R(:)F I L.E F"[ l'S COL. L. AR/F'ERF' F'RODUCTION F'ROFiLE P R 0 D LJ C T I 0 N P R {:} F I L. E ..... P 0 $ l' - $ T i M · VERT I LOG MAGNEL. OG F:'RODUC-I"ION F'ROF"rL~ F'RODUCI'ION PROF'ILE COMF:'L.L::TI ON RF:'CORD C 0 I.. [. A R GAMMA RAY F'I '¥$ F'I 1'$ PI_EASE SIGN AND RE'¥URN '¥Ft~ ~'~"[(]IV]~ D)F'Y AS RECEIP'T OF RE:CE:IVEI) BY ........................................ Q.CT...uZ,--1988 HAVE A NICE DAY! ,S'A L..L Y HOFF:'FCK E:R A'FO-t 529 .Oil & Gas Cons. C;ummission TRANS ~:88598 !~ A P P R 0 V E I) ............................................................. D I £' i' R I 8 U T I 0 N RUN RUN RI. JN RLJN RUN RLJN I:;:IJN RUN RUN RUN RUN RLJN RUN RLJN RUN RUN RUN RLJN RUN RUN RLIN RUN RtJN RLJN t, 1, t, 1, 1, t, t, t, t, 1, 2, t, 1, t, 1, t, 1, 1, 1, DATA· 5" 5" 5" 5" 5" 5' 5" 5" 5" 5" 5" .5 ' 5" 5' 5" 5" 5" .5" 5" 5' 5" CAMC;O SCH ~. AI'LAS'"~ A'I' I_ A~.,.,,~' CAMCO (.;AMC(] CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO ATL. AL~' CAMCO CAMCO A'I'I_A:'~ A T L A,.V CAMCO CAMCO SCI.J ATL. A,S' CAMCO CA~i{JU CAMCO CAMCO CE:NI'RAL F'I L. Ei:$ ..,HI:VRON l) & M '"' EX'FENS I (lIN E. Xl-. LUF;,'A T ~ ON 'Ir E: X X O N MAI:;,'A THON '.' MCJB I L. · ,,-'"' P FI 1 I_ L :[ F:' $ F'B WELl_ FILE,S' R & I) .-,,,I '1 '"~ ..,, A F t., ~: .S'I"ATE: O1":' AL. ASKA · .'"' TEXACO ARCO ALASKA, INC. ~-'~ P.O. BOX t80360 ANCHORAGE, ALASKA 995t8 DATE: 9-~ 6-88 REFERENCE: ARCO PRES'SURE DAI'A 3-~ 9-~ --88 BHP--FLOWING GRADIENT CAMCO J--~.~ 9-i -88 BHP--FL. OWING GRADIENT CAMCO PWDWJ-t 9.-5-88 BHP--$'FATIC GRADIENT CAMCO PLEASE S'IGN AND RETURN I'HE ATTACHED COPY AS' RECEIF'T OF' DATA. CENI'RAL FILE£ CHEVRON I) & M EXTENSION EXRLORATION EXXON MARATHON MOBIL. PHILLIPS F'B WELL FILES R & D SAF'C &'I'ATE OF' ALA~'KA TEXACO ~ ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RE;GUMPLm~TIUN tirol-Uti, AHU ~ Classification of Service Well 1. Status of Well OIL I~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 75-75 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20187 4. Location of well at surface 9. Unit or Lease Name 2017' FSL, 664' FWL, Sec.11, T10N, ELSE, UN Prudhoe Bay Unit. At Top Producing Interval 10. Well Number 1297' FNL, 1491' FEL, Sec.10, T10N, R15E, UN :~-1 At Total Depth 11. Field and Pool 1137' FNL~ 1583' FEL~ Sec.10~ T10N, R15E, UN , Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6, Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 61'I ADL 28328 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband.115.Water Depth, if offshore 16. No. of Completions 2/21/76 3/14/76 4/10/76,I N/A feet MSL 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. Directional Survey 20. Depth where SSSV set 21. Thickness of Permafrost 10030'MD/9250'TVD 9908'MD/9134'TVD YES [~ NO [] 221:~' feet MD 1900' 22. Type Electric or Other Logs Run DIL, GR/Sonic, FDC/CNL_. CBL/VDL. CCL, Gyro.. Vertilog 23: ...... CASING., LINER AND, CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 9b,# H-I;N .~,l~'~ ~n' R,~ P=a ~" 300 SX PF l! 13-3/8" 72# ~N-~O .~,,,-f ?7~n, !7-!/2" 5~00 ~× PF !!, Top .~eb ?,/~20 =x PF cmt 9-5/8" 47# L-RO/~OO-q5 .~,,r-f qc~R7' !~_-!/4" !000 sx ¢~.~SS C &' !05 :; PF I! · 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) ' 7"/'5½,, 9133 ' 9018 ' "1 · 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. , DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED , N/A See attached I. . . 27. PRODUCTION TEST . Date First Production I Method of Operation (Flowing, gas lift, etc.) June 1977 ..........I Fl.owing .............. Date of Test Hour~ Tested PRODUCTION F~OR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAs-oIL RATIO 7,30-77 .... 2.1 TESTPERiOD ..~1~ ~ 891.7 ~;~_z; 2.ct ~.o_Rn/~... Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL G~t-/~I~FY-API (corr)' - ' press. 1079. 0 24-HOUR RATE ~1~ 1.0191 7376 34r 27.0 28. COP E DATA . . . Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None · , * NOTE: Perforated well 4/18/77. Perforations added 11/5/84, 11/27/85, & 11/5/87. Workover performed 4/11/88. · . " (Dani ) TEMP3/WC105 , Form 10~407 Submit in duplicate~, Rev. 7-1-80 CONTINUED ON REVERSE SIDE 29 3O. 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. Top Sadlerochit 9403' 8651 ' N/A Base Sadlerochit 9911 ' 9137' · 31. LIST OF ATTACHMENTS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~('~)/~/)< ? 5~,(_.~J.~/)~7[_) Title A.~sociaf'_~_ Fnnlnmc, r 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 WELL COMPLETION OR RECOMPLETION REPORT AND LOG DS 3-1Cont'd. Item 24 - Perforations' Perforated w/4 spf 9404' -9501' MD 9525'-9561' MD Perforated w/1 spf 9572' MD 9582' MD 9602' MD Perforated w/1/6 spf 9622'-9658' MD Perforated w/4 spf 9671 '-9696' MD 9728' -9742' MD 9788'-9813' MD 8652'-8744' TVD 8768'-8802' TVD 8813' TVD 8822' TVD 8841' TVD 8860'-8895' TVD 8907',8931' TVD 8962'-8975' TVD 9019'-9043' TVD TEMP3/WCIO5a ARCO AI...A,.~K A , P., Ii., .BOX F~'.F..FF:R'F:N.r.:I~!:: AR'CO £:A.~ED HFli..F.". F'I'N~I ~ [":!::: N T 1~'~ ! .. !:: ]' ! ..1!..". ~' .,,.'"' CFIF'VF: .ON IF. X Y, !.".1 N HARATI4I'IN :~ HOB T I... STATE OF ALASKA f'-", ALAS~_. OIL AND GAS CONSERVATION COMN .,SION 'REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate. [] Pull tubing Alter Casing [] Other I~x WORKOVER 2. Name of Operator ARCO A1 aska_~ I n~, 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2017' FSL, 664' FWL, Sec.ll, TION, R15E, UM At top of productive interval 1297' FNL, 1491' FEL, Sec.lO, TION, R15E, UM At effective depth 1169' FNL, 1565' FEL, Sec.lO, TION, R15E, UM 5. Datum elevation (DF or KB) RKB 61' 6. Unit or Property name Prudhoe Ba~/ Unit 7. Well number 3-1 Feet 8. Approval number ~-I~R 9. APl number 50-- 02e-?nlfl7 At total depth 1137, FNL~ 1583' FEL~ Sec.10~ T10N~ R15E~ UM 11. Present well condition summary Total depth: measured 10030'MD true vertical 9250'TVD Effective depth: measured 9908 'MD true vertical 9134'TVD feet feet feet feet 10. Pool Prudhoe Bay Oil Pool Plugs (measured) None Junk (measured) None Casing Length Size Conductor 80' 20" Surface 2690' 13-3/8" Production 9957' 9-5/8" Cemented Measured depth 300 sx PF II 80'MD 5400 sx PF II & 2720'MD Top job w/320 sx PF cmt 1000 sx Class G & 9987'MD 105 sx PF II True Vertical depth 80 ' TVD 2720 ' TVD 9208'TVD 12. Perforation depth: measured 9404'-9501', 9525'-9561' 9671'-9696', 9728'-9742' 8652'-8744', 8768'-8802' 8907'-8931', 8962'-8975' true vertical Tubing (size, grade and measured depth) 7"/5-1/2", L-80, tbg w/tail @ 9133' Packers and SSSV (type and measured depth) FB-1 pkr (~ 9018' & Bal-0S SSSV @ 2212' Stimulation or cement squeeze summary N/A Intervals treated (measured) Treatment description including volumes used and final pressure , 9572 ' -9608 ', 9622 '-9658 ' , 9788 ' -9813 ' , 8813 ' -8847 ', 8860 ' -8895 ', , 9019'-9043' 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Inj. ection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Workover Wel 1 History) Daily Report of Well Operations t~ Copies of Logs and Surveys Run [] 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85(~ Title Associate Engineer Date 4'Z7-E~ (Dani) 5W03/71 Submit in Duplicate ARCO Oil a,,d Gas Company ~)aily Well History-Final Relx)rt Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or wall is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test Is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" torm may be used for reporting the entire operation if space is available. J Accounting cost center code District I St at~LK ARCO Alaska, Inc. I County or Parish NORTH SLOPE Field ILease or Unit IWell no, PRODHOE BAY FIELD I ADL: 28328 DS 3-1 I Auth. or W.O. no. ITitle AS2076 I WORKOVER AP:]:: 50-029-20187 Operator A.R.Co. W.I. [Total number of wells (active or inactive) on thisI Icost center prior to plugging end I ARCO 22. 0000 Jabandonment of this well Spudded or W.O.AcC~..pTbegun Date 03/19/88 /IH°ur 0930 II Prior status If a W,O, Date and depth as of 8:00 a.m. Old TD 04/12/88 ( 2 TD:10030 PB: 9908 SUPV:RS Complete record for each day reported WESTWARD RIG i RIG RELEASED MW: 8.5 SEAWATER TEST TBG ADAPTER AND HANGER TO 5000 PSI. SHEAR OUT SOS PLUG AT 3400 PSI. SET BPV. RELEASE RIG AT 1200 HRS 4/11/88. DAILY:S54,181 CUM:$1,292,116 ETD:S1,292,116 EFC:$1,331,000 New TD Released rig Date Classifications (oil, gas, etc.) Type completion (single, dual, otc.) Producing method Official reservoir name(s) Potential test data RECE!v D _, , ~ . ,~aska Oil & Cas Oo~,s ' : JKInd of rig Well no. Date Reservoir Producing Int.erval OII or gasTest time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected The above is correct Signature Date ITitle A~TE ENGINEER AR3B-459-3-C INumber all dally well history forms consecutively as they are prepared for each well, iPage no. Dlvldon of AtllntlcRk=hfleld~plny ARCO Oil and ~as Company Daily Well History--Interim Instructions: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District JCounty or Parish IState ARCO Alaska, Inc. ~ NORTH SLOPE I AK Field ILease or Unit I PRUDHOE BAY FIELD DS 3-1 t, omplete record for each day while drilling or workover in progress WESTWARD RIG 1 04/09/88 ( TD:10030 PB: 9908 SUPV:RS Date and depth as of 8:00 a.m. 04/10/88 ( TD:10030 PB: 9908 SUPV:RS 21) 22) 04/11/88 (21) TD:10030 9908 SUPV:RS POH W/8-1/2" MILL MW: 8.5 SEAWATER CIRCULATE OUT GAS & PUMPED SWEEP BELOW EZSV RETAINER. RIH F/9347'-9792'. BREAK CIRC. & MILLED JUNK AND FILL F/9792'-9896'. CIRCULATE HI-VIS SWEEPS. FOLLOWED WITH CLEAN SEAWATER. POOH WITH 8-1/2" MILL. DAILY:S35,314 CUM:$1,032,872 ETD:S1,032,872 EFC:$1,331,000 RIH W/5-1/2" TUBING MW: 8.5 SEAWATER CONTINUED POH WITH DP. LD BHA. PICKED UP BAKER FB-1 PACKER & TAILPIPE. RIH ON 3-1/2" DP. SPACED OUT & SET PACKER @ 9010' (WESTWARD RKB). SHEARED OFF & TESTED PKR TO 2500 PSI. POOH LAYING DOWN DP. INSTALLED 7" RAMS & TESTED. MAKE UP SEAL ASSY & RIH. DAILY;S31,277 CUM:$1,064,149 ETD:S1,064,149 EFC:$1,331,000 NIPPLE UP TREE MW: 8.5 SEAWATER/DIESEL CAP RIH WITH 5-1/2" & 7" TUBING. STING INTO PKR. TEST SEALS. SPACE OUT. INSTALL HANGER. FREEZE PROTECT TUBING AND ANNULUS W/140 BBLS DIESEL. LAND TUBING. TEST TUBING TO 3000 PSI. INSTALLED BPV. ND BOPE. NU TREE. FB-1 PKR @ 9018', TAIL @ 9133', BAL-OS SSSV @ 2212' DAILY:S173,786 CUM:$1,237,935 ETD:S1,237,935 EFC:$1,331,000 Iwell no. The above is correct For form preparation and dj~tributlon see Procedures Manual SeaSon 10. Drilling, Pages 86 and 87V IDate ITitle ~.- ~Z -<~ AS80~A~ ENGIINEER AR3B-459-2-B INumber all daily well history forms consecutively as they are prepared for each well. IPage no. ARCO Oil ah,_ .;as Company Daily Well History--Interim Instructions: This form is used durin~ drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil string until completion. District Field ARCO Alaska, Inc. ICounty or Parish 1State NORTH SLOPE AK Lease or Unit DS 3-1 PRUDHOE BAY FIELD Date and deptll as of 8:00 a.m. 04/02/88 ( TD:10030 PB: 9908 SUPV:JS O4/03/88 ( TD:10030 PB: 9908 SUPV:JS 04/04/88 ( TD:10030 PB: 9908 SUPV:JS 04/05/88 ( TD:10030 PB: 9908 SUPV:JS 04/06/88 ( TD:10030 PB: 9908 SUPV:JS O4/07/88 ( TD:10030 PB: 9908 SUPV:RS 04/08/88 ( TD:10030 PB: 9908 SUPV:RS Complete record for each day while drilling or workover in progress WESTWARD RIG I .6) .7) 8) SPACE OUT HYD CUTTER MW: 8.2 OBM CUT 9-5/8" CASING @ 2384'. TOOK GAS KICK. BUILD 8.2 PPG OBM. SPEAR AND RECOVER FULL FISH. TIH TO CUT CASING @ 2396'. DAILY:S41,502 CUM:$565,195 ETD:S565,195 EFC:$1,331,000 TIH WIH DRESSING SHOE MW: 8.4 OBM SPEAR AND RECOVER FISH. WORK OVER 9-5/8" CASING STUB 15'. TEST LAP. TIH WITH SIZING AND DRESSING SHOE. DAILY:S35,025 CUM:$600,220 ETD:S600,220 EFC:$1,331,000 POOH LD 9-5/8" CASING MW: 8.3 OBM TIH. DRESS 9 -/8" CASING STUB @ 2394'. CIRC HOLE. RUN 9-5/8" CASING PATCH AND ECP. CIRC ARCTIC PACK. ENGAGE PATCH. PATCH SLIPS. APPARENTLY NOT HOLDING. WORK SEVERAL TIMES. CIRC OUT ARCTIC PACK. POOH WITH 9-5/8" CASING STRING. DAILY:S141,714 CUM:$741,934 ETD:S741,934 EFC:$1,331,000 PREPARE TO CUT 9-5/8" STU MW: 8.3 OBM LD 9-5/8" CASING. MU CASING PATCH. RIH W/TRI-STATE PATCH. PATCH SLIP WOULD NOT HOLD. POOH WITH 9-5/8" CASING. PREPARE TO CUT 4'-6' OFF STUB. DAILY:S45,607 CUM:$787,541 ETD:S787,541 EFC:$1,331,000 TESTING PATCH MW: 8.30BM/SEAWATER CUT STUB @ 2401' AND RECOVERED. DRESSED NEW STUB. RUN, ENGAGE & TEST CASING PATCH. HEAT USED ARCTIC PACK TO 150 DEGREES. PUMPED 150 BBLS ARCTIC PACK, DISPL W/170 BBLS OBM. DAILY:S32,789 CUM:$820,330 ETD:SS20,330 EFC:$1,331,000 CIRCULATING MW: 8.5 SEAWATER TESTED 9-5/8" CASING TO 2000 PSI. TESTED 9-5/8" X 13-3/8" ANNULUS TO 2000 PSI. NIPPLE DOWN, PICK UP BOP'S & 9-5/8" CASING SPOOL. SET CASING SLIPS W/100,000# OVER STRING WT, CUT CSG, INSTALLED 9-5/8" PACKOFF & NEW FMC GEN III TUBING SPOOL. TESTED PACKOFF TO 3800 PSI. TESTED BOPE TO 5000 PSI. PICKED UP 8-1/2" MILL & RIH TO 2663'. DISPLACED OIL-BASED MUD WITH SEAWATER. RIH TO 6613'. WELL FLOWING, CIRCULATE OUT GAS. DAILY:S33,511 CUM:$853,841 ETD:S853,841 EFC:$1,331,000 CIRC. OUT GAS MW: 8.5 SEAWATER CIRCULATE OUT GAS THROUGH CHOKE. CONTINUED RIH WITH MILL TO 9232'. WASHED & REAMED FILL F/9323'-9344'. MILLED 9-5/8" EZSV. CIRCULATE OUT GAS THROUGH CHOKE. DAILY:S143,717 CUM:$997,558 ETD:S997,558 EFC:$1,331,000 IWell no. The above is correct For form preparation an(fY/distribution see Procedures Manual~ction 10, Drilling, Pages 86 and ~ Date ]Title 4 AR3B-459-2-B INumber all daily well history forms as Ihey are prepared for each well. consecutively JPage no. ARCO Oil anQ ~as Company Daily Well History--Interim Instructione: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name In describing work performed. Number all drill stem tests sequentially. Attach description of al cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2) on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil siring until completion. District Field ARCO Alaska, Inc. ICounty or Parish tStetL NORTH SLOPE Lease or Unit DS 3-1 PRUDHOE BAY FIELD Date and depth as of 8:00 a.m. 03/27/88 ( TD:10030 PB: 9908 SUPV:DL/RS 03/28/88 ( TD:10030 PB: 9908 SUPV:RS 03/29/88 ( TD:10030 PB= 9908 SUPV:RS 03/30/88 ( TD:IO030 PB: 9908 SUPV:RS 03/31/88 ( TD:10030 PB: 9908 SUPV:JS 04/01/88 ( TD=10030 PB= 9908 SUPV:JS Complete record for each day while drilling or workover in progress WESTWARD RIG 1 POOH. PICKED UP CASING SPEAR & ATTEMPTED TO POLLED CASING HANGER & CASING. DAILY:S37,027 CUM:$259,435 ETD:S259,435 EFC:$1,331,000 REV. ARCTIC PACK W/DIESEL MW= 0.0 SEAWATER RIH WITH CASING CUTTER; RECUT @ 2341'. POH. MU SPEAR, STABBED INTO CASING & LIFT HANGER TO FLOOR. ATTEMPT TO CIRC. ARCTIC PACK, POH LAYING DOWN 9-5/8" CASING. MU 12-1/4" BIT & 13-3/8" CASING SCRAPER & STAGE INTO HOLE, REVERSING ARCTIC PACK WITH DIESEL. DAILY:SS6,420 CUM=$345,855 ETD=S345,855 EFC=$1,331,000 MU WASHPIPE & MILL SHOE MW= 8.5 SEAWATER POH WITH CASING SCRAPER. MU WASHPIPE BHA. TIH. WASHED FROM 2341'-2368'. POH. CHANGED WASHPIPE SHOE. RIH. TAGGED METAL @ 2368'. POH. MU NEW SHOE & WASHPIPE. DAILY:S28,708 CUM:$374,563 ETD:S374,563 EFC:$1,331,000 BACK OFF CSG STUB MW= 9.5 SEAWATER LAY DOWN WASHPIPE. PU NEW SHOE AND WASHPIPE AND RIH. WASHOVER 9-5/8" CASING FROM 2368'-2385'. REVERSE CIRCULATE. POOH. LAY WASHPIPE. MU BACKOFF BHA. RIH ON 3-1/2" DP. RU PUMP FOR BACKOFF. DAILY:S27,784 CUM=$402,347 ETD:S402,347 EFC=$1,331,000 POH W/CSG DRESSING TOOL MW: 8.5 SEAWATER BACKED OFF 9-5/8" CASING. POOH WITH BACKOFF TOOL. RIH WITH SPEAR & SPEARED CASING STUB. ROTATE LEFT 4 REV. POOH WITH STUB. RIH WITH CASING CUTTER & SPEAR. CUT CASING @ 2378'; SPEAR SAME & POH. RIH WITH 9-5/8" CASING DRESSING TOOL. DRESSED OFF CASING STUB & POH. DAILY:S28,918 CUM:$431,265 ETD:S431,265 EFC=$1,331,000 PREPARE TO SET CSG PATCH MW= 8.6 SEAWATER/DIESEL RIH WITH RTTS & FO FINGERS. FINGERS UNABLE TO GO INTO THE 9-5/8" CASING. CHANGED OUT FINGERS. RIH. ATTEMPTED TO OPEN FO - WOULD NOT OPEN. TESTED CASING TO 2000 PSI. POOH. RAN 2370' OF 9-5/8" CASING. CIRCULATE ARCTIC PACK. DAILY:S41,116 CUM:$472,381 ETD=S472,381 EFCt$1,331,000 CUT 9-5/8" CASING STUB MW: 8.6 SEAWATER/DIESEL ATTEMPT TO SET 9-5/8" CASING PATCH. PATCH WOULD NOT HOLD. POOH. LEFT PATCH 1JT 9-5/8" CASING AND EXTERNAL CASING PACKER IN HOLE. RIH ATTEMPT TO BACKOFF FO @ 2393' . WOULD NOT BACKOFF. BLEW SEALS IN BACKOFF TOOL AFTER SEVERAL ATTEMPTS AT MAX BACKOFF PRESSURE. POOH. RUN HYDRAULIC CUTTER. BEGIN CUTTING 9-5/8" CASING STUB. DAILY:S51,312 CUM=$523,693 ETD:S523,693 EFC:$1,331,000 Well no. The above is correct IDate ITille 4--Z~-~ ASSOCIATE ENalNEER AR3B-459-2-B Number all daily well history forms as they are prepared for each we . consecutively IPage no. ARCO Oil a,,d Gas Company Well History - Initial Report - Daily Instruotions: Prepare and submit the "Initial Report" on the first Wednesday after a well is spudded or workover operations are stetted. Daily work prior to spudding should be summarized on the form giving inclusive dates only. District ICounty. parish or borough ~.CO Alaska, Inc. I NORTH SLOPE Field ILease or Unit PRUDHOE BAY FIELD I ADL: 28328 Auth. or W.O. no. ITitle AS2076 I I Sta~K DS 3-1 JWell no. API: 50-029-20187 Operator ARCO Spudded or W.O. begun IDate ACCEPT I 03/19/88 Date and depth as of 8:00 a.m. 03/20/88 ( TD=10030 PB: 9908 SUPV:JS/JH 03/21/88 ( TD:10030 PB: 9908 SUPV:JS/JH 03/22/88 ( TD:10030 PB= 9908 SUPV=JS/JH 03/23/88 ( TD:10030 PB:9908 SUPV:.JS/JH 03/24/88 ( TD:10030 PB: 9908 SOPV:DL/RS 03/25/88 ( TD:10030 PB: 9908 SUPV:DL/RS 03/26/88 ( ) TD:10030 ~B: 9908 SUPV:DL/RS The above ia correct Complete record for each day reported WESTWARD RIG i I ARCO w.i. IHour I 22,0000 IPrior status if a W.O. I 0930 SPEAR 5-1/2" TBG M~: 8.6 SEAWATER MOVE RIG TO DS 3-1. ACCEPT RIG AT 0930 HRS, 3/19/88. CIRC WELL W/8.6 SEAWATER. PUMP HEC PILL DO~N ANNULUS. SET BPV. ND TREE. NU BOP'S. TEST BOP'S. KILL WELL. PULL BPV. SPEAR 5-1/2" TBG. DAILY:S56,047 CUM=$56,047 ETD=S56,047 EFC=$1,331,000 POH MW: 8.6 SEAWATER SPEAR AND PULL STUCK HANGER. SHUT OFF TBG ABOVE PBR. PULL 125 K OVER STRING WEIGHT TO FREE STUCK TBG. CONTROL WELL. POOH W/5-1/2" TBG. DAILY=S39,021 CUM:$95,068 ETD:S95,068 EFC=$1,331,000 POOH W/ FTA ~1 MW: 8.6 SEAWATER SERVICE RIG. POOH LD 5-1/2" COMP ASHY. PU FTA ~ 1. RIH. PU 3-1/2" DP. ENGAGE FISH. PULL SAME FREE. POOH W/ FISH. DAILY:S28,950 CUM=$124,018 ETD=S124,018 EFC=$1,331,000 POOH W/ PKR MW: 8.6 SEAWATER POOH. LD PKR, K-ANCHOR, 5-1/2" TBG. LD FISH AND FTA ~ 1. PU FTA ~ 2. RIH. WASH FILL F/990' TO 9063'. MILL OVER PKR. PULL PKR FREE. POOH W/ PKR. DAILY=S30,405 CUM=$154,423 ETD=S154,423 EFC=$1,331,000 WASH OVER FILL & JUNK MW: 8.6 SEAWATER .TOH WITH PACKER. CIRCULATE BOTTOMS UP - BUBBLE UP AFTER 500 STROKES. CIRC. THROUGH CHOKE. CONTINUED TOH WITH PACKER. NO FISH. ASSUME THAT IT IS IN TOP FO. TIH WITH SAME. TAGGED PACKER. SET GRAPPLE. TOH WITH FTA #2 & PKR. LD PACKER, TAILPIPE, & FTA ~2. MU NEW BHA ~3. TIH ON 3-1/2" DP. TAGGED FILL @ 9765'. PU KELLY & WASHED OVER FILL AND JUNK. DAILY: $30,551 CUM: $184,974 ETD=S184,974 EFC:$1,331,000 POOH W/ PKR SETTING TOOL MW: 8.6 SEAWATER WASH TO 9893'. POOH. RIH W/ FO CLOSING TOOL AND RTTS. CLOSE FO'S AND PRESS TEST TO 2000 PSI. POOH. RIG W/9-5/8" EZSV ON 3-1/2" DP. SET AT 9347'. TEST CSG TO 2000 PSI. PULL UP 30'. MIX AND PUMP 3000 ~ SAND ON TOP OF EZSV. CIRC. POOH. DAILY:S37,434 CUM=$222,408 ETD=S222,408 EFC=$1,331,000 ATTEMPT TO PU 9-5/8" HANG MW: 0.0 SEAWATER POH WITH RUNNING TOOL. RU ATLAS W/L & TIH WITH 8-1/2" GAUGE RING & JUNK BASKET. RIH WITH VERTILOG CASING INSPECTION TOOL. RD. RIH WITH DP TO 2500', DISPLACED SEAWATER WITH . Signature ~j ~fl~~ ,~ II Date For form preparation and/flletributlon, see Procedures Manual, ~tlction 10, Drilling, Pages 86 and 87~ AR3B-459-1-D INumber all dally well history forms aa they are prepared for each well. consecutively Page no. XEROX TELECOPI ER F F,: C' f"l 295 ; 3-2]-88; ?:09 P~4; * ' Pipe Ram~ .,. ... i. Biin8 Rams .... · , 0 907276?542 . Controi~ ~ H~s t,ar Ramo.=~ ~ Blinds swicch. Upper LOBBY' ~t-~ Ball Type .... Ins a.d Pressure ~._~ 0 Valves No £1an~"s ~ p - Adjustable Chokes ..... ':" ..... ' ;i?'~'',*. 'f ;~ ,',.;': ,,';'?":"~'¢~?$¢'~.:""'t'¢* ~'5 :' '~;~ U:~;:' ,4 '" "' '" ~ .... ~' '" ~e air or,Re lacemer~ of .,.,...,. ¢, · ~ ;~/' ,. . , Cotillion,, offica' notified ..".,'..,. · ...... , .., ..... ....;, , - .' w , ,, ., ~ : , .,, &~.-.~ . , ~ , .. , , - - .... .:' ',r.; ,,. }'. .;;.., ,., .... ~,,,.,~q 'h ...... ,,(',','~,,,~ ;,-:?,:,,,_ . ~ .... ... .,.:~-?~y ~ .... · ..... ~: ....... r..* ..... ¢ '¢ .:.,. :. · t. ~¢ ,.... ..... :..,~ ';'.'..'...<,~,. ~',;, ..:: ..:.',.*~,'/¢;'r'~ '~,.; ~ .... " '~.?;~.., ;. :,:,..,',, :~ :,.: .... . ,.,.,,......... Distribution . .,f~ '~, ,... , ,$ .... ,~ ...-, ,,.- .}.'.: .,.~ ':,,,., ....: '. o=2g,::t:.-'~ AOS660 ,,.:, .~ .. '.,.... 'v.: ~' ,..,:. ,~ ..... . ' ~c -.Supervisor TOTAL F'. 1 ARCO AI...A'-~KA., .T. NC,. P.~O., Box ~o~e ANCHORAGE'., AI...A,.~KA 995t (-) DATE: 5-7-88 RF..FERFNC['7.: ARCO PRE,.~,.~UI;'E DATA ~'~ ,,?- 74-E!8 BHF'-XTAT T £~: ~R'AO I F'NT '7-t~'~ 2-~.--~8 BHF .....S"T'AT];C GRAOIFNT F'I...EA,~E .S'TGN ANO RETURN TNE A'TTACHEO COPY AY REEE'EF'T flF DA'FA., r: A M (': fZ. AM£:I] r':AMEf~ I:;'t:!:CE'[VED BY ................................................... HAVE A NTf.'.'.E DAY! F:, I::.i",! T R A/.. F .T.I...F_ ~;' f'.'.HFTV ROM EXTt.-.-.N,~TON F'XF'I. I']RA'f'I'riN E¥¥RN MARATHON M 0 B I I... F'H :[ I.. I.. I F' .'.'..' F'R WFI I F'[I I:;.' ,t, .~'A F' fT. STAT.r-.: (".il:." AI..AS,'KA ARCO AI._A2KA, EN~, P.O., BOX t0036A ANCHORAGE. AI..AYKA 995iQ DATE' ~-t~-~ REFERENCE' ARCO CA~ED NOI...E FTNAI i -t a t t -25/?,4-87 '~_-z i i -.~. f)-gl7 3-2 ~ i-5-~7 S-4 t 2-t 6/5 ~-~7 n-i 2 i t -t't -R7 5:8 ti-26-~7 7-6 i t-7'-~'7 7-i ~ t t -&-~7 -.3 . . 7-i 7 ~ t -,~-~7 ~.~ ..... I 6-t t 7-t P. OI..! .AR P. OI.. t AR'/F'ERFRR'ATTON Chi .. I...A R' / F'E R F- F!R A T T ON C Ell.. I. A~'/F'ERFF1RAT l F1N C nl...I._A R/PERF[!RAT T F1N ILO!.. ! AR/F'FF='FFIR'ATTF1N P,l-] I ..!.AR /F'F R F F1K'A T T_ ~OI.. I., AR/F'FK:FF1K'AT T F1N C, OI ..I .AF</PF RF-FI~'A T T mN C nl..t... AR'/P .E~'F n RAT I ON CE. II...[ ,AK' /F'F RE-ORA T T P. F1 t.. I.., AR/P .FTRFOK'A T T ON chi.../ Cfll .t.. A~'/PE-~'FF1RAT l' F1N F:fll. I. AR/F'ERFOF;:AT I r!N F'I..EA,~E .SIGN AND R~~- ' ' ' HAVE A N I :; C .' .~ ~as!'~ 0it & Gas Cons. "-~mm,s~l~,,.: ...-. ~%hsrage F'~f;GY BENNE~TT ...~... Tt-;.'AN.~ ~88t 6.7 AF'F'ROVED D T ,..2 T R T f41 IT T FIN RI.IN RI. IN RI IN RI tN R! IN RI.IN RI.IN R'I IN R!IN RI.JN I-~' I.IN RIIN RI.IN R I.!I',l R!IN DATA, :~ F;E N T I-~'AI... I::' T !..I.=.: 2 ¢ P H T I...I... I P,S" ~ C!qF.."JR(]N F'P, taEl.. I... FTI.. F:,.," D & M R ,S T) ~'~' EYTEN,~TrlN ..... FXF'I .F1RATT FIN -,-'"-.., ~ EX¥1]N "~ ..... ..gTATF.. OF AI._A,%KA PtARA'¥NON $ TFXAP. F1 ' MO~.T.! -,~ ..... ,'"""'~. STATE OF ALASKA ~ ALASK,. ,.)IL AND GAS CONSERVATION COMM,..~ION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate J~ Pull tubing/~ Amend order [] Perforate ~ Other/~ 2. Name of Operator ARCO Alaska, Inc, 3. Address P. O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 2017' FSL, 664' FWL, 5ec.11, TION, R15E, UN At top of productive interval 1297' FNL, 1491' FEL, Sac.lO, TI.0N, R15E, UN At effective depth 1169' FNL, 1565' FEL, 5ec.10, TION, R15E, UN At total depth 1137' FNL, 1583' FEL, 5ec.10, TION, R15E~ UN 11. Present well condition summary Total depth: measured 10030 'MD feet Plugs (measured) true vertical 9250 ' TVD feet 5. Datum elevation (DF or KB) RKB 61 ' 6. Unit or Property name Prudhoe Ba~/ Unit 7. Well number 3-1 feet 8. Permit number 75 -75 9. APl number 50-- 029-2o187 10. Pool Prudhoe Bay 0il Pool None Effective depth: measured 9908 'MD true vertical 9134'TVD Casing Length Size Conductor 80 ' 20" Surface 2690 ' 1 3-3/8" Production 9957 ' 9-5/8" feet Junk (measured) No ne feet Cemented Measured depth 300 sx PF il 80'MD 5400 sx PF II 2720'MD 1000 sx Class G & 9987'MD 105 sx PF II ~ueVerticaldepth 80'TVD 2720'TVD 9208'TVD Perforation depth: measured 9404'-9501 ' 9671 '-9696' true vertical 8652 ' -8744 ' 8907 '-8931 ' Tubing (size, grade and measured depth) 5-1/2"/4-1/2", N-80, tubing w/tail @ 9192' Packers'and SSSV (type and measured depth) Baker 5AB pkr (~ 9053': Cameo Ba]-O RR.~V ~ 711~' 12.Attachments , 9525'-9561' , 9728'-9742' , 8768'-8802' , 8962'-8975' 9572 ' -9608 ' 9788 ' -981 3 ' 8813 ' -8847 ' 901 9 ' -9043 ' Description summary of proposal , 9622'-9658', , 0 ! 1 $8 /',laska Oil & Gas Cons. C0mmbs Anchorage Detailed operations program ~ BOP sketch~ 13. Estimated date for commencing operation March 13, 1988 14. If proposal was verbally approved Name of approver Date approved 1511 hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~(~~_ ~ Title Associate Engipeer Commission Use Only ( J G ) Conditions of approval Approved by Notify commission so representative may witness [] Plug integrity [] BOP Test [] Location clearance Approved Copy Returned ORIGINAL SIGNED BY LONNIE C. SMITH Commissioner Form 10-403 Rev 12-1-85 Date SA3/67 I "°. the commission Date Submit in triplicate PBU DS 3-1 WORKOVER PROCEDURE OBJECTIVE: Retrieve the existing parted 5-1/2" tubing and Baker SAB packer and PBR. Acidize and squeeze the entire perforated interval. Run a Verti- log casing inspection log across the 9-5/8" casing. Cut, pull and replace the leaking 9-5/8" BTC casing above +2376'MD with new 9-5/8" Mod-BTC casing. After successfully testing the new 9-5/8" casing and drilling out and testing the squeezed perforations, 7" LTC 8rd IPC x 5-1/2" Mod IPC tubing wi th GLMs and a permanent packer will be installed. Production will reperforate the well after the rig moves off. 1) MIRU workover rig. Circulate seawater through tubing part at the PBR. 2) Set BPV. ND, NU, test, retrieve BPV. 3) Pull and LD 5-1/2" tubing. 4) Retrieve tubing stub and PBR seal assembly. 5) Retrieve PBR and K-anchor. Mill and recover SAB packer. 6) RIH w/DP. Acidize and cement squeeze entire perforated interval. POOH. 7) Run Vertilog casing inspection log. 8) RIH with RTTS and test squeeze to 2500 psi. Circulate 2400' diesel cap. POOH. 9) RIH, mechanically cut 9-5/8" casing at +2350'MD. 10) Pull 9-5/8" casing. 11) Roundtrip 13-3/8" scraper and 12-1/4" bit to top of cut. 12) Test Arctic pack to 2000 psi. 13) RIH, back off 9-5/8" casing at 2376'. POOH. 14) RIH, recover 9-5/8" casing stub. POOH. 15) Run new 9-5/8" Mod-BTC casing with external casing packer. 16) Circulate oil base fluid into 9-5/8" x 13-3/8" annulus. A~he~ge 17) Screw into 9-5/8" BTC casing with new Mod-BTC. 18) Test 13-3/8" x 9-5/8" annulus to 2000 psi. 19) Set 9-5/8" external casing packer. -2- 20) ND BOPs, install slips, cut casing, install packoff, NU and test BOPs. 21) Test casing and squeeze to 2500 psi. 22) RIH and clean out to PBTD at 9908'. 23) Test squeezed perfs to 1000 psi. 24) RIH with 9-5/8" packer and tailpipe on DP, set, POOH and LDDP. 25) Test 9-5/8" casing and packer to 2500 psi. 26) RIH with 7" x 5-1/2" tubing and GLMs. 27) Freeze protect well, ND, NU new 7" tree, test, release rig. BHP = 3830 psi @ 8861'TVD (8.31 ppg EMW) Workover fluid = 8.5 ppg seawater LWK/22 2/24/88 ANNULAR PREVENTER 6 PIPE RAMS 5 BLIN4D RAMS TUBIN6 HEAD 1. 13-3/8" CASING HEAD 2. 9-5/8" CASING HEAD 3. 5(..)00 PSI TIJB!NL~ HEAD - RA~ 4 13-5/8" 5000 PSI BLIND 5. !3-5/8" - 5000 PSi PIPE PAM$ 6. 1.3-$/8" - [5000 PSI ANNULAR ACCUMULATOR CAPACITY TEST I. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPEP LEVEL WITH HYDRAULIC FLUID. 2 ASSURE THAT ACCUMULATOR PPESSURE tS 3000 PSi WITH 1500 PSI DOWNSTREAM OF THE PEGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF, 4. RECORD ON THE IADC PEPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST FILL BOP STACK AND MANIFOLD WITH ARCTIC DIESEL. RETRAC ~ CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY T~r~. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT ~N WELLHEAD. RUN iN LOCk.-DOWN SCREWS tN HEAD. 3. CLOSE ANNULAR P,O. EVE,~iTER AND CHOKES AND BYPASS VALVES ON THE P'~ANIFOLD. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 10 MINUTES. 5. INCREASE P~ESSURE 70 2500 PS~ AND HOLD FOR 10 MINUTES. BLEED TO ZERO PSi OPEN ANNULAR PP. EVEr,~TE~' Ar,iD CLO'~E TOP SET OF PIPE RAM'~ !HCREASE PRESSURE T~ 5,?.~;C, ;~'S.~ A~iD HOLD FOP I0 MINUTES. 'LOSE VALVESD~RE~TL~ ,~,:,. ~tAi'l OFCHC)K. ES ~:.LEED ~"3"'~T~'',,,,--, ,- .PRESSURE ~'~ ZERO ~i T"3 T~,:T ,,' ..... ,~ ~o . ,.~u',~ TEST~EMAINING L:HTE'STE~ MANIFOLD VALVES. iF ANY. '..V!TM 5U00 PSI UPSTREAM OF VALVE WITH ZERO PSI DOWNST~'.EAM. ~'~:~ SYSTEM TO ZERO PSI 9 OPEN P!FE ~Ai'!S. 5AC~..OFF PUNNING JT AND PULL OUT OF HOLE, ~ ..... ~ T~T ~'", ~'" ,~ ~,~r,~ , ~ , ~v..,0 PSI FOR ~0 MINUTES. BLEED CLOSE ['~ ,~'~D AND ~ .... w~ -, TO L_RU ~Si 10. OPEN 5LINDRAMS AND~ECOVEP. TESTPLUG. MAKESUPE MANIFOLD LINES ARE =IJLL OF ARCTIC D~E'SEL AND ALL VALVES A~.E SET IN THE ~ ~ TE?TSTANDP!PE VALVES TO 5000, PSI. "- :EST KELLY ;-p,,.-~-c. a~.n . ~ ~'' _ . ............... .~ INSIDE BOP T05000~ WITH KOOME'". _. ~ErO~n -:'ST ~NFO~MAT ON '"'~': E'.':.,::,WOUT PREVENTER ~E~7 ~c,:,~"' - -' AND SEf4D TO DR',LLiHG ! 4 PEQFOPM ...... u(.,~' ..... ~'LETE BOPE TES,.~ ONCE A WEEK AND FUNCT~ONAL~ ' OPERATE ~O¢'E DAILY. dG NOVEMBER 21, I'.~$~! STATE OF ALASKA '~'-". ALA~,~A OIL AND GAS CONSERVATION CON,.~,ISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] Alter Casing [] Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, AK 99510 4. Location of well at surface 2017'FSL & 664'FWL of Sec, At top of productive interval 1297'FNL & 1491'FEL of Sec. At effective depth 11, TION, R15E, UM 10, TION, R15E, UM At total depth 1137'FNL & 1583'FEL of Sec. 10, T10N, ELSE, UN 5. Datum elevation (DF or KB) 61' RKB Feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number 3-1 8. Approval number 7-R?{') 9. APl numb~9_20187 50-- 10. Pool Prudhoe Bay 0il Pool 11. Present well condition summary Total depth: measured true vertical 10030 feet 9251 feet Plugs (measured) Effective depth: measured 9908 feet true vertical 9134 feet Junk (measured) Casing Length Size Cemented Measured depth True Vertical depth Conductor 80 20" 300 sx PF 11 Surface 2720 13-3/8" 5400 sx PF 11 Production 9986 9-5/8" 1000 sx Class G & 105 sx PF 11 80' 80' 2720' 2720' 10030' 9251' Perforation depth: measured true vertical ,SS 9404-9481', 9481-9501', 9525-9561', 9671-9696', 9728-9742', 9788-9813', 9572-9608', 9622-9658' 8591-8665' 8665-8684' 8707-8742' 8846-8870' 8901-8914', 8958-8982', 8752-8786', 8800-8834' Tubing(size, grade and measured depth) ~" 12.6#, N-80 tail to 9192' 5½", 17#, N-80 to 9065'; ~2 , MD Packers and SSSV(type and measumd depth) Bal-O SSSV @ 2115'MD, SAB Packer @ 9053'MD 12. Stimulation or cement squeeze summary Intervals treated (measured) Treatment description including volumes used and final pressure 13. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl 8800 11800 5400 9100 12200 5600 Casing Pressure Tubing Pressure 82O 830 14. Attachments Daily Report of Well Operations [] Copies of Logs and Surveys R.u__n ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed 2~d~~ Form 10-404 Rev. 12-1-85 (;T/~T17/2_1 Title Operations Engineerin~ Manager /3, Flin~Y,f. Date /y~//r~ ~. Submit in Duplicate DS 3-1 Daily Report of Well Operations Add Perfs 11/5/87 MIRU PT equipment to 3500 psi. OK. SI well. RIH w/gun #1, Jumbo Jet charges loaded @ I shot/6 ft, 120° phasing. Open well, tag PBTD @ 9813'ELM. Shot 9652' & 9658'. Shot 9640' & 9646' S.I. well. POH. ~11 shots fired. RIH w/gun #2, Jumbo Jet charges loaded @ i shot/6 ft, 120° phasing. Open well. Shot 9622', 9628', 9634'. S.I. well. POH. All shots fired. RIH w/gun #3, Jumbo Jet charges loaded for selective fire. Open well. Shot 9602' Shot 9572' and 9582'. S.I. well. POH. All ~hots fired. O.O.H, open well, RD. Well turned over to DS-3 Operator. STAT17/3-1 ,/", STATE OF ALASKA '-", AL~',, .~ OIL AND GAS CONSERVATION CO,,..,'IISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re*enter suspended well [] Alter casing [] Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order [] Perforate I~ Other [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360~ Anchorage, AK 99510 4. Location of well at surface 2017'FSL & 664'FWL of Sec. 11, T10N, R15E, UM At top_ of productive interval 1297'FNL & 1491'FEL of Sec. 10, T10N, R15E, UN At effective depth At total depth 1137'FNL & 1583'FEL of Sec. 10~ TION~ R15E~ UN 11. Present well condition summary Total depth: measured 10030 feet Plugs (?easured) true vertical 9251 feet 5. Datum elevation (DF or KB) 61' RKB feet 6. Unit or Property name ', Prudhoe Bay Unit 7. Well number 8. Permit number 75-75 9. APl nur~r 5O-- -20187 10..Pool Prudhoe Bay Oil Pool Effective depth: measured 9908 feet Junk (measured) true vertical 9134 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 80 20" 300 sx PF 11 Surface ___ 2720 13-3/8" 5400 sx PF 11 Production 9986 9-5/8" 1000 sx Class G & 105 sx PF 11 80' 80' 2720' 2720' 10030' 9251' Perforation depth: measured 9404-9481' 9481-9501' 9525-9561' 9671-9696' 9728-9742' 9788-9813' ' true vertical 8591-8665' 8665-8684' 8707-8742 8901-8914' , 8958-8982' Tubing (size, grade and measured depth) 5½" 17#, N-80 to 9065'; 4½" 12 6# N-80 tail to 9192'MD ' ' ' ' Packers and SSSV (type and measured depth) Bal-O SSSV @ 2115'MD, SAB Packer @ 9053'MD 12.Attachments Description summary of proposal [] Detailed operations program [] BOP sketch 13. Estimated date for commencing operation October 27, 1987 14. If proposal was verbally approved Name 'of approver Date approved 15. I hereb~ certify that the foregoing is true and correct to the best of my knowledge Signed 2~,~~?~ Title Operations Engineering Manager Date //~/~ ~'/~/~' Conditions of approval CommiSsion Use Only so representative may witness I Approval Notify[] Plug commission integrity [] BOP Test [] Location clearanceI No. ,~ ~ ~ ~ ),~~ ~eturned Approved by ff~~-~ Commissioner Form 10-403 Rev 12-1-85 STAT17/3-1 S. A, D~gert (263-4290) by order of the commission Date Submit in triplicate ARCO Alaska, Inc. proposes to add perforations in DS 3-1 for selected intervals within the Sadlemchit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operations. Proposed Perforation Intervals: 9572-9608' MD (36') 9622-9658' MD (36') Ref: BHCS 3/13/76 ARCO Alaska, Inc. P.O. Box t00360 Anchorage, Ataska 995~0 DATE: March t4, t986 REFERENCE' ARCO Cased Hole Final. 4-6 t 2-t 4-85 F'DK tO0 Run t-40 t 4-25-84 TDT Run J 5' 3-~ 2-~ J-86 Gamma Ray J-~ ~ t 2-25'85 CFS Run ~ 5' 3_~ j ~ 2-26-85 CFS Run 3-~5 ~ -9-86 Spinner/GR/F[uid ID Run 3-24 ~-~ ~-85 CNL/Hu ~ i-SpaCe R~n 3-24 ~e-~-8~ Epilog Lac Analysis Run ~ 5' 3-2~ t-8-86 Sp inner/GR Run 3-28 ~8-38-85 TDT Run ~ 5" DA Otis Go Go Camco DA DA Camco $ch F'[ease sign and return the attached copy as receipt of data. Rece i red By_ HAVE A NICE DAY! Irma CarLin ATO-'1427F TRANS ~86'i 95 DI2TRIBUTION Phi [[ip~ F'B WeLL Fi Les R & D $oh i o State-of-' AlaSka'- · Texaco P,~ O. ,o :.,° o x t (-) ¢, S 6 0 A'r~ c h o ¥° :°..'~ .c.] e, A L ~'..'~ ~ k a .r..!::, "i: .¢..', fn c ,.':) i'i 4. j...,. ,. i':.. E:.' i. I. ":.'" P'i C: i" .:':'i 'i" i...":i l'i Ci A T' 0 ..... i ,:!. 2 9 F:' Alaska Oil' & Gas Cons. Commission .... i:':.'..,':':'., ~'-~;F ..... ., ..;:. ,.:, Anchorage i ":.; '!t' ':Y ~,,J .i.') ]: ,? T F;.: :i; B U T ]: O ,'.....' Chevron Mob i L '- · :'.,."~ ... t. ;i) & i"~ :'::..:.., E'xp Lora't' ion 5;e'r'v ice:=-.- F'h i L L i --Ex"teri..s i o¥'1 E:xi:~ Lora'l: i o¥; F'r u. dh,:::,e E x x o'r'~ ~:;.." &: Ge t -I: y Sob i o N a 'r' ,'..'i 't' h ,::.,. 'n £ 't a t e o f A La:5'ka ARCO Alaska, Inc. Prudhoe Bay L..=~ineering Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 263 4248 Donald F, Scheve Regional Operations Engineer December 5, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton: Re: D'S 3-1 DS 3-15 Permit No. 75-75 Permit No. 79-92 Enclosed are "Subsequent" Sundry Notices and Well Completion Reports detailing work done on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/JEB/la Attachments CC: SOHIO Alaska Petroleum Co. File P1 (DS 3-1) W1-3 PI(DS 3-15)Wl-3 P1 (DS 3-1) W4-3 P1 (DS 3-15) W4-3 RECEIVED AlasKa Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc. la a Subsidiary of AtlantlcRIchfleldCompany STATE OF ALASKA ALASKA O~L AND GAS CONSERVATION COMMISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~ OTHER [] Name of Operator ARCO Alaska, Inc. Address P.O. Box 100360, Anchorage, Alaska 99510 LocationofWell(Surface) 2017' FSL S 664' FWL of Sec 11, T10N, R15E, OM (Producing Interval) 1297' FNL & 1491' FEL of Sec 10, T10N, R15E, UM (Total Depth) 1137' FNL & 1583' FEL of Sec 10, T10N, R15E, UM Elevation in feet (indicate KB, DF, etc?) 61' RKB 6. Lease Designation and Serial No. ADL 28328 7. Permit No. 75-75 8. APl Number 50-029-20187 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 3-1 11. FieldandPool Prudhoe Bay Field Prudhoe Bay 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 ~[ 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). Began perforating operation on 11/5/84. RU perforating unit, pressure tested equipmnent. RIH w/gun 91, shot interval 9481-9501' MD (4 spf). Shut in well, POOH, all shots fired. Secured well, RD. Ref: BHCS 3/13/76 ECEIVED ~'~-r' g!a~,-,,a o~i & ~as Cons. CommissJofl Anchorage 14. I herebv,~rtify that the f,~regoir)~is true and correct to the best of my knowledge. Signed .~~ ~_ ._ Title Regional Engineer The space below for Commission use Conditions of Approval, if any: Approved by By Order of COMMISSIONER the Commission Date Submit "Intentions" in Triplicate Form 10-403 Rev. 7-1-80 and "Subsequent Reports" in Duplicate STATE OF ALASKA ALASK. OIL AND GAS CONSERVATION ,,~MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL I~ GAS I-I SUSPENDED I--I ABANDONED [] SERVICE [] .. 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 75-75 3. Address ' 8. APl Number P.O. Box 100360, Anchorage, Alaska 99510 50- 029-20187 4. Location of well at surface 9. Unit or Lease Name 2017'N & 664'E of SW Cr Sec 11, TION, R15E EM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1297'S & 1491'W of NE Cr Sec 10 T10N,R15E UM DS 3-1 At Total Depth 11. Field and Pool 1137'S & 1583'W of NE Cr Sec 10~ T10N~ R15E~ UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) 1 6. Lease Designation and Serial No. Prudhoe Bay Oil Pool 61' RKBJ ADL 28328 i'2. D'ate Spudded2/21/76 13. Date T.D. Reached3/1/+/76 14' Date C°mp" Susp' °r Aband' I 15' Water Depth" if °ffsh°re I 16' N°' °f C°mpleti°ns/+/10/76 N/A feet MS L 1 17. Total Depth (MD+TVD) 1B. Plug BackDepth (MD+I'VD) 19. Directional Survey 20. Depth where SSSV set I 21. Thickness of Permafrost IO030'MD 9250'TVD 9908' MD 9134'TVD YES ~ NO [] 2207 feet MDI 1900' (aDorox.) '52. Type Electric or Other Logs Run - ' DIL; CR/Sonic; FDC/CNL; CBL/VDL~ CCL 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLESlZE CEMENTING RECORD AMOUNT PULLED 20" 9/+"Vetc( H-/+O RO'B~]. Pad ~2" Ann,-nw ~AA ~w I~TT 13-3/8" 72"Butt~ ess MN-80 2720' 17~" 5/+00 sx PFTT 9-5/8" /+7"Buttless L-R0 998~' 12%" ~AO sx ~1~ C~ ~m~ & SO0-C~ 2nd Stm. w/~O5 .~x PFII 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) * 9/+81 - 9501' MD w//+ SPF 5% 9192 9053 9671 - 9696' MD TVD of perfs: 9728 - 97/+2' MD 8665 - 8982 26. ACID, FRACTURE, CEMENT SQuEEzE, ETC. 9788 - 9813, MD DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED *added on 11-5-8/+ w/ /+ SPF 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 1977 Flowing 6ate of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SI;~E ~ GAS-OIL RATIO 7-30-77 2.1 TEST PERIOD I~ 891.7 6/+5./+ 2.9 3/+°-80/6~ 72/+ "l~low Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 1079 0 24.HOUR RATE I~ 10191 7376 3/+ 27° , 28, CORE DATA Brief descriptiOn of l ithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. None RECEIVED I)!f;C 0 6 Alaska Oil & Gas Cons. Commission Anchorage Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE :. -. ":GEoEOGic-i~.A'RKERs.. 'i.., ''T :.. :~..;'.':~;"'-..~ . ' : FORMATiON TE:STS ;: NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 9403' MD 8651' TVD Base Sadlerochit 9911' MD 9137' TVD 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ..... Title Regional Engineer 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 CC.,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS DRILLING WELL [] COMPLETED WELL~ OTHER [] 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, Alaska 99510 4. LocationofWell (Surface) 2017' FSL & 664' FWL of Sec 11, T10N, R15E, UM (Producing Interval) 1297' FNL & 1491' FEL of Sec 10, T10N, R15E, UM (Total Depth) 1137' FNL & 1583' FEL of Sec 10, T10N, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. 61' RKB J ADL 28328 12. 7. Permit No. 75--75 8. APl Number 50- 029-20187 9. Unit or Lease Name Prudhoe Bay Unit 10. Well Number DS 3-1 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 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 10-407 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). ARCO Alaska, Inc. proposes to add perforations on DS 3-1 for selected intervals within the Sadlerochit Sand from the Prudhoe Bay Unit. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The SSSV will be installed at the conclusion of the perforating and clean-up operation. Proposed Perforation Intervals: ~84~__4' - 9501' MD (20') $ Ref: BHCS 3/13/76 Subsequent Work Reported RECEIVED JUN2 8 Alaska Oil & Gas Cons, Commission Anchorage 14. I hereby,~7.~rtify that the,,,foregoing is true and correct to the best of my knowledge. The space below for Commission use Date .... ~/~q/~¢~z/ Conditions of Approval, if any: IRIGII~A[ $1G~t£0 8T [0t~IE C. SMITH Approved by CQMM ISSIONER APProved Copy By Order of the Commission Form 10-403 Rev. 7-1-80 Submit "Intentions" in Triplicate and "Subsequent Reports" in Duplicate ARCO Alaska, Inc. Post Office E~,.., 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 June 18, 1984 Mr. C. V. "Chat" Chatterton Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Dear Mr. Chatterton: Re: DS 3-1 DS 3-3 DS 3-5 DS 3-14 DS 3-15 Permit No. 75-75 Permit No. 76-39 Permit No. 76-57 Permit No. 79-82 Permit No. 79-92 Attached are "Notice of Intention" Sundry Notices for work proposed on the above-mentioned wells. Very truly yours, D. F. Scheve DFS/WT/lmh Attachments cc: Sohio Petroleum File P1 (DS 3-1)Wl-3 File PI(DS 3-5)W1-3 File PI(DS 3-5)Wl-3 File PI(DS 3-14)Wl-3 File P1 (DS 3-15)W1-3 ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany ARCO Alaska, Inc. Post Office Bo Anchorage. Ala=..a 99510 Telephone 907 277 5637 June 20, 1983 Reference: Arco Cased Hole Finals D.$. 1-10~ 5-12-83 D. $. 2-6-' 4-14-83 D. $. 3-1'~~'~ 5-8'83 D.$. 5-9-' 5-5-83 D.S. 5-16~ 5-12-83 D.S. 7-7A ~ 6-4-83~' 6-4-83~" ~ ~ DlS. 11-6-- 5-7-83 .~ ~ D.S. 12-16~~ 2-21-83 ' 1 6-10-83 5-24-83 5-29-83~ CH CNL CH CNL CH CNL CH CNL CH CNL CPL/Producibility w/Listing CPL/Volan w/Listing JIR~LOG printout CH CNL ACBL/VDL/Sig/GR C, BL ~ D.S. 15-6/ 5-6-83 CH CNL Run 2 5" Sch Run 4 5" Sch Run 3 5" Sch Run 2 5" Sch Run 3 5" Sch 5" Sch 5" Sch Sch Run 2 5" Sch Run 1 5" DA Run 1 5" Sch Run 2 5" Sch Run 4 5" Sch Run 3 5" Sch Run 3 5" Sch Run 9 5" Sch Run 11 5" Sch Run 1 5" Otis Run 2 5" Sch /please sign and return the attached copy as receipt of data. Kelly McFarland ATO-1429D Trans. # 376 NORTH GEOLOGY R&D DRILLING PHILLIPS SOHIO MARATHON CHEVRON DISTRIBUTION EXXON -'~.~c~., GETTY /2.. (~,~ '~' t.~~ STATE OF ALAS~ 9ALLAS CAROLINE SH[TH ARCO Oil and Gas~-~mpany Post 0" f,~c= .,x 380 Anchorage, Alaska 99510 Te!ephone 907 277 56S7 July 25, 1980 Reference: ARCO Magnetic Tapes .D.S. 1-14 5/15/80 Tape #60517 5/21/80 Tape #60522 2/3/80 .Tape #60234 6-2 5/19/80 Tape #60524 se sign and return the attached copy as receipt of data. K. J. Sahlstrom North Engineering ~ 1 GEOL. --~-a"E~ STAT TEC ! J-~iLR. J TRANSMITTAL #484 R & D Mobil Drilling : Getty Eng. Manager Phillips D & M Sohio Geology Marathon State of Alaska ~' ~evron ARCO C, il an(I Gas Company ~s 3 D~vislon ot AtlanhcR~ch/ielctCompany Post Oil? i'~× 8GO Anchorn.~ ,C, laska gD510 .. _ Te!ephene gO7 277 5637 June 30, 1980 Reference: ARCO Cased Hole Logs C:OMM~ , t ENG ._'~..._ ...... ~-~NG Z~..i~ --t.L? [NG:'t.Te .._ J STAT TEC I' STAT TEC --i ............ CONFER: [FtLF:' D.S. 2-6 D.S. 6-2 D.S. 6-3 D.S. '9-4 eS~s5-15 e sign of data. 5/18/80 , CNL Run 2 5" 5/18/80 " Run 2 5" 5/21/80 " 'Run. 2 5" 4/20/80 " Run 1 5" 5/19/80 '~;:':" Run 2 5" 5/17/80TM" Run 2 5" 5/21/80 C~L Run 3 5" 6/22/79 Continuous Flow Run 1 5" and return the attached copy as receipt K. J. Sahlstrom North Engineering TRANSMITTAL #412 DISTRIBL~ION North Geology Exxon R & D Mobil Drilling Getty Eng. b~nager Phillips D & M Sohio Geology Marathon State of Alaska Qevron ARCO Oil and Gas Company is a Division of AtlanlicRichficldComp,.lny Alaska Region O,fl~,. x 360 Post ' "- , Anchorage~'.aska 99510 Telephone 907 277 5637 Reference: EncloseS' are the following logs: D.S. f~4-9 Continuous Flow 5" D.S. #7-1 CBL/VDL 5" D.S. #7-1 CNL/GR 5" D.S. #7-1 CNL 2" & 5" together · D.S. f~l-4 Gamma Ray Neutron 5" Long Spacing Gamma Ray Neutron 5" Short Spacing ~- Production Log 5" NGI #10 Production Log 5" Run 2 2" NGI f~10 Production Log · /~ Run 1 Please sign and return the copy as receipt of data. Sincerely, V.G. Reimers North Engineering TRANSMITTAL #447 AtlanticRichfieldCompany North American Producing Division North Alasl trict Post OfficeX'~ 360 Anchorage, Alaska 99510 Telephone 907 277 5637 August 16, 1978 Reference: Enclosed is a 5" VDL-GR-CCCL (5") on Drill Site .#3-1. Please sign and retu_,~n the copy as receipt of data. Sincerely, V.G. Reimers North Engineering Transmittal #411 AtlanticRichfieldCompany North Ame~ Producing Division North Alas ~ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 February 16, 1978 Mr. Hoyle H. Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' DS~_-2~(31- 14- DS 3-3 (13- DS 3-4 (ll- DS 3-5 (31- DS 3-6 (11- DS 3-7 (11- DS 3-8 (31- 10-10-15) 10-10-15) 11-10-15) 13-10-15) 14-10-15) 14-10-15) 15-10-15) 15-10-15) Permit No. 75-75 Permit No. 76-24 Permit No. 76-39 Permit No. 76-51 Permit No. 76-57 Permit No. 76-60 Permit No. 76-53 Permit No. 76-73 Dear Sir' Enclosed please find a Completion Report for the aboVe-mentioned wells. Very truly yours, Frank M. Brown District Drill ing Engineer /am Attachments SUBMIT IN ~. jATE* -~___~t STATE OF ALASKA <S~eoth~rin- st ructions on reverse side OIL AND GAS CONSERVATION COMMITTEE WELL C~MPLETION OR RECOMPLETION REPORT AND LOG* _ la. TYPE OF WELL: Oil, 6As W ELI, W ELL DR Y Other b. TYPE OF COMPLETION: NEw ~] wonK[-] ~zzr- [~] m.c~ [~ m~. ['-] Other pr~,a,,,-~nq BACK RESVR. -- OVER EN ~ ',-* ~,~ ~ ' WELL 2. NAME OF OPERATOI% Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.0. Box 360, Anchoraqe, AK 99510 4.LOC~IrON Or WELL (Report location clearly and in accordance with any State requiremet~ts)* At surface 2017'N & 664'E of SW cc Sec ll, TION.;RI5E, UM At top prod. lnterval reported below 1 ' ~t t2t97d&~& 1491'W of NE cr Sec 10, T10N-R15E, UM 12. PERiViIT N'O. 1137'S & 1583'W of NE cc Sec lO, TION-RI5E, UM 75-75 ~. o.~r seu,on>2_21_76 114' DATE T'D' RF-''~2CHED''li' DATE CO'lVIP SUsP Ol:~ ABAN]D'3-14-76 J 4-10-76 i1~' IKL'EVATIONS (DF' RKB]t~j~'~' '~rc)'t17' ELJgV' CA$INGIIEAD28' Pad elev.16lff RKB~ ~ INTERVALS DRILLED BY IO,030'MD, 9250'T~D 9908'MD, 9134'TV~ aow~N~,single ~OT OOLS " None 9.9,. PRODUCING INTERVAL(S), OF TI'tlS CO,1VIPLETION--TOP, BOTTOM, NAME (NIT) AND 'I'VD)* 23, %,VAS DIRECTIONAL !SURVEY MADE Top Sadlerochit 9403'MD 8651'TVD Base Sadlerochit 9911'MD 9137'TVD ~Yes ~. AP1 NU1VLF_.E/CAL CODE 50-029-20]87 6. LF-ASE DESIGNATION J~ND SERIAL NO. ADL 28328 '7, IF IND1AZq, AJLLO'i"r.:E OR TRIBE NANIE 8. UNIT,F~I.M OR LF~kSE NAME Prudhoe Bay Unit · 9. WELL NO. DS 3-1 (31-10-10-15) 10. FIELD AND PdOL, OR WILDCAT pr~dhn¢_ Ray Fio. ld. Prudhoe n. sec.. T., a., M.,-(~o.ro~ ao~ 1 Pfol OI~JEC'rlVE) Sec 10, TION-R15E, UM 24. TYPE ELECTEIC AND OTHER LOGS RUN DIL fiR/Sonic, FDC/CNL, CBL/VDL, CCL ! 25. CASING RECORD (Report all strings set i:~ well) ]..3-3/8" 17~"n,i~;;d~iNi~nl--~7~n' _ ' J ~7-~/~"J ~h-~'v-~ ;~' -~+ J 9-5/8" [47{ ButtreJsMN-80l 998~' 1 i2-17 "/ T000 ~ Cla~ ~'"fmt [ .~ is00-951 ' [ [ 2nd sta~e w/105 sx PI, II I LINER[ I ~~CO~ ~ 27. ~I'UBING RECOP~ 5-1/2" 9!92' q0~*' I ii 28. PE~OR.AT1ONS OP~ TO PRODU~ON (interval, size and nurnber) 29. ACID, SHOT, FilACiURE, C~,IENT SQUEEZE, ETC. 9728' 9742' w/4 shots per ft. I ~,' ,'~ ~ 9671' - 9696' i I Producing ~' June 1977~ j Flowing ~__ - · -~ .~ .... ~ou~s T~ST~ 'Jc~oxE SLZ~ JPgOD'N ~O'~ O~BB~. ' '~A~CF. WAT~BB~. ' JGAS-Om ....... I I o 80/ I.~s'r ~,~,~T~ L, 2.1 134 -641 .... ; 1 891.7 I 645.4 I ~.9 i 724 ~W, ~BING IcA}mG PRESSURE iCAL~T~ OI~BBL. GA~-I~CF. WATt--BBL. ' JOl: GRAVITY-~I (CO~.) ~sa I ' ~ 12~-~ou~ a~ .I . 1079 J 0 J ~ [ 10191 J 7376 ] 34 J 270 API ...... ,A. O~SPOSm'ION Or gas (Sold, used ~or ]uel, vented, etc.) [TEST WITNESSED BY t Re i nj erred 32. LIST OFATTACHMENTS . 33. I herebycerLify that t~e foregoing and attached information is complete and correct as determined from all-available records )~~ District Drilling Engineer DATE 2-15-78 SIGNED . ~ TITLE *(See Instructions and SpaCes for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lanJs and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- merits given in cther spaces on this form and in any atlac!~mer~ts Items. 20, and 22:: If this well is completed for separatc prcdvction from more than one ~r~terval zone (multiple completion), so state ~n item 20, and in item 22 show the p~cJuc,n9 ~ntervat, or ~ntervals, top(s), bottom(s) and name (s) (if any) for only the interv~l rel~orted in ~en~ 30. Submit a separate report (page) on this form, adequately identified, for each addit,or~a[ interval to be separately produce.J, show- ing the ad~litional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well shoulJ show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). SUMMARY ()V I.'ORMA'rl 0 N 'I'~.iS'I'S INt'LLII)IN(; INTERVAL, TV-_.,CiTED. PI1E,"~tJRE DATA A._ND I:L~COVERIES OF ()IL. GAS.- aS. G I~OL,OG I C M ARKI~R~ WATER AND MUD , Top Sadlerochit 9403' 8651 ' Base Sadlerochit 9911' 9137' · · · ,,,,,, , i , , , , ,, i '1{ ., . .ir iir .... i · ~.~. AND l)g"l'EL'q'gl) SIIOW'S OW OI1,. GAS OR · .- North Alaska District ]h~gineeri.ng-. -. TO z-" "'/:'"';'~:~'" ::; ~:::~:':-: '/::'~'~:-:::'-::::;c-: .-.:.~:.~'~::~';~ :--:..' ~;:;~;~,;: ~':-.:::::>'?:~C:-;[;:~ ':: [:.~:From:. '-:" ' 'z '" -~'~ " ' "' -.- Z': .. " ": '-'':~-':>'~'""'''" :'- ' ' ' " .. ' ' '" " .... '"'.-'"":' ' ' '" ', :: ........ :"'-'-"".'-:"." l~ate: ::: ....... .'-_ , .... :.'-:- 11 N . ~ ? . . . . - ..... - < ,-~..':.'.~'- ~:.. ' .. ~.. . ....::::~):'.:~....:.-.f,Z.> ,.: :::.:4 · ?.:~.-:.-: .....:>--;: :,: :... .:::..: ..:..:'< ..:. :.....::. - . --..... ; ." - . . - ... . . .. . ...:.. ' . . . .. "--"... .- - '...-.'..:> ...~'-.: . . .-. . . Ru~ No. . :'- .... Scale· Xerox Sepia BL L~e .- . , ,,...'... ,- - ..'. "...'. '.: .- - . . . .. -. . ... .. · . '.. . ~ ...... - . ..., . n~clC~li~e~ Log ' . BHC S ' ' ' ' ' O ~ . -" . . .-- -' '-. -- BHC 'Son~clCal~pe9 - a~ma'~ay Lo~ ' .- - · ':'.' .... BHC Son~clC~a ~ Lo2 ...-- -' -.. " . ..-.. · '-':' Cal~pe~lCCL . .. ' :-:.~... _....'.:" _ __ · .. :.- ' ' Ce~ene 2on~ ~O~L "' .-. ' -. -' --- "' -Come, ate& Fo~at~on ~d.s~ty L62' ' ' ..... . _ . 'Z: . _ _ . .,_ .. ...... Compensate5 Neu~on-:o~tion. Density-~ -. -. . · ._ . Compensaee5 Neue~on Lo~ ' . '- . ..--,.. Co~e ~alys~s - Inte~al . . .'~-- ' ' - - Core' No. ' ' .. -' ' ': '. - ..... -'. .. ., "'.7' ~, Coze ~S.c~iPt~on (S~C) -.Inte~al .. ''_ ':~'...'" '."".: ,.' .... Co:e ~esc:lptioh (ConY,) - Core No. , ..... ~_ ._, '-- . " '~i~ectional Su~ey...- ~o " . · :-. S~n2le Sho~ "" . ... .. .... . ... . . . ' . ~lt~shot ' .... . .' '. '.'.. ..-' ~rlll Ste~ Test' - ~est No. ., "- "'" ' -'. , .-,. ..... · ~al Induction' Late~olog .-. ..' ..'." . , FoI~ation ~ens~t~ Log · .- _ · ~~ ~zlcc~ ~ . ~-.-c~ " .~ . .... Late:olog ' ' . .. .... '.,-~ .~:~ :. t~ .. Location Plat . . ' .. . ':: :~:,~:.:.:, ....,. ~,.- .- ~ic:olo~ - - ' .... -"' " .,.~ ~:( ~3' :''' - '~ ' '" ' " ~adlog - Inte~al ~>,'-:" - i.." '""~" ' ~', -. . . -~ ~-DIL . ,.: " .- ~"'>'~ ~ :'::~'" ," ....... . .. /. -/- . . Please ~e~ulm ~eccipt to: '~~tic ~chfield Company . North Alaska Engineering P. O. Box 360 Oi~L~~Tm T R A N S M I T T A L Date: June 6, 1977 ]From ' Well Name' J. A. Rochon~,D. R. Jackson D.S. #3-1 Transmitted herewith are the following for the subject well' Run No. Scale BHC Sonic/Caliper Log BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (~VC) - Interval Core Description (Cony.) - Core No. Directional Survey - Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog Microlog ~dlog - Interval Sample Log (A.R. C0.') - Interval Synergetic Log TVD-DIL TVD-Porosity Log .Co}l_a r T,n~ Xerox Sepia BL Line Receipt Acknowledged For' Date' Please return receipt to' P. O. Box 360 Anchorage, Alaska 99510 #466 CONi;IDENTImL DISTRIBUTED STA. TE OF ALASKA DIVISION OF OIL North Alaska District Eng .... TRANSN I TTAL 3'0' From: J. A. Rochon/p. Hellstrom. Date' May.10,.1.977 , Well .N--~=- D.S 3-1 '. C~.~pensatea Fo:r~t:/.on Da~_!_~ Long . ~- . -~ ~~~ate~ Neu~dn Log - Core ~~~ - ~te~ ' ..... Core' No.' ....... ~"' ' ~'- ' - . Core Des~iption [Cony.) - Core No. - ' - ' .. ~9~t~hot · ~~ St~'Test - Test No. ~ Induc~on Late~olog - ... ~~fion De~i~ ~ ~ _ .---._ ~~~on De~i~ ~o~S~ RaY T.ransmitted here~.,~ith are the following for the Subject well- . o · · Rum No. . : BHC Sdnic/Calipar BHC Sonic/Caliper - Ganxaa Ray-'L. og 2BHC Sonic/Gm .1.1~. Log . . ., . . "' CementCal~per/CCL' 'pg/VDL-2Bona L i-i-",: '. :'-':'-,,'-'"::' .- ". - ~ -- ,. Aaterolog ': .'- ~ - ~ Location Plat ~ . ~Iicrolaterolog .. ' "~'m 1 - -- cro-og. ' SCale Xerox . . .. - '--~r, . i t _ - , . . .._. _ . - ..... '~.' - .. ' . _. _ ~gxllog- Interval _ ~' ' : "Sample Log (A.R.Cc.)-Interwali "'-' '- .Syn. ergetic Eog 7VD-DIL TVD-Porosi~' Log ---RT-C-E I : iviAY 1 2 1977 '-' ' · . . Receipt Acknowledged For: Date: Please return receipt to: Atlantic Richfield ¢o...~pany North Alaska Engineering P. O. Box 360 -":" .... '~-~ A[:,-;t '3:" #328 , At~'anfi~RichfieldCompany North Ame,'"~.n Producing Division , North Alas~ istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 5, 1977 Mr. Hoyle Hamilton State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 j FILE: Subject' Dril 1-10-10-15) Permit No. 5-75 Drill S'?'t-e-8--~14-10-10-15) Permit No. 76-24 Drill Site 3-3 (13-11-10-15) Permit No. 76-39 D~ill Site 3-4 (11-13-10-15) Permit No. 76-51 Drill Site 3-5 (31-14-10-15) Permit No. 76-57 Drill Site 3-6 (11-14-10-15) Permit No. 76-60 Dear Sir: Enclosed please find our Sundry Notice of Subsequent Report detailing the work done on the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure RECEIVED 1'2, ' 977 i / Form 10-403 REV. 1-10~73 Submit "1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT-J' for such proposals.) 1. V~/~LLF~ GAS [~ OTHERWELL. 2. NAME OF OPERATOR Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 4. LOCATION OF WELL At surface 2017'N & 664'E of SW cr of Sec 11', TION, R15E, UM 13. ELEVATIONS (Show whether ~F, RT, GR, etc.) 61' RKB 14. Check Appropriate Box 'To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20187 6. LEASE DESIGNATION AND SERIAL NO. ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM OR LEASE NAME Prudh0e Bay 9. WELL NO. Drill Site 3-1 (31-10-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerochit 11. SEC., T., R., M.,.(BOTTOM HOLE OBJECTIVE) Sec. 10, TION, R15E, UM 12. PERMIT NO. 75- 75 )ort, or Other Data NOTICE OF INTENTION TO; SUBSEQUENT REPORT OF= FRACTURE TREAT MULTIPLE COMPLETE FRACTURE TREATMENT ALTERING CASING SHOOT OR ACIDIZE ABANDON* SHOOTING OR ACIDIZING ABANDONMENT* REPAIR WELL CHANGE PLANS (Other) Perforate (Other) (MOTEt Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE.PROPOSED OR COMPLETED OPERATIONS (Clearly state all I~rtlnent details, and give pertinent dates, Including estimated date of starting any proposed work. Began operations @ 0600 hrs. on 4/12/77. RU & tstd perf. manifold. RU & tstd BOP' to ~. Pulled dum~y valve. Ran GR/CNL/CCL from 9810' to 8700'. Perf'd intervals ~98_~_12~%~~d<JGT-1-rz~gG]~/4 shots per ft. Ran press recorder. Flowed W~l-a total o"6-f-'33'[-b~ls 'o-7~347~-4"'~]~oke w/final flowing press 990 psi @ 5016 BOPD rate. SI for buildup. Ran & set flapper valve @ 2207'. Tstd balance & control lines to 5000 psi OK. Bled press above flapper valve to 0 psi held OK. Installed & tstd tree cap to 5000 psi OK. Released well to Production Dept @ 2400 hrs on 4/18/77. RECEIVED MAY 1'21977 Division of Oil ~nd C3.s [:..n~:~.,~. :,J::~ 16. I hereby certify that the foregoing is true and correct SIGNED ~-~'~ ~ ~/~,~ ~, TITLE., Dis,trict Drill inq Enai neet DATE;. (This space for State office use) APPROVED BY CONDITIONS OF APPROVAL, IF ANY.' TITLE DATE, See Instructions On Reverse Side STATE DEPARTMEIiT OF ttATURAL RESOURCES Dtvtston of 011 and Gas Conservation TO: Hoyle Ii, Hamilt~~ Director Lonnle C, Smith ,~~/f/*~ Chief Petmle~ Engi ~n L~o.~n Thru: FROM: Petrolemn Inspector DATE : April 29, 1977 Sub-surface Safety Valve and Surface Controlled Safety Valve Tests on Arco' s DS 3-1 ..~.nday,. April ]8,J)77- I departed my ~home. at 2:15 PM for a 2:45 PM showup and-' 3:45' PM de~rtui;e 'via wi.eh flight #10g to Deadhorse. I arrived in DeadhorSe at 6.:'10 PM and' after testingSSSV and SCSV on DS 5-1, we met Lanny Burner, Petroleum engineer, at Arco base and proceeded to DS 3-1, arriving at 8:20 PM. The SSSV was open and shut in tubing.-pressure was 1400 pstg. SSSV was then closed and pressure downstream bied to 700 psig and monitored for five minutes. SCSV was then closed and pressure downstream bled to zero and monitored for five minutes. The gate valve downstream of the SCSV was then closed and the SCSV reopened, a-nd pressure attained 67S pstg. Pressure above the SSSV was then bled to zero, master valve and SCSI/ closed and well buttoned up. Tests. were concluded a t 9:10 PM. A field inspection report was prepared with the original given to Lanny Burner, a copy mailed to Bob )lines and a copy attached to this report. !~ s~ry: I witnessed successful: tests of SSSY and SCSV on Arco's DS 3-1. Cons Inspection Report Represented by Name &'NOmt~er Z:):~ ~-/ , Sari sfaC.tory :'.. ,TYPe, Inspection YeS NO ~ ' :'_I' ti~m ('. '")'~::' L°¢,a'~i.oii ;'Geiie'~a 1 (,,:) ( ) 1., We.ll S,ig.n ( ) :2:. General. H'ou.~ekee'pin'g ( ) 3. Reserve Pit-( )Open(. )filled ( ) ( ) .".::.~..~ 'Rig..' '.:..~ ..... ' .(.~,~e ~.. ,v ~ ~.v~, ,Te's.~s. (~ ( ) 5'. SUrfaCe-No. Wells (~.~ ( ) 6. S~B~:~rface~No'. 'W~I'I s (). ~ell Tes~ Data () () 7. ~e1.1 ~os. , , , ( ) ( ) 8. HRS...Obser__, , , ().() e. BS-~. , , . ,. ( ) ( ) 10..~. Bbls. Sa ti s Fact Yes .No T~,~:t's } ;( ) "Casing .set L~ ), ,( ) ) (') 18; N~.'.bt.ls~?.~:,-__,__, .'.p's.~'g' II s ( ) ' 20:.'"Drilling spool- "outlets ( )' () 21. Kill Line-( ) Ch6ck?valve .... ( ) ( ) 22. Choke .Flowline ( )HCR valve ( ) ( ) 23. Choke Manifold No. valvs flos ( ) ( ) 24. ChOkes-( ):'Remote( )POs'.(~dj~:. ( ) ( ) 25. Test Plug-(.)Hellhd( )csg.( )..none, ( ) (.). 26. Annular Preventer, PSig · . ... :i.?i.. (.').i.'Fi]nal Aban'do:n~m~nt ( ) (')~ 27'.Blind R.ams~.· .psig .. . ·" i?' (.) (") .... .l"l:'~',..:P&A.;!!Me~r..ke.r · · . '.":':'"'."'i/."'.'~' ".."'.:." ;(:)'". (.'.)'. ',..28.:;:'.Pi'p~e:-.Rams ':..: psi'g'." · '. "'.!.'..]" T."..'.. ,:.' (') ( )' 12'."'w~t'e~"'Wel'i-( ")capped('.'')p'i:u'ga'ed'i.'.( .;)..' ("'). '291.'... Ke~."iY .&,. Ke~i~=c6~k." ps.i~'..' ".... '~.' :'".:. · (..). ".( )...';..13..';. Cl;e.an.;uP .:' ..' .... 'i. i'.: ': '.' .: .".~..... '. (....,)'...' ('..).. ::...3"O.~'.::L.°.Wer.,. .',.,e..l:.i:.~,...val'.ve..' ..' ps.i:qi!il.'...' "...~,:... '.';....' "" · (:':.)"'""' (. "')'."'::' '.'"'t4?'~.:~Pa'd!"":l:..'eV~'l:ed' "..f...' -i:i .':. ......... .~..'~..:" :.'.'.'~".~" .".,'::~ i.-'(".'~""~):-'..'..:'~(:.'"~.'.)'..-':.~.-'"'~]' 3'.l-':j.!-.: $~f,e~:Y.;.::'F~.l:.o:ot~.':' v'-a.,1.'ves ~.(" ~.)B.V:.:~'?:')!D~?,t~ ~ .'....L Total ". i n spec t.~ o'n..~.bServa ~ion '..t.i me~hi~ ~'i~.:~. ,.TO.t.a 1 '..;n umbe:.r.,!'".:l;eak. S'.and 70:r" :ea.ui p'. '.fa i.l,Ur.e s "i..'O: "i..::..!. '.,..........'; ''IRe'mar'ks' ''''-~'~'1~' '.:":' i;' "~'~ :;~'"' ' '~'-]"~"':~i:~'~:~'i?.~ '. ' /i? '":' = '." '.:: I]I''.: i::''I i"]'::".' :."~":"..'i;' ?'"':.':~:'."'::'i i..'i :;...".:'.i,'i..;...'..':."...:._,_'__]. ]_ '~ ~~i~"~..' .' "'::i'.';. ;;?:,?c c :' .'.;~.: ~' '~, ~.'::....,NOt i.. fy, in..:'.'..' ,'.:.:. :.,U:~y.S,.:.r:i o;P.:..:..Wh~:'n.:r:.:!r..e a;~l~..,..ii.i:;.i. '.::. :'"':].':i,~fiisi~:e.c,t.e d':-bY...'~ :..:~~D:~:'~e~ ~~~~~~~.... ~.- ....... · . ... ........ · .... !: .'... DRILL $1~E NO. 3-1 PERFORATE AND CLEANUP RECORD AFE NO. 391395 APRIL 16 - APRIL 18, 1977 Drill Site No. 3-1 was drilled to a bottomhole location in the northeast corner of Section 10, TION, R15E, Prudhoe Bay Field, through the Sadlerochit Formation. Depths of interest are as follows' RKB Top of Sadlerochit Gas/Oil Contact (Not Present) Subsea Datum Level Perforations Water/Oil Contact Base of Sadlerochit PBTD (4/17/77)' No junk in hole Measured Depth Subsea Depth.. Zone O' (+61 ') 9402' 8589' 9392' 8580' 9624' 8800' 9671-9696' 8846-8870' 9728-9742' 8901-8914' 9788-9813' 8595.5-8982.5' 9873' 9040' 9911' 9076' 9815' 8984' LBS LBS LBS A cased hole GR/CNL/CCL log was run by Schlumberger prior to perforating, and was subsequently used by Dresser Atlas for depth correlation during perforating. The first gun run was a 25' gun which was fired from 9788-9813' M.D. The well was flowed on a 34/64" choke for five mi-nutes after firing, with 480 psi FWHP. Turbine metering equipment was not available, therefore, BFPD rate was determined by tank gauge of cumulative flow after the final gun run. SIWHP was 1010 psi. The second gun run was a 14' gun fired from 9728-9742' M.D. after flowing for five minutes on a 34/64" choke. Wellhead pressure increased from 480 psi to 580 psi after firing, which built to 1000 psi when shutin. The third gun run was a 25' gun fired from 9671-9696' M.D. after flowing for five minutes on a 34/64" choke. Wellhead pressure increased from 580 psi to 720 psi after firing. At this time, the test tank was gauged and cumulative flow was determined to be 122 BF during the previous 27 flowing minutes, yielding an average rate at this point of 6507 BFPD, with 1050 psi SWIHP. At this time, a Hewlett-Packard pressure bomb and surface console were rigged up, due to nonavailability of Amerada subsurface pressure recording equipment, and preparations were made for drawdown/buildup testing. Initial tubing pressure was 1010 psi by gauge and 1137 psi by surface readout. The well was opened to the test tank on a 34/64" choke with initial' FWHP of 700 psi at 20°F which built to 1000 psi after 30 minutes. After flowing for one hour, the well was shutin to begin pressure buildup. Final FWHP was 990 psi at 32°F. The total drawdown flow by tank gauge was 209 bbls in one hour, or a flow rate for this period of 5016 BFPD. Hewlett-Packard pressure readout showed a stable Drill Site No. 3-1 Perforate and Clean~'~Record Page 2 drawdown from the initial bottomhole pressure of 175 psi. Using these figures, the estimated productivity index is calculated to be 28.7 STB/day/psi-drawdown. Final SIWHP was 1391 psi by Hewlett-Packard surface readout. The total estimated surface volumes of reservoir fluids produced during perforating and drawdown are as follows: Cumulative oil production, STB Cumulative gas production, MSCF Average solution GOR, SCF/STB 67 50.2 750 From gradient surveys taken with the Hewlett-Packard pressure bomb, the static bottomhole pressure at the recognized subsea datum level of 8800' s.s. was 4403 psi. BHT was not recorded. RDJ 5/27/77 AtlanticRichfieldcompany North Amer,~en Producing Division North Ala~. ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 22, 1977 Mr. Hoyle Hamil ton STate of Alaska . Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject~ (31-10-10-15) --~~ ~'~'-~T~~ ( 14-1 O- 1 O- 15 ) Drill Site 3-3 (13-11-10-15) Drill Site 3-4 (11-13-10-15) Drill Site 3-5 (31-14-10-15) Drill Site 3-6 (11-14-10-15) Permit No. 75-75 Permit No. 76-24 Permit No. 76-39 Permit No. 76-51 Permit No. 76-57 Permit No. 76-60 Dear S i re: Enclosed please find a Sundry Notice outlining our plans' for the above-mentioned well. Very truly yours, Frank M. Brown District Drilling Engineer /vp Enclosure RECEIVED D~vi$1~fl of 0il llllcI Sas Oofl~ervation Form [ ~-403 REV. ~1-10-73 Submit *'1 ntentlons" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS {Do not use this form for proi3os~$ to~ rill or to dee~>en Use "APPLICATION FOR PERMIT--" for sa~ch Dro0osals.) o,- I~ GAS F-1 WELL'"-WEL~.L.J OTHER NAME OF OPERATOR Atlantic Richfield C.0..mpany ADD~S OF OPERATOR P. O. Box 360, Anchorage, Alaska 99510 LOCATION OF WELL Atsurface 2017'N & 664'E of S'R cr of Sec 11, T10N, R15E, UM 13. ELEVATIONS (Show whether DF, RT, GR, etc.} 61 'RKB Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 5,0-029-20,187 6. LEASE DESIGNATION ANO SERIAL NO; ADL 28328 7. IF INDIAN, ALLOTTEE OR TRIBE NAME 8. UNIT, FARM'O~ LEASE'NAME Prudhoe Bay, 9. WELL NO. Drill Site 3-1 (31-10-10-15.) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay - Sadlerchit 11_. SEC., T., R., M., (BOTTO/~I HOLE OBJECTIVE) Sec. 10, T10N, R15E, UM 12.' PERMIT NO. 75-75 )ort, or Other Data NOTICE OF INTENTION TO: TEST WATER SHUT-OFF ~ PULL OR ALTER CASING FRACTURE TREAT MULTIPLE C~MP~_~----TE SHOOT OR ACIDIZE ABANDON' REPAIR WELL CHANGE Pt..:NS (Other) Perfo. r.a~e SUBSEQUENT REPORT OF: WATER SHUT-OFF REPAIRING WELL FRACTURE TREATMENT ALTERING CASING SHOOTING OR ACIDIZING ABANDONMENT* (Other) {NOTE.' Report results of multiple completion on Well Completion or RecomD~etion Report and Log form.} 15. DESCRIBE PROPOSED OR COMPLETED OPER_~TICNS (Clearly. state all pertinent details, and give pertinent dates. Including' estimated date of starting any proposed work. Atlantic Richfield Company proposes to perforate selected intervals within the Sadlerochit interval. Ail perforated intervals will be reported on subsequent report. A 5000 psi WP wireline lubricator, tested to working pressure, will be utilized with all wireline work. All perforations will be made with hollow carrier type guns at 4 shots per foot. Well will be flowed to a surge tank to recover load fluids and any produced well fluids. All recovered liquids will be retained in the surge tank, then trucked to the oily waste disposal facilities for disposal. Any produced gas will be vented to the atmosphere during perforating operations. The down hole safety valve will be installed and tested upon conclusion of job. Estimated start date' April 21, 1977 RECEIVED MAR2 19/7. 16. I"-hereby certify that the foregoing Is true and co.eot D!visi0n of 011 arid Gas 00nservation_ ' Sl.g N E D ~~ ...... ' i {Thls"$pace for State office uso) TITLE District Drilling EngineerDaTE_ . , iONS OF APPROVAL, I~"ANY~r Petroleum Engineer See Instructions On Reverse Side DAT''30-77 .~:~roved Copy Return,-,. ~ --~1-77 To' · o~th ^laska ])ist~ict.E~g±neez ~. .CONFIDENTIAL DISTRIBUTED TO: STATE OF ALASKA DIVISION OF OIL ~r GAS TRANSMITTAL From · J. A. Rochon/W. Toliver Date' June 10, 1976 .Well Name: D.S.#3-1 (.11.-..!.0-!5 Transmitted herewith are the following for the subject well: Run No. Scal'e Xerox 1 .TVD-Porosity Log 1 Borehole Geometry.. Log ..... 2 Depth Determination Collar Log ....... BHC Sonic/Caliper Log , BHC Sonic/Caliper - Gamma Ray Log BHC Sonic/Gamma Ray Log Caliper/CCL ~ Cement Bond Log/%~L $" Compensated Formation Density Log Compensated Neutron-Formation Density .. Compensated Neutron Log Core Analysis .- Interval ' Core No. Core Description (SWC) - Inte'rval Core Description (Cony.) - Core No. Directional SurVey- Gyro Single Shot Multishot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Fomation Density Log/Gamma Ray Gamma Ray/CCL Laterolog Location Plat Microlaterolog - · Microlog Mudlog- Interval . Sample Log (A.R.Co.)-Intervai)- S)rnergetic Log 5'~ Sepia i ea. ea. BL Line ] ea. ]. ea. Receipt Acknowledged For: Please return receipt to' (_A/lantic Richfield Company xq~orth Alaska Engineering Manager P. O. Box 360 Anchorage', Alaska 99510 · JUN ! 4 1976 AtlanticRichfieldCompany North Ame~ Producing Division North Ala~, ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 May 6, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Oil and Gas Division 3001 Porcupine Drive Anchorage, Alaska 99504 RE: DS 3-1 (31'10-10-15) Permit No. 75-75 Dear Sir: We are enclosing the Well Completion Report along with the Well History and Directional Survey for the above mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer CRK/BDR/j r Enclosures / // / /' STATE OF ALASKA SUBMIT IN . OIL AND GAS CONSERVATION COMMITTEE '-, '* ZE* st ructions on reverse side; iii i i ii i i i ii WELL cOMPLETION OR RECOMPLETION REPORT AND LOG* ,a. TYP~.0rw~L'~: ' o,i,~ ~AS ~ Z~ W ELL W ELL DR r Other ~b. TYPE OF' COMPLETION: NEW WORK ~ PLUG ~[-~ DIFFi WrLL [-~O,'m~ ~ I~EEe-~x ~ II.~_CK nESVI1. [~ Other Suspended.. NAME OF OPERATOR · Atlantic Richfield Company 3. ADDRESS OF OPERATOR P. 0. BOX'360, Anchorage, AK 99510 4. LOCATION OF WELL (Re~ort location clearly and in accordance with any State requirements)* At surface 2017'N & 664'E of SW cr Sec 11, T10N-R15E, UN At top prod. interval reported below ' 1'297'8 & 1491'W of NE er Sec 10, T10N-R15E, UM At total depth 1137'S & 1583'W of NE er Sec 10, T10N-Ri§E, UM ORIGINAL 5. APl NLrMF_.~CAL CODE 50-029-20187 6. LEASE D~-,SIGNATION AND SERIAL NO. aJ)L 28328 ~. IF INDIAN, ALL(~TTEE OR TRIBE NA1VIE 8. UNIT,FA.I-I~ OR LE~kSE NAME Prudhoe Bay ~ (31-10-10-15) ]10.~I~EII~AND' POOL, OR WILDCA. T [Prudhoe Bay- Sadlerochit [11. SEC., T., R., M., (BOSOM HOI~ ~ OBJECTIVE) .U CO 1 Sec 10,T10N-R15E, UM 12. PER1VIIT BrO. 75-75 2-21-76 13-14-76 14-~0-.76 1 ,03 : 59250' 908' & 9134' ingle All None ~. P~ODUCING !~VAL(S), OF ~IS CO~P~TIO~--TOP, BOSOM, NA~E (~ AND ~)* ,23. WAS D!RE~O'NAL ~ SURVEY MADE None t Yes 24. TYPE ELECTRIC AND OTHE~ LOGS RUN DIL GR/Sonic, FDC/CNL, 'CBL/VDL, CCL ., CASING RECORD (Report all strings set in w~{'{') :'-.~0 [94#-Vete~ I~-4o ks l.pd. 132' Fpprox 300 sx Pr II 13-3/8" ~#- Buttres} ~-80[ 2720'- 117-~/2" B400 sx PF II emt ' ' "9-s/'a'~ ~7#-~tt=~} ~-ao[ 99a6'' 1,22x/4''~000 ~ c~ g ' ' ~ 'a [S00'951 i '" ~nd sta~e w/105 sx PF II ,,,, ,,, ,,, [ ........ / , S I ,,,~ ,,, ~ _ II / ~ ~ ,,t H · ~ 26. LINER ~CO~ ]27. TUBING RECOF~ -',',' ...... ", .... t' .... !....'" . t' . " t". ... ],..0,.,, -. ,,, 28. PE~OR.AX'iONS OP~ TO PRODU~ON (interval, size and number) 29 ACID Si'~OT F;IA-I'GR~ C~,iENT SQUrV7~ ETC. D~i I~T~V.~ (MD) ~ AMOUNF 2~D I'2IND OF MATEPIAL US~ N/A ~ / NA ..... ,, 30. PRODUCTION DATE FIRST PI%ODUCTION I pRODucTION ME'IIIO~D (Flowi~*g, gas lifL purnph'~g--size and typo of pump) [V/ELL STATUS (Producing or N/A t ! ~'~-~) unperrorated ..... I completion ~O, TU~ $II Iiit : =, I ID)l Ig,/~ [g i1 ~ r~ b"~ .. '1 ~)ISPO*l~[lOS or OAS tSo[d' used ior 'fuel vented eic )- ' [ I ' '' D~zll~ng Hxstory and Gyro Sqrvey · ' ~' .... "~ ' · 33. I hereby certify that {he forll~oln~ and attached information t~ complete and correct au determined from all-available reeorcl'i SIGNED ___ TITLE DATE · (See Instructions and Spaces for Additional Data on Reverse Side) INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on alt types of lands and leases in Alaska. Item: 16: Indicate which elevation is used as reference (where not otherwise shown) for depth measure- ments g~ven in cther spaces on this forn~ and in any at~arh:~.~ents. Items 20, and 22:: If this well is completed for separate- prcduction from more than one ~nterval zone (mulliple completion), so state ~n item 20, and in item 22 show the prcJuc~r~9 interval, or ~ntervals, top(~;), bottom(s) and name (s) (if any) for only the intervol ref)orted in ~ten~ 30 Submit a separate report (page) on this form, adequately identified, for each add~tior~al interval to be seperately produce,d, show- ing the ac::k. Jitional data pertinent to such interval. Item26: "Sacks Cement": Attached supplemental records for this well should show the details of any mul- tiple stage cementing and the location of the cementing tool. Item 28: Submit a separate completion report on this form for each interval to be separately produced. (See instruction for items 20 and 22 above). , , 34. SUMMAItY OF FO{{MATION T~S'I'.% IN('L.UI)IN(; INq'EI{VAL T~CVFED. I>HI~.~SURI~ I)ATA A_N-D IR~COVEI{IES OF OIL. GAS. 35. G I~OL,OG IC M A1RKEiR~ WAT~F( AND MUD ~E^S r;L'PT~( ~U~ V~m.T. OgP~ Top Sadlerochit 9.403' 8651' Base Sadlerochit 9911' 9137' · . 3/1. CORE DATA. A'I'I.'AC'I{ I,~RIEle' D~_~,~[~:'~']~)~q~S O,1~ LITI. I'OLOG.Y. PO.FI¢)RI~TY. AN'E~ D:g',l~'Ig~,"lqgl0 $II~)WS O~ ().IL.. GA.S' O11 i i i i i i i iii i i ii i ,, , Atlantic Richfield Company DS 3-1 (31-10-10-15) API 50-029-20187, ADL 28328, Permit No. 75-75 DRILLING HISTORY Spud @ 1400 hrs 2-21-76. Drilled 17-1/2" hole to 2720'. Ran 13-3/8" 72~ MN-80 buttress casing w/shoe @ 2720'. Cemented w/5400 sx Permafrost II cmt. Washed 13-3/8" x 20" annulus and'recemented w/320 sx Permafrost II cmt to remove all possible freezible fluids. Landed 13-3/8" csg, installed and tested packoff. NU and test BOPE. RIH with 12~1/4'' bit, drilled FC, shoe and formation to 2764'. Tested formation to 0.65 gradient. Directionally drilled 12-1/4" hole to 10,030'. POH with multi-shot. Ran DIL/GR/Sonic and FDC/CNL logs. Conditioned hole for casing. Ran 9-5/8" 47~ MN-80 and S00-95 casing with shoe at 9986', FC at 9908', lower FO at 2672' and upper FO at 2392'. Cemented casing with 1000 sacks Class G cement. Installed and tested casing packoff. RIH with RTTS and shifting tool, cemented through lower FO at 2672' with 105 sacks Permafrost II cement. Closed and tested FO with 3000 psi. Opened upper FO at 2392', circ and pumped 315 bbl Arctic Pack at 9.5 ppg with break through at 161 bbls. 0% water at end of job. Closed and tested FO with 3000 psi. RIH with 8-1/2" bit and 9-5/8" casing scraper, drilled firm cement 9887' to top of FC at 9908'. Ran GR/CBL/VDL, CCL, and Gyro survey. POH. Changed mud to water and water to diesel. Installed and test 5-1/2" rams. Ran 5-1/2" 17~J MN-80, 8rd LT&C A-B modified tubing with shear sub at 9192', X-L nipple at 9125', SAB pkr at 9053' top of PBR at 8972', X-N nipple at 8928 and SSBV nipple at 2207'. Land tubing, tested hanger and packoff with 5000 psi. NU and test xmas tree.Drop ball and set SAB packer. Pressure 5-1/2" x 9-5/8" annulus - communication with 9-5/8" x 13-5/8" annulus. ND xmas tree and NU BOPE Pulled and layed down 5-1/2 "tubing. RIH and pressure test9-5/8" casing. Tests indicated leak above 2000'. Ran caliper log - showed 9-5/8" casing parted at 1906'- 1908'. RIH and set retainer at 2991'; spotted sand plug on top. Unland and pulled 9-5/8" casing with split collar from 1906'. Cut and recovered 9-5/8" at 2032'. RIH with 12-1/4" bit to stub at 2032'. POH. Ran RTTS and set at 2020'. Tes~ 13-3/8" casing with 1500 psi. Squeezed 9-5/8" x 13-3/8" lap with 200 sacks Permafrost II cement. RIH with 8-1/2" bit to 2062'. POH. RIH and dress stub at 2032'. Pressure test 9-5/8" x 13-3/8" lap - no good. POH, ran RTTS to 2020', squeezed lap with 250 sacks Permafrost II cement. RIH and washed over 9-5/8" casing, cut and recovered 9-5/8" casing from 2338'. Ran 9-5/8" Joy/ARCo csg patch - unable to set patch. RIH and WO stub to 2371'. Cut and recovered 3' of 9-5/8" csg. Reran and engaged csg patch okay. ND BOPE, landed 9-5/8" csg. NU and test BOPE. Ran RTTS and shifting tool, tested csg above and below RTTS to 3000 psi. Open FO @ 2316', pumped 161 bbls Arctic Pack. Closed FO and pressure tested to 3000 psi. RIH and changed over Invermul to diesel @ 2990'. Engaged and recovered Baker BP. RU and ran 5-1/2" 8rd LT&C A-B modified completion assembly, landed @ 9192'; 41/2" X nipple @ 9125'; packer @ 9053'; PBR @ 8972'; 5-1/2" landing nipple @ 8928', and~'. ND BOPE, NU and test xmas tree. Tested and pulled dummy valve. Ran 2-7/8" dummy gun. Released rig @ 060~~~.~ REPORT of SUB-SURFACE DIREC TIONA L SURVEY Atlantic Richfield COMPANY D. S. 3-1 WELL NAME Prudhoe LOCATION JOB NUMBER TYPE OF SURVEY / DATE A376 GO090 Gyro 8-76 ,.:,. SURVEY BY OFFICE ,Tames Sexton Alaska FORM _G YRqS. COP_[C__$_URV_E Y _R~D..I.U..S_ 0 .F_.~.U.~.V~_T..~ R.E__~. E..? HO D_.OF ----Cg,rMPU!.ED-----F--O B .... 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' : , ............. : 4000-.-~ . ; 4400: ' SCALE j :500 ATLANTIC RICHFIELD DRILL SITE GYROSCOPIC · ................. TMD= ~ ,, .~ 8800 j ~ . , "_;.7~ .'; LT;Z .'.'. UL'._~TZZi-.--L;iL._.L L_~L i .... ~ ....... --7- ......................... -~ .............. : ............ ~ ......u . I ~ ' ............. ~ .......... ........... ! ........... l .......................... 'l .................. ~ ........ ' ............ ~ ....... ~ ........................ q- ............ ~-- ...... i ................ ~,-" .......... :-! ............. i, i .... : .....~ ......... ~ ...... .'-t .......... ] ALL DEPTHS SHOWN_ .u_~ _ - ............. '7 ................. ~,: '-~:--~!/----'-:--:---':-:'-:"-:--'i------:----7.-~- : / ~.~ ~v~ ..... 'I ..... : ..... -': .......................... ~O{ ...... 1 ........ :- .... i ....... , ............. ~ ....... -. ..................................... ~ ...... ~ -- : j - .: ........ t ............................... i LOCATED IN THE APPENDIX [21 WFL [2] IPR LOG CALIPER SURVEY UI VOLAN [21 CURVE DATA [21STRATIGRAPHIC HIGH RESOLUTION DIPMETER OTHER: ~ ATL,~NTIC RICHEIELD CO~NY TO' . CONFIDEN~[ ^~ ~~ En§ineering DISTRIBUTED TO: T R A N S ~[ I T T A L STATE OF ALASKA. D!V!S!ON OF OIL ~ G~ From' J.A.Roc~on/l~. To15ver Date: _April 27,1976 Well Name:D.S.#3-1 (ll-10-1S). " 1 BHC Sonic/Caliper-- Gmma Ray Log -BHC Sonic'- Gamma Ray .Log. '..:.".-.. -".- Cement. Boncl. Lo~VDL ..... : . .... :':' · :'" , ,' compensated Pomation.Densi~'~Log::. '. 'i-~ 5" Compensated Neutron-Formation Density S" Core Analysis - Interval ............... '' . -'" -.'..' · Core No'. '" "' '" Core Description (~VC) ' ~iht~rval core Description (Cony.) Core No. Directional. Survey - Gyro' --_.. ... ...' Single Shot - . · MultiShot Drill Stez~ Test Test No. i~l :'Induction Laterolog Formation Density'Log' - Formation Density Log ~ Gamma Ray Gamma Ray - C~?'-'i :::!- _ Laterolog . . . Location Plat DEicrolaterolog Microlog ... Dhdlog- Interval Sample Log [A.R.Co,) Interval Synergetic Log Receipt Ack~c~ledged For' Please re'turn receipt to' ~lantic Richfield Company North Alaska District Engineer P.O. Box 360 Anchorage, Alaska 99510 · . _ L · ..-/g~' -":'A'" ":% ' '- >,:-7'~ ..... : j .. -~ . · ~:- .:':.".. :~ .- :-:. :'.~ .-- . . .__ ./~.,, :-'.~.:. .- . _ · ._ . _ . .. · . ~ ... . .. Transmitted herewith are the following for.the subject well' - - :'-'-'- '- .--~ Run.No' -' . : " Scale '.'.- i.~ Xerox i Sepia." ~L Line '~ ,:: .........' ' """.-- ~c.-~'"'~'_ __.____.~o,~d~,,~~" "--"~' "-' .... '",.o~. ~ .... '--'"' .'-... - '"~"?':""":' ' '"-'::':' :"':::"'" "'""-:?'." --. -. -' .'-.,-....'-- .... -.. ..... ........ . ~. '"'"' "- '"" .': :- :~ ? '-'.: ?--:~:~'-::::"-':/:/7:'~":7:--~':~"~:: ,eldCompany ~ / North Ame?'~'~ Producing Division North Alas,, ~istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 April 5, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 Subject' Drill Site 3-1 (31-10-10-15) Permit No. 75-75 Dear Sir' Enclosed please find the MOnthly Report of Drilling Operations for the above-mentioned well. Very truly yours, C. R. Knowles District Drilling Engineer /cs Enclosure DIVISION OF OIL AND GAS Atlanti~RiEhfieldCompany North A~.r~~''' ~ Producing Division "" North AI~.I .~ ..,Istrict Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 March 4, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, AK 99501 DS 3-1 (31-10-10-iS) Permit 75-75 Dear Sir: Enclosed please find the Monthly Report of Drilling Operations for the above mentioned well. Very truly ~ours,/~ C. R. Knowles District Drilling Engineer Enclosure CRK/BDR/jl AtlanticRichfieldCompany North Am~r"'~- Producing Division ~ North Alas~,,. District ~ Post Office Box 360 · - Anchorage, Alaska 99510 Telephone 907 277 5637 February 13, 1976 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Procupine Drive Anchorage, Alaska 99501 RE: DS 3~1 (.31-10-~10.-15) Pemit No, 75~75 Dear Sir: Enclosed please find a Sundry. Notice describing the change of plans for the above mentioned well, Yours very truly, C, R. Knowtes District Drilling Engineer CRK:jl Enclosure BPALASKA iNC. 3111 C STREET · TELEPHONE {907} 279 0644 MAILING ADDRESS: P.O. BOX 4-1379 ANCHORAGE, ALASKA 99509 January 6, 1976 State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99504 Attention: Mr. O. K. Gilbreth Director Re: Arco Well DS 3-1 (31-10-10-15) Gentlemen: Attached is our statement of non-objection regarding Atlantic Richfield Company's proposal to drill Well DS 3-1 (31-10-10-15). Very truly yours, BP ALASKA INC. G. D. Taylor Manager Operations PRJ:cmc Attachment cc: Atlantic Richfield Co. File: DEV-PB-072/2 F~rm 10-403 REV, 1-10-73 Subml t "1 ntcntlons" In 'triplicate ~ & °'Subssquent Reports" in Duplicate sTATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE SUNDRY NOTICES AND REPORTS ON WELLS · (Do not use this form for proposals to drill or to deepen Use "APPLICATION FOR PERMIT---" for such proposals.) WELLI._J OTHER 2. NAME OF OPERATOR Atlantic Richfield Company [ ADDR~S OF OPERATOR P. O. Box 360~ Anchorage~ Alaska 99510 4. LOCATION OF WELL At surface !253' SNL, 502' W-EL, Sec. 6, T!IN, R14E, UPM 13. ELEVATIONS (Show whether DF, RT, GR, etc.) KBE=55.02 ' AMSL: BFE=26.44' AMSL 14. Check Appropriate Box To Indicate Nature of Notice, Re 5. APl NUMERICAL CODE 50-029-20166 LEASE DESIGNATION AND SERIAL NO. ADL 28299 7. IF INDIAN, ALLOTTEE OR TRIBE NAME' 8. UNIT, FARM OR LEASE NAME Prndbne. g~y 9. WELL NO. E-1 (24-32-12-14]) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay, Prudhoe Oil POD,1 ,, 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Sec. 32, T12N, R14E, UPM 12. PERMIT NO. 75-40 3ort, or Other Data NOTICE OF INTENTION TO; TEST WATER SHUT-OFF ~ PULLOR ALTER CASING FRACTURE TREAT MULTIPLE COMPLETE SHOOT OR ACIDIZE ABANDON* REPAIR WELL CHANGE PLANS (Other) SUBSEQUENT REPORT OF~ WATER SHUT-OFF ~ REPAIRING WELL ~ FRACTURE TREATMENT ..~ ALTERING CASING SHOOTING ORACIDIZING ! ABANDONMENT* (Other) Re-entry to replace completion fluid (NOTE: Report results of multiple completion on Well Completion or Recompletion Report and Log form.) 15. DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent (tares, including estimated date of starting any proposed work. · Accepted rig 2400 hours, May 14, 1976. Nippled up and tested 6" BOPE. Pulled blanking sleeve. Replaced diesel in well with water. Continued circulating water until clean. Reversed well over to diesel. Ran dummy guns to 9845'. Re-ran blanking sleeve. Nippled down BOPE; installed and tested Xmas tree. Released rig 1200 hours, May 17, 1976. JUI i 'f 1976 DIVISION OF OiL AHD O,',:q 16. I hereby certify that the foregoing Is true and correct _ TITLE ('(his space fc~ State office use) APPROVED BY CGNDITIO,~;S OF APPROVAL, IF ANY: TITLE DATE See Instructions On Reverse Side ~)~m No. P--4 L~/, 3- I-?0 STATE OF ALASKA OIL AND GAS CONSERVATION COMMI'i-I'EE SUBMI~ 1~ DUPLICAT~ 1, MONTHLY REPORT O'F DRILLING AND WOR'KOVER OPERATIONS WELL WELL OTHER 2. NAME OF OP~t~TOR Atlantic Richfield Co,mpany :[ ADDRESS ~)F OPF_.R~TOR __ P. O. Box 360, Anchorage, Alaska~ 99510 4. LOCATION OF W~U.T- ' r ' 2017'N & 664'E of SW cr Sec ll, TION-R15E, UM 5. AP1 NUMEHICAL CODE 50-029-20187 ~ 'LEASE DESIGNATION AXD SESIAL NO. ADL 28328 7 IF INDIA~, ALOTiEE OR TRIBE NAME 8. L.~IT F~riM OR LEASE NAME Prudhoe Bay g WELL NO DS 3-1 (3l-lO-lO-15) lO. FLELD AND POOL, OR wILDCAT _ Prudhoe Bay - Sadlerochit Pool ~i, s~:c, T., R., ~,. Caorrow~ ~tOL~ oamc-rn~ Sec lC, TION-R15E, UM 12. P]~VIIT NO. -- , 75-75 13. REPO~T TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEiVIENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED. PEHFOH~TIONS~ TESTS ANT) HESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TP..ACKED HOLE A. ND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. R_EPORT ON OPERATIONS FOR THE MONTH OF MARCH RIH with 12-1/4" bit, drilled FC, shoe and formation to 2764'. Tested formation to 0 65 gradient. Directionally drilled 12-1/4" hole to 10,030'. POH with multi-shot. Ran 6IL/ GR/Sonic and FDC/CNL logs. Conditioned hole for casing. Ran 9-5/8" 47# MN-80 and S00-95 casing with shoe at 9986', FC at 9908~, lower FO at 2672' and upper FO at 2392'Ri Cemented casing with 1000 sacks Class G cement. Installed and tested casing packoff. H with RTTS and shifting tool, cemented through lOwer FO at 2672' with 105 sacks Permafrost II cement. Closed and tested FO with 3000 psi. Opened upper FO at 2392', circ and pumped 315 bbl Arctic Pack at 9.5 ppg with break through at 161 bbls. 0% water at end of job. Closed and tested FO with 3000 psi. RIH with 8-1/2" bit and 9-5/8" casing scraper, drilled firm cement 9887' to top of FC at 9908'. Ran GR/CBL/VDL, CCL, and Gyro survey. POH. Changed mud to water and water to diesel. Installed and test 5-1/2" rams. Ran 5-1/2" 17# MN-80, 8rd LT&C A-B modified tubing with shear sub at 9192', X-L nipple at 9125', SAB pkr at 9053', top of PBR at 8972', X-N nipple at 8928' and SSBV nipple at 2207'. Land tubing, tested hanger and packoff with 5000 psi. NU and test xmas tree. Drop ball and set SAB packer. Pressure 5-1/2" x 9-5/8" annulus - communication with 9-5/8" x 13-3/8" annulus. ND xmas tree and NU BOPE. Pulled and layed down 5-1/2" tubing. RIH and pressure test 9-5/8" casing. Tests indicated leak above 2000' Ran caliper log - showed 9-5/8" casing parted at 1906"- 1908'. RIH and set retainer at 2991'; spotted sand plug on top. Unland and pulled 9-5/8" casing with slit collar from 1906'. Cut and recovered 9-5/8" at 2032'. RIH with 12-1/4" Squeezedbit to stub 9-5/8" at 2032'x 13~3 8"POH' Ran. RTTS and set at 2020'. Test 13-3/8" cas!ng with 1500 psi. / lap with 200 sacks Permafrost II cement. ~IH with 8-1/2" bit to 2062'. POH. RIH and dress stub at 2032" Pressure test §-5/8" x 13-3/8" lap - no good. POH, ran RTTS to 2020', squeezed lap with 250 sacks Permafrost II c.ememt,~, ;RII~ washed over 9-5/8" casing to 2154'. Preparin§ to cut and reco~-')9~L~,,~'i~g[~r-~t approximately 2350' on April l.L[~ . APr '/' 1976 DIVISION OF OIL AND GAS oi! and gas cofllervoflon committee byfhe 15th of the succeeding month, uflle.8 Otherwise directed. ,ulB STATE ~ .~. D.EPART~NT OF }~TUP~L RESOURCES '?~vtS,On Of 0tl and To: 1--- O. K. Gtlbreth. J Ot rector Chief Petroleum Engineer/" ~ FROM: Bell Le~oi-{llan Petroleum Inspector DATE : SUBJECT: Merch 24, 1976 Arco DS_ 6-6 F~ry 25, 1976 - I:lepart, ed_~:_.~ at 6:00.PM for a. 6:_30 s,,howupe for a 7:15 PM ~&p~Ftu~ via Wlen Flight #43'~..Oeadhorse..~= Arr~tved.at Oeaanors at 9:00 Pt4 and, hitchhiked a ride on a Parson's~bus. to Arco. base, · At Arco base we met with Gtl Meyer., alternate to Btl! Cengden, .to try .to- detemtne ~wh.tch of the t~o tests would begin first. He advised.Rowan Rig .#35 was ahead tn nlppl~tng up. so we radioed the rig for traaspa~,atton and. arrived at OrtllStte #3 at 10:20 Temperature -40°F, no wind,., ice .fog. - Drilling foreman for Arco was~=~]ack Murray and toolpusher for Rowan was Red Adams. -~4any i ines were frozen and .the stack had not been picked up yet. .February 26., 1976- At 10:00 iJ~-~.we called Jack Morrow, Arco dri.11, ing.for.,ema,n at '~Ii1-'$~ t~" #6 t~-~etermine .what p~egmss Parker Rig #.14] was maK.lng, mn nlppl tng UP- They were about to do a ~top job and at this potnt in ttme it appeared two tests might coincide, ! advised ~ack-Morrow that tf this ..did occur ! would give. prefermmce to Rowan Rtg #35. since .~the equipment had. not been previously tested. ! had personally tested BOPE ~ Parker Rig #]41 .on.. two previous occasions. Whtle nipp]lng up, I toured the locat.iou at.. Drill Site #3 and. found it well organized, the reserve pit wel] bu~It, steel wetded fuel tanks.were not bermed, the rig tn good repair and the well sign .tn.place.. ,However, we. noU.ced no N2 backup at the accumulator add Red Adams advi~sed ~the rig. ~has never had ,this system since its arrival on the slope in 1969,.~ Ne discussed th.is with Jack Murray .who advised the system wou]d be ~nstalled as~ soon as posstb!e. February 27, 1976 -Drtl! S~.Ji~6. cal]ed at 5:00 PNand advised they would begin -~{~t~s a~=aPproximately 6.00 PM, k~ arrived at Parker Rig #141 at 6.:15 PM and the ~st~ began at 7:20 PM. The-new drllling foreman was Weldon Arbsland and the toolpusher, BIill Selby. . Pi..~.: rams and eight valves a"d .~.th.irty.flanges. in the choke manifold tested to $000 PSZG. The manual adjus~tablech~ke -was free mov.ing, and the. SWACO choke, was actuated. One wing valve and check valVe on.. the kill line and. both ~tng valves on the choke line tested to. 5000 PSIG. The. inside valve on-.the kill ltne'~would not test and will have to be ~paired or_ replaced. While removing drill pipe to~..test the blind rams, we ~ed the location which was well, s.organized, reserve pit .well built, steel We]ded fuel tanks not bemed, the rig-~in good repair and the well Sign not received from Anchorage. ..- O, K, Gtlbret~, Jr.. -2- March 24, 1976 The a~lator ~a.s testmi to 2750 PSIG. N2 bottles tested to I100, 1500, 1600 and 1400 PSIG. ~ .reccmmm~ bottles, ~1, ~2, and #4 be replaced. Rams were actuated by both prtma~y and ~emo~ controls. Blind r~s test~ to 5000 PSIG ami hydrtl tested to ~ PSIG. At thls point they could ~ot ¢ind the test adapte~ sub for testing the kelly cock ~d dectded to fabrfcate a ne~ eno. F~ary .28,~ 197G - At a ltttle past mtdntght the new adapter sub was completed but'~'kellY was ~ in Sba rathele. This was finally overcome and tests resu~d at 1:25 AR. ~elly cock ami leper kelly valve tested to 5000 PSIG, Both dart type and ball type floor valves ~ on the floo~. Tests were completed at 2:00 AH. Afteld tnspectlon report wes .completed, the ortgtnal given to Weldon Arbsland, a copy mafled to Betray Loude~llk ~ a copy attached to this repm't. We were driven back to Drfll $1te #3, a~tvtmj there at 2:20 A~. The m~ drtlltng fo~~ at 1~H'11 Site #3 was 'Buck Rice. Tests began at 11:25 AM, but there ~as an tmedtate flaege leak aad the: hydr-ll ~ould not test. The acc~lator was ~ted to 2800 PSIG and ram were actuated by both the primary and remote controls. ~tle awattfng repatrs we drove to 0rfll Site #g, Rowan Rtg #34 to see tf they had tnstalied the N2 backup as receaeeaded' back In qanuary. They had done a neat Job complete w~th gauge and bleedoff valve:. Buck Rtce observed the hookup and wtll copy tt for Rtg #35 as these sister rigs are almost Identical in construction. While at Rig #34 we tested the N2 bottles, each of whtch tested in excess of 2000 PSIG. Tests resumed at 3:00 PM ~d we- tested both the upper and lower pipe rams to mOO PSIG. Beth wtng valves on the choke 11ne and the wlng valve and check valve on. the kill line tested to 5000 PSIG. It was definitely decided at this time to change the. packing element in the hydrtl. Drill pipe was removed and blind rams tested to 5000 PSIG. We decided to isolate the choke manifold from the stack with a wing valve and continue tests. However, one valve refused to test and it was so located that until it was repaired or replaced no other valves in the choke manifold could be tested. Feb~ry 29, 1976 - By 10:00/LM~ny delays had occurred. The hydrll packing ei~ment was'~ replaced, but one of the roughnecks fell some thirty feet into the cellar ~nd was ~ushed to the. hospital. Fortunately, his injuries were minor. One of the wing valves on the choke, line which previously tested okay would not close and had to be repaired. Tests resumed at 3:00 Plq w~th .the lower kelly valve testing to 5000 PSIG. However, the kelly cock would not test and the kelly was set back in the rathole fo~ stea~ng. ? / O, K. Gilbreth, dr, / / / / / / March 23, 1976 Tests resined at 6:45 PM and thirteea valves a~d forty-two flanges tn the choke manifold tested to $000 PSIG. The- ea~al adjustable choke vas free eovt~g and the ~ superchoke was tes~ to $000 PSIG. At thts paint tn ttee a roug~k dropped a !/2" clevls pin into the stack. An attest to rake up drill F!Pe leto the test: plug fatled when It was fou~ a piece of rubber ~ the size of a ma's shoe free the-old hydrtl element had dropped precisely into the box up ca the test plug sub. The stack was drat~ed and t~, lower pipe raes preventer ~d to retrteve the piece of rubber. Oft11 pipe was tbe~ rode ~ into the test plug aed it was then raised until the clevis pin ceuld be retrieved :by hand. ~ pr~ was then. ntppled up and retested to At 11:30 PM the hyd~'l ~as test~ to 3000 PSIG a~d the repatred valve on the c~ lire tested to 5000 ~IG. Kelly cock was tested to $000 PSIG and tests con- cluded at 12.:00 e4datght. Both dart type ae~l ball type valves were on the floor. A ~'!eld tnspectt~ report ~as prepared, the ortgt~al given, to Buck Rice, a copy mailed to Benny-Lo'udeeeild a~d a copy attached to this report. March I, 1.976 - ! depa~ .Oead~ at 4:SO PM via ~/ten flight #20 and arrived : a:t:6:30 PM and at my hoee at 7:00 PM. in suaeary, ! witnessed BOPE tests at Arco OS 3-1 and OS 6-6. Attachaents ii?~pera tot ld Ins in Report Re Item"('~)~ L'OCa~'On,~6neral l~'' ( ) 1. Wel.1 Sign (.) 2. General Housekeeping (:), : ,3. Reser,Ve,pit-( )open(: )filled ~!( ) 4, Rig () () () ( () ( Sub~Uri~ace-No. Wel 1 s ( )Well TeSt Data Wel 1 Nos. :( n Yes No Item Te'sts 20. Drill i 23. ChOke Manifold No. 24.. Chokes. ") : 2 7 '. ~ g t:',~ nd Rams ( ~ ( ) 28..Pi pe 'Rams ..~mme ps.i g '?-( )'"' (: ')" 1.1. P-&'A".l~a'r'l~er "' ~:!?. ( )::" (..) 12. Water well-( )capped( )pl.ug~ed (~() 29. Kelly ,&, 'Kelly-coc.k,f~psiq iiii:''' ()!!iii.:(]) 13. C1..~.n,U..p~.. '. ..'' .~' ('.~-.(.."":) 3'0.'. LOwer. ,~e. lly'va'lv-e'j.~.-p-Siq~~::' - ~:~':.': ~ (')''~'.mt?~;.~(~"?"~')~ 'l:'4'J Pa'd'.".lev:eled. -'.. "",."]<. · "." (~':.!'('"') '. 31'~ 'safety.iFlOb.r"..val'vJS';:(~/'~:~i:f't ~ .?Totali:i?~.ection observation time .~.~m~' hr.s/?mjlm. To'~:a:.l' .number'.leakS and/or-.equip., failunes'... ' ~ ??. -"~'~.~'.:"' ........ . .... , ..... ' · . · . :.~;'.::.i:':'.'. .... ",. ' .... · .... .i.'... ... _ · . _ Form No. P--4 REV. 3-1-70 STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS WKLL WELL 2.NAME OF OPERATOR ATTIC RICHFIELD COMPANY 3.ADDRESS OF OPERATOR P.O. BOX 360 ~ Anchorage ~ Alaska 4.LOCATION OF WELL 99510 2017'N & 664'E of SW cr Sec 11, T10N-R15E SUBMIT IN DUPLICATE ~. Ap1 NU~HER/CAL CODE 50-029-20187 6 LEASE DESIGNATZON A.%'D SE]RIAL NO. ADL 28328 ?. IF INDIA~T, ALOTiE~ OR TRIBE NAME 8. LTNIT,FARM OR LEASE NAME Prudhoe Bay 9. WELL NO DS 3-i (31-10-10-15) 10. FIELD A_ND POOL. OR WILDCAT Prudhoe Bay - Sadlerochit Pool 11. SEC,. T., R., M., (Bo'rTOM HOLE OBJ'F, CTn,'E) Sec 10, T10N-R15E, UM 1~. PI~UVIIT NO. 75-75 "'~3. REPORT TOTAL DEPTH AT END OF MONTH, CI-L%~GES IN HOLE SIZE, CASING AND C~ENTING JOBS INCLUDING DEPTH SET AND VOLU1VEES USED, PERFOP~ATIONS. TESTS AND HESULTS. FISH!NG JOB~. JUNK IN HOLE AND SIDE-/RACKED HOLE Ae~D ANY O'I~IER SIGNIFICANT CHANGES IN HOL~ CONDITIONS. . Report on operations for the month of February. Spud @ 1400 hrs 2-21-76. Drilled 17-1/2" hole to 2720'. Ran 13-3/8" 72# MN-80 Buttress casing w/shoe @ 2720'. Cemented w/5400 sx Permafrost II cmt. Washed 13-3/8" X 20" annulus and recementedw/320 sx Permafrost II cmt to remove all possible freezible fluids. Landed 13-3/8" csg, installed and tested packoff. NUand test BOPE. Preparing to drill out FC and shoe on March 1, 1976. SIGNED d/~/~A~_ T~TLE ' ~.~.4.,~9 DATE -, , --, NOTE --Report on this form Ii required for .each calendor ~nth~ regardless of Ihs rue of operations, and muir ~ file~ ~n dupli~/e with the oil and gas conservation commiflee bythe 15~ of the suecNding mon~, ~le~ otherwise directed. Form P--3 REV. 9-39--6 9 Sabmtt "Intentions" in Triplicate & "Subsequent Reports" in Duplicate STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE' SUNDRY NOTICES AND REPORTS ON WELLS (Do not use this form for propo.sals lo drill or Io deepen Use "AI'P'LIC,,VI'IL)N 'FOIl I'~EI~IT~'' 'for such 'pi;o~osals.) 1. 2. NAME OF OPERATOR ATTIC RI~FIELD 3. AI)I)I.LESS OF OPEIIATOR P.0. BOX 560~ ~0~GE~ ~~ 99510 4. LOCATION OF At surface 2017'N & 664'E of SW' cr Sec I'I, T10N, RiSE, UM 13. ELEVATIONS (Show whether DF, RT, OR, etc. 5. APl NUiFL1KR.ICAL CODE 50-029-290187 6. LEASE DESIGNA'rlON AND SEI~.IAL NO. ADL 28328 7. IF INDIAN, ALLO'I"I'EE git 'I'IHBE NAME 8,UNI'r, FAF~I OR LEASE NAME Prudhoe Bay 9. WELL NO. DS S-1 (31-10-10- 5) 10. FIELD ,AND POOL, O1{ WILDCAT Prudhoe,..Bay Salerochit Pool 11. SEC., T., R., AI., (BOTTOM HOLE OBJECTIVE) Sec 10~ T10N-R15E~ UM 12. PEI~IIT NO. 75-75 Check Appropriate Box To Ind;i,cate Nature of N~tice, Re )oPt, or Other Dato NOTICE OF INTENTION TO: TEST WATER 8HUT-OFF FRACTURE TREAT SttOOT OR ACIDIZE REPAIR WELL PULL OR ALTER CASINO MULTIPLE COMPLETE ABANDON* C'HANOE PLANS ~Other) SUBSEQUENT R~PORT OF: WATER SI{CT-Or~ i REPAIR,NO WELL FRACTURE TREATMENT ~ ALTERING CASINO SHOOTINO OR ACIDIZINO , , ' A~ANDONME~T* (Other) (.NOTE: Report results of multiple completion on Well C.mpletlon or Reeompletlon Report and Log form.) 15 DESCRIBE PROPOSED OR COMPLETED OPERATIONS (Clearly state all pertinent details, and give pertinent dates, including estimated dat~ of starting any proposed work. Atlantic Richfield Company proposes to change the surface location of the well from 1370'N and 801'E of SW cr Sec 11, T10N, RISE, UM to 2017'N and 664'W of SE cr & Sec 11, T10N, R15E, UM. An as built plot .of Drill Site 3 is attached.. Atlantic Richfield Company proposes to change the proposed depth and 9-5/8" casing setting depth from 10,425' to 10, 150'. Atlantic Richfield Company proposes deletion of the well samples and mud log requirements for this directional well. The approved-drilling permit for this well requires cutting samples, core chips and a copy of the mud log. This data will be available from DS 3-6 Well. We do not have any present plans to core or mud log DS 3-1. We therefore respectfully request that this requirement be wi.thdrawn from the permit to drill this well. 16. I hereby certtf~th~._f~re.~tn~_ sthe foregoing ~ true and correct SIGNED _~,~.~("' ~'/~_ I~ (This space for State~,~.,qffi~ use) ~ co~m=~o~s o~ovi~, I~ ..~ TITLE - ~ ~ · See Instructions On Reverse Side DATE ^r~t~r~ed Copy Rel~med - - 664" -'---'-- 71:5' lO Ii 15 14, CERTIFICATE OF SURVEYOR ' HERE3Y CERT',FY THAT I AM PROPE.RL( REGISTERED ,~ND L;'CENS£DTO PRACTICE LAND SURVEYING IN THE STATE OFALASKA AND THAT THIS PLAT AP_PRE - SE'iTS A LOCATION SURVEY ,MADE 9'(' MEOR UNDER MY S:JPERV]Si'ON, A>ID ALL DI.MEN$1ONS AND OTHER DETAILS ARE. CO.RR._CCT. WE~"'~' No. I LA'I. 'TO°l 4,'0 I. 509"' LONG, 14.8 ~ I ~':Z':).77:~" WELL No,.A LAT. 70° 14' 00.593" LONG. 148°16' 22.066" Y 5 938 074.65 X: 713 90~75 ' 937 96L.93 713 931.25 WELL No. :5 LAT. 70°13' 59.2/58" Y 5 937 84528 LON~. 1%8°15'21.535" X 713 959.73 · ...'t'.~ OF' 0 EXI~I~ WELL O~.CONDUCTOR PIPE ARCO No. HVL No.33-Dg:~-76 ATLANTIC RICHFtEL.D CO. AS BUILT DRILL SITE No. 3 WELLS No. ! ,2 & 3 LOCATED IN PROTRACTED SECTION II.,TJON ~RIBE~ U.M. PREPARE:) BY · I mdNSB,JRY E~ ASSOC. HEWtTT V. _',~ Y23 ,V 5 ;n. ,"-VE., ,g.,'JCHOR-'G E,~LASKA SCALE 300' , ,,',?KD. B'F GD · P E' 3 3 '4 LOC~__ LEAF AtlanticRichfieldCompany North Ameri~. Producing Division ~, North Alask 'strict ~- Post Office Box 360 Anchorage, Alaska 99510 - Telephone 907 277 5637 December 9, 1975 Mr. G. D. Taylor BP Alaska, Inc. Box 4-1379 Anchorage, Alaska Dear Sir: We propose to drill our DS 3-1 (31-10-10-15) from a surface location in Sec 11, T10N-R15E, UM to a bottom hole location in Sec 10, T10N-R15E, UM. Both the sections are on ARCO-Exxon leases, We propose to complete this well for production within 1600 feet of the lease line. State regulations define the operator of a lease, offsetting such a proposed well as an "affected operator" and require the consent of the affected operator. In the case of DS 3-1 (31-10-10-15), BP Alaska operates the offsetting lease. Please indicate your consent in the matter by signing below and on the enclosed copy. Please forward one copy to the Division of Oil and Gas and return one copy to us. Sincerely, C. R. Knowles District Drilling Engineer CRK:alh Enclosure CONSENT IS HEREBY GIVEN AS NOrD ABOVE BP Alaska, Inc. Signature ~r 1~, Ig75 Re: Prudhoe Bay DS .3-1 (31-10-10-15) Atlantic R~chfleld Ccepany State Pen~t ~o. 75-75 Oear Sir: · £nctosed is tl~ approved appllcation for permit to dr111 the above referenced wall at a 1.ocatton tn Sectton :10, Township 10~, Range 15£, Well samples, core chips aud a mud log are required. A directional survey is requt~. Many rivers in Alaska and thelr drainage systemms have been classified as t~rtant for ~ s~in9 or migration of anadromm~s fish. Operations in ~ areas are subject to .AS 16.50.870 and the regulations promulgated there~ (TiUe 5, Alaska Administrative Code). Prtor to com~nct~J operations you may be contacted by the Habitat Coordinator's office, Oepart- merit of Fish and Game. Pollution of any waters of ~ State is prohibited by AS 46, Chapter 03, ArtiCle 7 and the regulations prolmul ga ted thereunder (Tttle 18, Alaska Administrative Code, Chapter 70) and by the Federal Water Pollution Control Act, as amended. Prior to ~lng operations you may be contacted by a represefltatt~ of t~ Oepartment of Environmental Conservation. Pursuant to AS 38.40, Loca] H!re Under State Leases, the Alaska Department of Labor is belng nottfled of the issuance of this permit to drill. To aid us in scheduling f{eld work, we would appreciate your .notify.lng.th.ts offi~ within 48 hot~s after the well is spudded. We would also lik bee to notified so that a representative, of the Oivision may be present to witness testing of blowout preventer equipment before surface casin!) shoe is drilled. C. R-;Kaowles Pa§e 2 December 18, 1975 In the event of suspensloa or aba.~t please gtve thts offtce adequate advance notJf~cat~o~ so that ~e my have a witness present. Very truly yours, Alaska 0tl and Gas Co~servat.l°n Ceaetttee E~closure CC: AtlanticR~ ichfieldCompany North Americ.~,,i Producing Division ~ North Alaska District '~: Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 December 11, 1975 Mr. O. K. Gilbreth State of Alaska Department of Natural Resources Division of Oil and Gas 3001 Porcupine Drive Anchorage, Alaska 99501 ~: DS 3-1 (31-10-10-15) Dear Mr. Gilbreth: Enclosed please find our Application for Permit to Drill DS 3-1 along with the $100.00 filing fee and temporary survey plat. Note that the location for wells No. 1 and No. 2 have been moved 10 feet north of original location. An updated survey plat will be submitted as soon as it is available. For your information, as well as for the State Depart- ment of Labor, this well will be directionally drilled from a surface location on Lease ADL 28327 to a target in~LeaseADL 28328. The effective date for both leases is October 1, 1965, with a termination date on March 27, 1984. Attached is a copy of a letter to the offsetting operator, BP Alaska, Inc.. A signed copy of this consent letter should reach you shortly. Sincerely, C. R. Knowles District Drilling Engineer CRK' alh Enclosures /r ~ SIJBMIT IN TRI7 \TE o (O~her instruet~o ~ P~I reverse side) 'STATE OF ALASKA~ ~:-, : F~ ~ ~ I~, , ~ API ~ 50-029-20187 OIL AND GAS CONSERVAIIO. N ~MI~EE APPLICATION,.,.o,,o,, FOR P[RMiT.. TO. DRILL... ., DE,tEN DRILL ~ DEEPEN U b. TYP~ OF W~LL ,,, 2. N~ O~ O~O~ Atlantic Richfield Company ADDRESS O~F OPF-~_~TOI{ P. O. Box 360, Anchorage, Alaska 99510 LOCATION OF WELLAt surface 1370'N ~ 801'B of SW cr Sec 11, T10N-R15E, UM At proposed prod. zone 1320'S ~ 1320'W of NE ct-Sec 10, T10N~R15B, UM 13. DISTANCE IN MILES AND DIRECT:ON F_~OM NEAREST TOWN OR POST OFFICe* Approximately 5 miles northeast of Deadhorse · 14. BOND INFORMATION: TYPE. Statewidesurety and/or No. Federal Insurance Co #8011-38-40 1,5. DISTANCE FROM PROPOSED' LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. (Also to nearest drig, unit, if any) ~. DISTANCE FROM PROPOSED LOCATION* 1320' TO NEAREST WELL DRILLING, COMPLETED, OH APPLIED FOR. FT. 5800' (DS1- 8) -~. ELEVATIONS (Show whether DF, RT, C.R, eteJ 22' Tundra, 28.' P .,a~t..; 6.1.' RKB "'il0. NO. '~F"ACKES IN LEASE I 2560 , . JIg. PROPOSED DEPTH i 1'0,425' 8. UNIT, FARM OR LEA-SE NAME Pru&hoe Bay 9. WELL NO. DS 5-1 (31-10-10-15) 10. FIELD AND POOL, OR WILDCAT Prudhoe Bay-Sadlerochit 11. SEC., T., R., M., (BO'I'TOM Pool HOLE OBJECTIVE) Sec 10, T10N, RiSE 12. ~o~, $100,000 NO. ACRES ASSIGNED TO THiS WELL 320 20. ROTARY OR CABLE TOOLS Rotary APPROX. DATE WORK WILL START' 1-13-75 23. PROPOSED CASING AND ;EM~NTING PROGI~&M 26" 20" 94# .... :H-40 100.',±., Circ. to surface 350 sx PF II __ ~1771/2'""i'' 132'5/~ 72# MN-SO 2700'*' Circ t--~ surface approx s000 sx PF .!2-~/4 . 9-5/8. ' 47# . ~¢I-80 .,10425' 1st sta~e w/approx 1500 sx Ciass~ _ ''. ...... ,, 8 RS-95 .............. '''' ~nd ~ta~9 300~± cmt c'olmm abo9% . ... ,,, i ..... .... .2600,' w/apprpx 125 sx o'f PF'"II /"ne Atlantic Richfield Company proposes to directionally drill this well to 10425'MD (9300') 'to produce the Sadlerochit zone. Logs will be run over selected intervals. A 20-3/4", 2000 psi Hydril preventer will be used on the 20" conductor. A 13-5/8", 5000 psi Hydril, 2 13-5/8" 5000 psi pipe rams and one blind ram will be used on the 13-3/8" casing. The BOP equipment will be pressure tested weekly and operationally tested each trip. A non- freezing fluid will be left in all uncemented annuli within the permafrost interval. II IN' ABOVE SPACE DZ~SCR/BE PI~OPOSPE*D I~J{OGRA-N[: If ~1 is to dee~n or plug ~, give ~ on p~sen~ p~u~ive zone ~d pro~ ~w ~odu~ive ~fie. If p~l ~ ~ drill or d~n d.Me~io~lly,. ~ve ~en~ ~ on ~bsu~a~ ~t~ ~d meas~d ~d ~ue ve~ical dept. Give blo~ut preventer p~gram. 24. I hereby cer%ify that the/Foregoin~ iS True an~ Correct (This space for State office use) CONDITIONS OF APPROVAL, IF ANal: ] SAMPLm AND CORE CHIPS p Ym .~ No , m~C~ON~ SURVEY ~~. ~ ~ u ~o 50-029-20187 . IIIL I , ti[ I', . tJ ILL II 75-75 '~ ~O~ ~OY~ AP~O~ Bv __. _ TI~- M~mber .. M~H 1 na December 18, 1975 'I OA~' : necember .! 8; !975 565' 590' 10 11 15 14 WELL I0 IFM L. CONTROL PT ) LAT 70° 13' 52 0" LONG 148° ~6' 26.3~' Y = 5,9:37,115 X = 71 :~809 EL£V277 TOP OF PAD 22 O' G~UND I__0£ii TIOIV OF WELLS 1-10 NOTE:Welt No. lis the control hole for the Directional Drilling Program. SCALE: I"= 400' C£H'ilFICA'i'E OF SUI, tVE YO~ I hereby certify that i an', properly registered and licensed to practice land surveying in the State of Alaska and that this plat represents a location survey made by me or under my supervision, end that all dimensions and all;er details are correct~ Date SURVEYOR DDED CONTROL HOLE NOTE ~RRECTED PAD ORIENTATION ~2/ 8/?5 12/10/70 C,J.R. A.LL. DRILL SITE N-°:3 Located in I/4 OF PROTRAC'I'E D SECTION~ II :TION;RISE.UMIAT MERIOIAN.AI< Surveyed for At lo n tic Richfie Id Cam pany I I I Surveyed by F. M. LINDSEY & ASSOC. LAND & HYDROGRAPHIC SURVEYORS 2502 West Northern Lights Boulevard Box 4-081 Anchorage Alaska CHECK LIST FOR NEW WELL PERMITS .~_ ---' Company /~.~....fm~z> Yes No Remarks Is the permit fee attached ..................... ./F~ Lease & Well No. ~r_,m/~'a~ Z~o~ ~_V~'),~_~_ ~,~- / Is well to be located in a defined pool .............. ~ Is a registered survey plat attached ................ ~ Is well located proper distance from property line ......... .K~. Is well located proper distance from other wells .......... ~ Is sufficient undedicated acreage available in this pool ...... Is well to be deviated ............... i) 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 ................... ~a~ 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 ~ )Il cement cover all ~ ........ ~-~+~,,~ ~~ · Will surface casing protect fresh water zones .......... . Will all casing give adequate safety in collapse, tension & burst · Does BOPE have sufficient pressure rating ............ d~tional Requirements- Approval Recommended' Geol oc~v Engi neeri hq' TRM HWK/~/K.a_/~_ OKG ~ HHH ,]AL ~0~/.. LCS JCM ~ Revised 1/15/75 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. .o 500292018700 Caliper Specialists Since 1953 KINLEY CORPORATION E~815 RoYalton, Houston, Texas 77081-2993 U.S.A. Phone (71 3) 664-4501 Telefax (71 3) 664-1 037 SERVICE AVAILABLE WORLDWIDE WITH ALL KINLEY WIRELINE TOOLS Calipers · Tubing Perforators · Sand Line Cutters · Power Jars · Measuring Line Cutters 500292018700 KINLEY SURVEY INTERPRETATION Common Abbreviations D~. = Dep~ Scatd. - Sc~ttcq~l TABULATION SHEET: JOINTS: are numbered from the top down. Numbering starts with the first full joint below the Christmas tree. PUP !OINT$: are designated by decimal numbers. For example, joint 32.1 represents the first pup joint bel6w joint no. 32. SPECIAL TOOLS are designated bY. letters. For example, "B" is the second special tool or nipple from the top of the well. GAS LIlT are numbered down from the top, as shown: GLM (1), GLM (2), etc. TABULATION SYMBOLS We use a circle as the basic tabulation symbol. The Kinley Caliper records the simultaneous action of all fifteen or thirty feelers. Our survey, therefore, has either 15 or 30 lines. These lines provide a view around the circumference of the inner surface of the pipe. A complete circle on the tabulation sheet indicates that at least 14 of 15 feelers, or 28 of 30 feelers found tubing wall reductions at the same depth in the well. This would be described as a ring. The number of feelers that indicate tubing wall reductions at the same depth is also noted on the tabulation sheet. For a 15-Feeler Caliper D3to5 D6to9 D 10to 13 O 14 to 15 For a 30-Feeler Caliper O 6 to 11 D 12 to 19 O 20 to 27 D 28 tO 30 MF~$11REMENT SYMBOLS [~] A PIT- A number alone represents the depth of penetration, expressed in hundredths of an inch, of the deepest pit. In this example 0.08". A groove around the pipe, found by 14 of 15 feelers or 28 of 30 feelers. The number inside the circle represents the maximum depth of the ring, expressed in hundredths of an inch. A PARTIAL RING - A groove around the pipe, found by 3 to 13 of 15 feelers or 6 to 27 of 30 feelers. The number inside the partial drcle represents the maximum depth of the ring, expressed in hundredths of an inch. MINOR DAMAGE - Indicates a "minor" amount of damage that is not severe enough to warrant measurement. NO COMMENT o Indicates no damage was found in that joint. Arco (Alaska), Inc. Prudhoe Bay, AK Drill Site #3-01 August 7, 1994 Survey No. 24108 Chart No. M1396 1st: 10-15-79 No. 9039 T-15 2nd: 0 8-24-90 No. 20255 T-15 This is the third survey of this well, the first to be made with the Kinley 30-Feeler Microscopic Caliper. The condition of the internal surface of the 5 162" 17# BTRS tubing in the well, from 3,008' to 9,100' (WLM), is covered in this report. The deepest penetrations recorded in the survey are pits located in the middle body of Jt #'s 19 and 90. These penetrations measure .20" or 66% of the tubing wall thickness. Cross-sectional drawings and photocopies of Jr. #'s 19 and 90, at the location of the penetrations, are included in the report. With the exception of Joint #'s 19, 41, and 90 the condition of the tubing surveyed and analyzed ranges from good to fair with respect to corrosive damage. Indications of damage are recorded in most of the joints in the forms of lines of corrosion, corrosion, lines of pits, scattered pits, and pits. As indicated by the Tabulation Sheets, an almost continuous line of corrosion is recorded from Jr. #139 up to Jr. #31. The Caliper Technician noted that the 5 1/2" 17# BTRS tubing between 3,038' and 5,324' is Class "B" tubing. The pup joints above and below the tool assemblies and GLM's are given individual joint numbers. Indication of corrosive activity is recorded in most of these pup joints. Photocopies of the recordings for some of these assemblies are included in the report. Many of the penetrations recorded in this survey exceed the maximum range of the photographic channels. The photographic enlargements included in this report will have the tops of some of the penetrations cut off as a result (Jr. #19). The chart was viewed with the Kinley Video Chart Reader to obtain accurate measurements of these penetrations, as the field of view is much larger. CALIPER TECHNICIAN Steve Adcock SURVEY ANALYST Jon Chance ARCO (ALASKA), INC. Continued Prudhoe Bay, AK Drill Site #3-01 Page 2 Survey #24108 jc Distribution: ARCO (ALASKA), INC., ATTENTION: Records Processor, Room #AT0-1529, P. O. Box 10-3240, Anchorage, AK 99510-3240 (TR) ARCO (ALASKA), INC., ATTENTION: Mr. Jason Weaver, Room #AT0-1788, P. O. Box 10-3240, Anchorage, AK 99510-3240 (1R) Chart received: Report mailed: 08-15-94 08-26-94 KINLEY CALIPER TALLY SHEET (Composite) DRILL SITE #3-01 Survey # 24108 August 7, 1994 5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Penetrations Over 85%: (Possible Hole) # of Jts Penetrations 41 - 85% JT. #'s 19 41 (Poor) 90 Penetrations 21 - 40% (Fai0 '. ,., JT..g's 92.1 100.2 106.1 112.1 112.2 131.1 136.1 136.2 138.1 4 10 11 12 13 14 23 24 25 26 27 31 34 35 36 37 47 48 50 53 54 ~ 72 73 74 75 76 81 82 83 84 85 89 91 92 94 95 99 100 101 102 103 107 109 110 113 116 123 124 125 126 129 '" 133 134 135 136 137 Penetrations 11 - 20% (Good) 119.1 119.2 125.1 5 7 9 15 16 21 28 29 30 40 42 44 55 59 71 77 78 80 86 87 88 96 97 98 104 105 106 118 120 121 130 131 132 139 140 103 53 Penetrations 1 - 10% (Very Good) No Penetrations Recorded TOTAL JOINTS SURVEYED: 164 ( Includes 24 Pup Joints ) KI E Y CORROSION PROFILE DRILL SITE #3-01 PRUDHOE BA Y, AK August 7, 1994 SURVEY # 24108 5 I/2" 178 BUTTRESS CORROSIVE DA MA GE FREQUENCY DISTRIBUTIONS MAX/MUM PENETRATION 13 3 NUMBER OF JOINTS % WALL LOSS CONFIGURA T/ON NUMBER OF JOINTS ~ o o DESCRIPTION BODY PENETRATIONS ~ % WALL LOSS 20 40 60 80 1 O0 1st Jr. of ~ 1/2" 1 ?Il BTRE; GLM (61 '~ GLM (10) , 12 1'8 24 30 PiT DEPTH (1/100 inch/ DR/£L S/Tf #3-01 SURVEY # 24108 PRUDHOE BA Y, At*: 5 1/2 ~' t 7# BUTTR[:'SS August Z, ?894 CORROSIVE DAMA GE FREQ UENC Y DIS TR/BUTIONS 44A~[/MUYt PENETRA T/ON Ng/V/£E;R OF JO/NTS CONflGURA T/ON DESCRIPTION BOO Y PENETRAT/ONS X over, GLM {~) % [%;ALL LOSS 20 80 0 6 I2 18 24 PIT £6PTH fl,/t00 KINLEY CROSS-SECTIONAL ANAL YSIS DRILL SITE #3-01 5 1/2" ? 7# BUTTRESS Survey #24108 O.D. - 5.500 In. LD. = 4.892 In. 9 8 10 o. oo o. oo '7 0.00 0.00 6 0.00 0.00 12 5 0.00 0.20 13 4 0.00 0.00 14 0.00 3 0.00 15 0.00 16 0.00 2 0.02 1 0.03 17 0.00 30 0.03 18 0.00 19 20 27 0.00 0.00 21 26 0.00 0.00 22 25 o. oo 23 24 o. oo 0.00 0.00 28 0.05 29 0.00 Description: JT. #13 PIT- Middle 8ody .20" = 66% Percent Area Reduction = 2.04 % Total Area Remaining = 4.86 Sq. ln. ;it : KINLEY CROSS-SECTIONAL AN,4L YSIS DRILL SITE #3-01 5 1/2" 17# BUTTRESS Survey #24108 O.D. = 5.500 In. LD. = 4.892 In. 9 8 10 o. oo o. oo 7 O. O0 O. O0 11 6 O. O0 O. O0 12 5 O. O0 O. O0 13 4 O. 09 O. O0 14 0.02 3 O. O0 15 0.05 16 0.07 2 0.03 1 0.00 17 0.04 30 O. 03 18 0.06 19 O. 08 20 27 O. 08 O. O0 21 26 O. 11 0.00 22 25 o. o4 23 24 o. o2 O. 03 O. 03 Description: JT. #29 CORROSION-. 11" = 36% Percent Area Reduction = 7.82 % Total Area Remaining 29 0.00 28 0.05 4.57 Sq. ln. KINLE Y CROSS-SECTIONAL ANAL YSIS DRILL SITE #3-01 Survey #24108 5 1/2" 17# BUTTRESS O.D. = 5.5001n. LD. = 4.892 In. 14 0.20 13 O. 09 12 0.02 9 8 10 o. oo o. oo 7 O. O0 O. O0 11 6 O. O0 O. O0 5 0.00 4 0.00 3 0.00 15 0.03 2 0.00 16 0.00 17 0.00 I 0.00 30 0.03 18 0.00 19 20 21 26 0.00 0.00 22 25 o. oo 23 24 o. oo 0.00 0.00 27 0.00 28 0.05 29 0.00 Description: JT. #91 PIT- Middle Body- .20" = 66% Percent Area Reduction = 3.89 % Total Area Remaining = 4. 77 Sq. ln. KINLEY CALIPER JOINT TABULATION SHEET $1/2" 17# BUTTRESS DRILL SITE #3-01 Body: 0.304 PRUDHOE BAY, AK Upset: 0.304 Suwey # 24108 Chart # M 1396 August 7, 1994 Feeler Ratio I · I Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION NO % INCHES % INCHES COMMENTS o PROFILE(% wALL) 1( 0.1 X-over; Pup Jt.; GLM (1) 0.2 Pup Jt. 1 16 0.05 Line of shallow corr.; 1st full length Jt. of 5 1/2" 17# BTRS below X-over 2 20 0.06 Pits u.B.; Line of shallow corr. (.04") 3 16 0.05 Line of shallow corr.; Scatd. shallow pits (.04") 4 26 0.08 Line of corr. 5 26 0.08 Corr. 6 16 0.05 Scatd. shallow pits; Line of shallow corr. (.04") 7 23 0.07 Corr. 8 20 0.06 Line of corr. 9 26 0.08 Line of corr. 10 33 0.10 Corr. 11 26 0.08 Line of corr. 12 26 0.08 Corr. 13 30 0.09 Corr. 14 39 0.12 Corr. 15 23 0.07 Line of corr. 16 26 0.08 Line of con'. 17 13 0.04 Line of shallow corr. 18 16 0.05' Line of shallow corr. 19 66 0.20 Pits m.B.; C°rr. (.09") 20 3 0.01 Roughness 21 23 0.07 Line of corr. 22 20 0.06 Line of corr. 23 36 0.11 Line of corr. 24 26 0.08 Corr. 25 33 0.10 Con'. 26 30 0.09 Corr. 27 33 0.10 Corr. 28 33 0.10 Corr. 29 36 0.11 Corr. 30 33 0.10 Corr. 31 39 0.12 Pits u.B. & I.B.; Line of shallow corr. (.03") 32 13 0.04 Shallow corr. 33 20 0.06 Line of corr. 34 36 0.11 Pit u.B.; Shallow corr. (.04") 35 23 0.07 Pit I.B.; Shallow corr. (.05") 36 26 0.08 Line of corr. 37 26 0.08 Line of corn 38 10 0.03 Shallow corr. 39 20 0.06 Shallow pit m.B.; Line of shallow corr. (.02") 40 30 0.09 Scatd. pits; Shallow corr. (.04") 41 43 0.13 Pit 1.B.; Line of shallow corr. (.06") 42 26 0.08 Line of corr.; Shallow corr. (.05") 43 13 ' 0.04 Scatd. shallow pits; Shallow corr. (.02") 44 26 0.08 Line of corr. 45 13 0.04 Line of shallow corr.; Shallow corr. (.02") 46 13 0.04 Line of shallow corr. 47 33 0.10 Pit m.B.; Line of corr. (.06") 48 33 0.10 Corr. 49 20 0.06 Line of corr. 50 23 0.07 Line of corr. -BODY m -UPSET KINLEY CALIPER JOINTTABULATION SHEET 5 1/2" 17# BUTTRESS DRILL SITE #3-01 Body: 0.304 PRUDHOE BAY, AK Upset: 0.304 Survey # 24108 Chad # M1396 August 7, 1994 Feeler Ratio 1 · I Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION n PROFILE 10 51 20 0.~ Line of 52 16 0.05 Line of shMlow corn 53 36 0.11 Pi~ I.B.; Line of co~. (.08") 54 26 0.08 Line of co~. 55 26 0.08 Line of co~. 55.1 13 , 0.~ Line of sh~low ~.; ~p Jc; GLM (2) 55.2 10 0.03 Line of sh~low co~.; Pup Jt. 56 20 0.~ Line of ~. 57 13 0.~ Line of sh~low co~. 58 13 0.~ Line of sh~low con. 59 23 0.07 Line of co~. ~ 20 0.~ Line of co~. 61 20 0.~ Line of co~. 62 20 0.~ Line of co~. 63 20 0.~ Line of co~. ~ 20 0.~ Line of co~. 65 20 0.~ Line of co~. ~ 20 0.~ Line of co~. 67 20 0.~ Line of co~. 20 0.~ Line of co~. 13 0.~ Line of sh~low ~. 70 16 0.05 Line of sh~low co~. 71 23 0.07 Line of co~. 72 33 0.10 Line of co~. 73 26 0.08 Line of ~. 74 23 0.07 Line of co~. 75 23 0.07 Line of co~. 76 26 0.08 Line of ~. 77 26 0.08 Line of co~. 78 23 0.07 Line of co~. 79 20 0.~ Line of co~. 80 30 0.~ Line of co~. 81 26 0.08 Line of co~. 81.1 20 0.~ Line of co~.; Pup JC; GLM (3) 81.2 20 0.~ Lineofco~.; ~pJt. 82 23 0.07 Line of ~. 83 30 0.~ Line of co~. 84 26 0.08 Line of co~. 85' 26 0.08 Line of coif. 86 23 0.~ Line of co~. 87 26 0.08 Line of co~. 88 26 0.08 Line of co~. 89 26 0.08 Line of co~. 90 66 0.20 Pit m.B.; Line of co~. (.08") 91 23 0.07 Line of co~. 92 26 0.08 Line of con. 92.1 26 0.08 Line of co~.; ~p Jt.; GLM (4) . 92.2 20 0.~ Line of con.; ~p Jt. 93 20 0.~ Line of con. 94 23 0.07 Line of ~. 95 33 0.10 Line of co~. 96 33 0.10 Line of co~. 97 33 0.10 Line of co~. 98 33 0.10 Line of co~. ~ 30 0.~ Line of co~. 1~ 33 0.10 Pit m.B.; Line of corn (.07") -BODY I -UPSET KINLEY CALIPER JOINT TABULATION SHEET .5 1/2" 17# BUTTRESS Body: 0.304 Upset: 0.304 Chart # M1396 Feeler Ratio I · 1 DRILL SITE #3-01 PRUDHOE BAY, AK Survey # 24108 August 7, 1994 Run # 1 MAXIMUM MAXIMUM UPSET/MAKEUP BODY DAMAGE JOINT PENETRATION PENETRATION PROFILE NO % INCHES % INCHES COMMENTS 0/ 100.1 20 0.06 Line of corr.; Pup Jt.; GLM (5) ~L][ 100.2 26 0.08 Line of corr.; Pup JL 101 33 0.10 Line of corr. 102 36 0.11 Pit I.B.; Line of shallow corr. (.04") 103 23 0.07 i Line of corr. 104 23 0.07 !Line of corr. 105 33 0.10 Line of corr. 106 33 0.10 Line of corr. 106.1 23 0.07 Line of corr.; Pup :It.; GLM (6) 106.2 13 0.04 Linc of shallow corr.; Pup 107 26 0.08 i Line of corr. 108 13 0.04 Line of shallow corr. ,',.., 109 26 0.08 Line of corr. 110 26 0.08 Line of corr. 111 20 0.06 Line of corr. 112 16 0.05 Line of shallow corr. 112.1 33 0.10 Line of corr.; Pup Jt.; GLM (7) 112.2 26 0.08 Line of corr.; Pup Jt. 113 26 0.08 Line of pits 114 16 0.05 Shallow pits I.B. 115 20 0.06 Line of pits 116 23 0.07 Line of corr. 117 16 0.05 Line of shallow corr. 118 33 0.10 Scat& pits; Line of corr. (.08") 119 20 0.06 Line of pits 119.1 33 0.10 Line of corr.; Pup Jt.; GLM (8) 119.2 26 0.08 Line of corr.; Pup Jt. 120 26 0.08 Line of corr. 121 23 0.07 Line of pits 122 20 0.06 Line of pits , 123 39 0.12 Line of corr. 124 36 0.11 Line of pits 125 39 0.12 Line of corr. 125.1 33 0.10 Line of corr.; PupJt.; GLM (9) 125.2 16 0.05 Line of shallow pits; Pup Jt. 126 30 0.09 Line of corr. 127 20 0.06 Line of pits 128 16 0.05 Line of shallow corr. 129 26 0.08 Line of corr. 130 39 0.12 Line of corr. 131 33 0.10 Line of corr. 131.1 26 0.08 Line of corr.; Pup Jt.; GLM (10) 131.2 13 0.04 Line of shallow pits; Pup Jt. 132 33 0.10 Line of corr. 133 26 0.08 Line of con'. 134 26 0.08 Line of corr. 135 23 0.07 Line of corr. 136 33 0.10 Line of corr. 136.1 26 0.08 Line of corr.; Pup Jt.; GLM (11) 136.2 23 0.07 Pits m.B.; Pup Jt. 137 26 0.08 Line of corr. 138 16 0.05 Line of shallow pits 138.1 26 0.08 Line of corr.; Pup Jt. 138.2i139 2316 0.070'05 Line of corr.Shall°w corr.; Flow coupling; Packer Assembly (A) ,' , ',' ,, 140 30 0.09 Scatd. pits; Survey ends in Jr. #140 @ 9~ 100' (WLM) -BODY m -UPSET i i . ~° 's=~9 ) v · .!. I,: '11 ...... - ....... _-- ...__ -- - , ,,I __ L~_ .... - ---~, _ii_ --' ~'1___~_ ' '.,~-- __lq__', . -- ; j I _ IlL L .., · i _ L Ill '~ - ii ...... im j_' : LI ~ ... .. . ~ .... ........ ,, : Ifil --._~' l · . ; ~'IMLD NAME, : PRUDNOE BAY 3GRO,UGH ~ ~?[)RTF~ SLOPE API ;~]Uabgk : 50-029-20187-00 REFERENCE ~'~0 : 94041 RECEIVED MAR 2. 1 1994 Masks Oil & Gas Cons. CommlSslO~ AnChorage PAGE: OPE?I ~OLE C:ASIhG DRILLERS CASING BiT SIZE (.IN) SIZE (I{~) DEPTH (FI) WEIGHT {..}0 0.625 9986.0 47.00 O0 7.000 3038.0 26.00 O~ 5,500 9133.0 17'00 C L,T,9 9S11.5 9 4 7 7. S 9~0r) . 0 9331 .C 92o7.0 PASS 1 TG 'l:'f~E OPg~z HOLE GR PROVIDED dY CLI~:NT. ALL, ~T[imA C~TD CU~VCA~ GP PAS5 I ~E~':,E CARRIED WITH TNAT SHIFT. FTLE '~:!a",~:g : EDIT .001 I),,~TF : 9't103/ 4 PAGE: f:~e~::)t, sht,~tedJ an~ cilpoed curves ~or each oass In separate files, 0.5 (,',) 0 0 S T 0 F~ D E P T H PAGE: 0,5 0 t 0 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000000 PAG£: C~ ~'r. eLTO 4.953 4'803 ,T~:'~ T(: · C N I'~ 30161688 rq'C.C~TO 54,4 ~'~;R,AT (::~1~ {I 7.2~6 Ci,iTC ~',!TD 853 217 CF '" -999.250 1999.250 624.875 595.938 255.513 248,263 ,IS q'ar'e ',:erf~:!catl.¢,n f,ist, inn PAGE: r'~z, th sni£te4 an4 cl~peed curves ~or each pass in, separate files. ~ l L:F' S U ~','~ a a R Y 1.9;~;6 !CCI, CC~L S~i'~[~T DtPi'H S%OP DEPTP a .............. ; .............. 7;'" C ~{,, 957 g. O q250.0 888~ 5 8~887.5 9544,5 9544,0 9535,0 9534.0 951!.0 95i0.5 950~.5 9501.5 9499,5 9497.6 9464.5 948~,0 9482,0 9470,5 946~.0 9a61.~ 94.25,0 9422.5 9400.5 9398.0 9399,5 9397,5 9392.~ 9389.5 935~.0 9358.5 9355,0 9354,0 93~a:0 9348.0 9347.a 9347.0 9330.5 9331.0 9313,0 9~13,5 928g.5 9289.5 9266.5 9267.0 9259.5 9260.5 975~.5 9254.0 !00,0 10!,5 F'E;',~'ARKS: 3'HU 9~?Tki AD,,iIJ¢¥f'>IEN'f'S SHOWN ABOVE REFLECT PASS 2 GRCH, ~0 PASS 1, G~CH, AND PASS 2 '~,~PHI TO PASS 1 NPHI WITH ;~Li.., OT?iE'R C~.~TD CURVES C.ARPt. ED '~ITH TD.E NPHI SHIFTS, LIS Fr'>~,~,~AT OAT~ ,,I8 ~a~'e 'v~riii. catiof TjSt.lno PAGE: (7) 0.5 FT 1 1 bcp? [;' '!' 48~I11 O0 NPHT C~4Tt) pi! ~bSl 1.1 OO O0 ~Ca~' C,~'rD CP~ 4~81,I1 O0 UO NRAT C ~x~ TD 4~iI1 oo OO CMTC CNTi) CP~ 48~1]. I O0 O0 CFTC C.,..i T D CPS 4~g 1 ].. 1 oO uO G~CH C~,,~TD GAPI 488111 OO PT APl TYPE CbASS M 000 O0 0 0 O0 0 o o0 0 O 00 0 O' O0 0 0 00 0 0 O0 0 0 O0 0 0 OD 0 0 O0 0 2 i I 4 68 0000000000 2 I I 4 68 0000000000 2 ! I 4 68 0000000000 I 1 4 ~8 0000000000 ~ 1 1 4 68 0000000000 2 1 i 4 68 0000000000 2 1 i 4 68 0000000000 2 1 1 4 68 0000000000 2 1 1 4 68 0000000000 2 1 I 4 68 GO00000000 D rrp ~'. q 577 500 M P H [, C '] T D 3 2 502 MC N I', C M T D 2530.864 , , ., , ' . C .... · C~AT C~:~TD ~4 344 MRAT.CNTD 5 086 ....bTu CNTD 2528 869 GPC;-~ ~"? .... ~)* ~.~ (' r,~ TD 1410.000 29,590 MC~T.CNTD 3007.875 ,, ~ . ~ ~ ~ , 4 766 CN~.'C.c..~rD 300g.094 14i2.625 FCNT.CNTD CFTC.CNTD FCNT.CNTD CPTC.CNTD 499, 807 629.219 594 · 406 center PAGE: (2PC~::. C'~T~ ...... -c::q'*. 25d TL['~5. C~''~ 6.818 C;~c. CNTD 14~5.000 1816.758 FCNT.CNTD 1853.121. CFTC.CNTD 273.611 254,447 F T l,l!' H E i~.DEIR i. fte~ and clipped curves for each pass i~ separate files, f>eDth sh . . 3 o, 5OO0 ,~T a. RT D~;PTF! 957~,n STOP DEPTH 9?50. o 9250.0 SHIFT b,ATA - PASS TI[) PASSf,f¢~EASUREF~ DEP'fN) P&SI~[,INE CU~V[:] FOR SNIFTS --- E(~UIVALC,-II tJNSNIFTFD DEPTH-- .... ---- GRC~ C%TD 88R~7,0 ~U88 .0 4-~A~-1994 10135 PAGE 9547. n 9546.0 95 rT.0 9516, 9502,5 ~5~:,1,5 94~5,0 9482, 947~. 0 94'15.0 94.~ 4,5 946~, C' 94'2t%. 5 9422.5 '~400,5 939" 5 ~ ~ "~390.5 9396, ':~ 392,5 9389. 9359.5 9358. 935!.0 9350.5 '~31 J. 5 9313. 93fl6. () 9306,0 92f:~ 3.5 9~64. 9760.0 92~1 ,o ~ 0n.0 10~ .0 101. nE;MARKS; Y~,4E DFPTH AJU$[~E~TS 8HOaN ABOVE REFbFCT PASS 3 GRCH, TO PASS 1 G~CH, A~D PASS 3 NPHI TO PASS 1 NPHI WITR gl,b OTHER C~TD CIj~VES CARRIED WITH ThE NMI SHIFTS, $ LIS FORMAT DATA TYPE REPI~ CODE VALUE CblU~nher~er ~sska co~putinc Cent.~r CFTC C~,~T() CPS 4d~l GPCH C?TO GAPI 4,8~1 TF(',jS C.'~TO LP, 4~81 ........ ~; ........ X;'~';' .... [['';I '~ ~ .... ;~' ........... ~[[i~;''' ER¥!CF . I ~P! I PI FI j ],-~ u~$ ZE REPR P ~;:D~ # LOG :tYPE CLASS ROD ~OuS SANP ESEM CODE (HEX) 8111 00 000 00 0 3 i 1 4 68 O000000000 ii 00 0C0 00 0 3 1 { 4 68 O000000000 11 00 00~> 00 0 ] 1 1 4 68 0000000000 Il OO 0Co 00 0 3 I 1 4 68 0000000000 ti O0 000 O0 0 3 1 i 4 68 0000000000 ~.1 O0 000 O0 0 3 ! 1 4 68 0000000000 ll Ob OOO 00 0 3 ! 1 4 68 0000000000 11 0O 0O0 O0 0 3 i 1 4 68 0000000000 11 O0 O00 00 0 3 1 1 4 68 0000000000 11 ~(,) 000 O0 ~ 3 1 i 4 68 0000000000 m#mmm~mmmmmmmmmmmmmmmmmmmmmmm.#m~mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ~'.F'}I CNTD 32 816 NChT.C~TD 25ti8 86 ~R~T.CNTD 5.036 CNTC,C~TD 2540:,60 · ~N$.C~TD 1415.000 ~;PHI,C~TD ;~'RAT.CNTD 'T'6~$.CNTD {JP~I,C~JTD T~TNS. C~'TD 3.0.762. MCNT,CNTD.~ ~T 3010:~25 4,8z47 C~,;$C C~ D 3024 75 1400.000 62596 CFtc.' T C . C~TD 1~72: 1400. 000 FCNT CNTD CFTC:CNTD FCNT CNTD CFTC:CNTD FCNT.CNTD CFTC.CNTD 501,132 470,627 623 375 579~813 283 881 258:062 ........ ,003 VERsin:'~ : n(>~CO1 : °4103/ 4 aF:C S!ZR : 1024 FILE PAGE: 10 AV~]~ a~gC, CURVE5 mo~)ensated ~,~eutron: Arith~,etlc average of edited Passes for all curves. oulsed l.~eutron: L~aaveraged edited Pass ~ Gamma ~my add backro~lnd counts; arithmetic average of edited static oaselJ, ne passes for all ot~er curves. P~.Sg.gS 'T~CLItD~D I~,i RE~'~g~KSI T[ti{ ARITH~qETIC AVERAGE OF PASSES ~, 2 & ] WAS COMPUTED AP rEh A[..,L DEPTH ADjUSTSEP~T8 WERE APPbJ'ED. '~er iiicat i<~n T..,i st ins AlaSKa Cc~putfna Center 4-~;AR-19q4 10:35 PAGE: 11 T~P~ - CHAN Se;~V! A I API AP1 Fl[, UM~ NUMB SIZE REP[{ .PROCESS LOG TYPE CLASS MOD ~LI~B SA~P EbE~ CODE (HEX) 48~111 nO oeo O0 0 4 1 I 4 68 0000000000 465111 O0 OeO O0 0 4 ~ 1 4 68 0000000000 4, a8111 Oo 6¢,6 oO O 4 t I 4 68 0000000000 aS~il! O0 000 Ob 0 4 1 1 4 68 0000000000 4~9ill O0 OeO OO 0 4 i 1 4 68 0000000000 dBtlll ()0 OOO O0 0 4 1 1 4 68 0000000000 4~111 O0 OOO O0 0 4 l 1 4 68 0000000000 4~111 O0 GOO OO 0 4 ], I 4 68 0000000000 4~111 O0 o00 0O 0 4 1 1 4 68 0000000000 4~81t,,1 O0 gO0 O0 0 4 i 1 4 68 0000000000 , * i'.) A 'f A * * DF .pT. 9bLg.O0 DEiPT. 9bO0. O~ ~,i C t,~ ?. CaaV 301 ~. 07 GPCH. C~',~ ~v' 1, 64.56 0 NPHI.CNAV 36.780 NRAT,CNAV 5,5~4 CRAT,CNAV 2 ?CMT. CN'AV ~67.7~3 CNTC. CNAV 2442,276 CFTC,CNAV 5 I ~,NS,CNAV 1.44.0 855 0 NPHI.CNAV 2~.865 NRAT.CNAV 4,805 CRAT.CNAV ': N C. ' """C 3 FC, NT.C AV ~25.7u0 ..hTC.CNAV 3016.417 C~',[ .CNAV 7 'Pn'.,~S C~JAv 1406 609 ?70.074 CD,~TC.CNAV 185 ; CF'T¢.CNAV 5.836 438,727 5 027 589:993 .362 25 .565 FILE ~iAi4g : El)IT .004 S ~'kV!Ct~; ; FblC VPRS I0,'~ : qOtCO1 DA'i'~ : 94/03/ 4 f','~fi.X RI'~?C SIZE : 102~ FTI,,T TYPE : [,, Verification [,istlno 10:35 Curves amd 1o~ header data for each pass in separate F',~8,~- NUUBRR: I D~P'¥H [NCRE~!ENT.'. 0.5000 ~'J ~t) 9586.0 DATE hOGGeD: SOW'IrWARE VERS[P~: TI~4E~ [.,OGGgR 0~ bOTTOm: TOP LOG T~TERVAL (ET): ~OTTOM LOG i~TgAVAt, (FT): LOf;GI~G SPEEO (FPHR): D~P'fH COMTRO~ LISEO o~.OP DEPTH V~NOOR TOOb CODE TOL)[ T~PE C~TD CASlN~ COLL~ bOG C ~TD I~EbEMETPY CARTR!PGE C ~,~ T D C~4PENSATED NEUTRON POREHOLE A,~,~D CASING DATA ~P. gN Hobg 3IT SIZE (IN): DRIL!,EPS CASING DEPTH bOGGER$ CASING DE:i?T~ files; raw bacKoround pass in last 5-FEB-94 9582.0 9250,0 9O0 ~ 9996.0 FLUIDS IS ?a~e VerIi.icat~on l~istino chlutr, her~,)er AlaSKa Computln9 Center ~! E I TH ER SANDSTONE BLUELI.hE CO.Ui~T ~ATV2 !~OR~'4A!.,IZAT1Oh~ ],N OIL ZO~IE TCP ~,~i]R~sbIZING Wtb'~DO~n (FT): BASE :,OR~ALIZI?,iG ~INDOW (FT): rA~ CG['NT ~'ATE l,O;~ SCAr,C (CF'S): 0 F,~n Ct.,t~,,~ ~A~E HIGH ~.~AI.E (CPS). 2000 .. ;'~.~S~. LGW sCAt, E (CPS); 0 2EAR COJ~T RATE HiGH SCALE (CPS J: 10000 TIe-in,I: 6w$ CNh 5/8/83 t. nree passes loused at 90n ft/ar all p~sses loqqed on sandstoDe matrix count ra~e normal ?I zatz[ol9 performed from 9400-9500'md averaQe c~orosJtv computed usinq nodc~e$-leymann compo/ation b!S FrT~R~AT DATA PAGEI 13 ** PA?R FORe, AT SPFCIFICATIt)M ~ECORD ** TyPE REPR COD~ VALUE 2 66 5 66 7 65 6 68 0,5 9 65 FT 11 66 ,23 ~3 66 0 i$ 'r~ne ~/er.i fication f,i, stipq ,chlu~;berqer Alas~.a Computi~ Cen%er 994 I 0: 35 PAGE: 1,4 **,sET "'¥~it;. - CWAN ** '';~ ............ aF S~]Rv U~: i7';;;:;~ ............ ~PI ~PT ;;i ......... API Fib [ .......... NU,',~iS ~IU ~'""~{~"~E~;S .... Pg;~;'" "Yp- bOG i ..~ CLASS MUD NU~S SA~P MLEN CODE (HEX) DEPT FT 48~11. I 90 000 O0 0 5 1 1 4 68 0000000000 ~P~'~ PSl ~)) a8811,1 O0 O00 00 0 5 1 1 4 68 0000000000 RT~i~ PS1 4~11.1 (?G O0O O0 0 5 1 1 4 68 0000000000 T~R~ PS1 4~111 60 uOO 00 O 5 1 1 4 6~ 0000000000 RC;~~' PSi CPS 46a111 00 0O0 O0 0 5 1 1 4 68 0000000000 RCF? PSI CPS 488111 0O 000 00 0 5 1 I 4 68 0000000000 CN~C PSi. CPS 48~111 00 00g 00 0 5 1. I 4 68 0000000000 CFTC PS1 CP~ 4~$111 00 00O O0 0 5 I 1 4 68 0000000000 G~ PSI GIPI 4~8111 O6 000 00 0 5 1 I 4 68 0000000000 TENS PS1 LB 46~111 o0 000 00 0 5 I 1 4 68 0000000000 CCL PSi V 4~8111 nO gO0 O0 0 5 I 1 4 68 0000000000 ' ~ ~ ' PSi 64'1.433 CNTC,P$1 DgPT 9500-00~ ,.~}t~.P51 g7,999 RTNR,.BS1 a C ~:~ ?, P $ ! 3 0 7 9.2 4, 5 R C V T. GP PSt i.~2 gOO ~ENS PS1 1365.000 C L.PSt 333 TNRA.PSl 387 CFTC,PSI 000 4,685 TNRA,.PSl 3060.307 CFTC.PSI 0.000 7.136 T~RA.PSl 1881,3 2 CFTC.PSi 0.0~0 5,585 455 ' 210 634,315 PAgg~ 15 **** FTb? 14EA f~FE **** SFRV1CE : PL~'C U~I~F : 941011 4 ~,.~X aFC STZP: : 1.024 Curves aha log ~eader data for each pass in separate STOP DEPTH ~A~E BOGGED: SOFTWARE ~FRSION: TO [)RIbD.ER (PT): POT~O~l LOG INTERVAL (CT): LUf;GI~G SPEED (BPHR): D~;P'i'H CONTROL I~$~ (YES/NO): , ...... ,"~ ., ~ . C~'~Tm C~'qTD C~Sl~i(; COI.,hA~ bOG C~.~TD I'EI';E/qETR ~ CARTRIDGE C~,~ T D CnhPE~SATED NEUTRON files; raw bac~oround pass in last fi 5-FEB-9.4 9582.0 958n.o 9250.0 9576.0 90O. 0 chl'-~m~,er~ier Alask'a ~omPuti:'lq Cer~tCr FLUID ~RLI:~ITY {PPis): ~,:!'IKR CUTS (PCT): CHOKE (DEC): i?i A T P I X: i,iATRiX Dg~:~q ~ TY; g~86.0 Pt:!ODUCED FLUIDS SANDSTONE ~[,U~LTNK CDUNT RATE ~:J(!RI'~ALIZATIDi,~ ],,N OIL TOP ~:OR~,ALIZING ~:~:!')0~, (FT): BASE ~-:,O~A~,IZI~]G ~,~,:l;~POW ~aP COUHT RATE I~ ~CALE (CPS): o FAP C&I,:NT PATE HIGH SCALE (CPS]: 2000 NEaR COUNT RaTE [,~)W ~CALE (CPSC: 0 SEAR C~.~:',:T ~'I'E HJ.f';H SCALE (CPS)~ JO000 TIE-IN: SWS C~L 5/8/83 three passes loaded at 9(i)0 ft/hr all passes loqged on sandstone matrix co%~nt rate normalization performed from 9400-9500'md averaae poros~.t¥ compute~ using hod~es-leyma~n compgtatton $ bTS FORe, AT DATA PAGE: ** PATA FORMAT SPKCIFIC.~TIQN RECORD ** ** ~wT YPE 6 TYPE; REPR C[JD~ VALUE . 4-~AR-~994 10:35 PAGE: 17 3 73 APl API E r]UNB NUmB SIZE R PR PROC K CLASS ~OD NUMB SA~P EbEM CODE (HEX) D~p'r ?T 488ill O0 000 O0 0 6 1 i 4 68 0000000000 ~PHT P~2 PIJ ~8111 ,.~v GOO O0 0 6 1 I 4 68 0000000000 ~.~i~J'!~ P~j~ ~8~1~1 OO UO0 O0 0 6 i I 4 6~ O000000000 T,..,:<~, PS2 4U8111 oo oOo O0 0 6 i I 4 68 0000000000 ~Cr~T P$~ CPS 48~111, O0 000 oO 0 6 1 I 4 68 0000000000 ~CF* PS? CP~ 48~11! ¢)~ t,)O0 O0 0 6 1 I 4 60 0000000000 C~TC PS2 CPG 48811.! O0 oOo O0 0 6 1 I 4 68 0000000000 C[TC ~52 CP~ .188111 O0 t~t)o O0 ~) 6 1 1 4 68 0000000000 GR PS2 GAP! 4~811,~ (~0 ()00 O0 0 6 1 ~ 4 68 0000000000 ..o2 L8 4,89111 Oo t')oO O0 o 6 ~. i 4 68 0000000000 * * D A T A * * DF:pT 958o.00~ NPHI,[.S2 "~1 595 RTNR,PS2 5,000 TNR ,PS2 Rr',;,~'P<?">..,, ~. o,., 25¢J.6~5. PCFT.PS2 516.129 Cr,,ITC.PS2 2585.315 CFTc.PS2, G~ PS~ 91 250 TE~5 PS2 1070 000 CCB,PS2 0 000 ', . ., t,.:2 51 765 [~T:JR.PS2 7 122 :NRA,PS2 ~'~C~'';'' .... PS2 2 6:852 CNTC PS2 18~4:784 CFTC*PS2 ~ ~ .~5'2 ~8~! 81.7 [~CPT* 5 , 5~. P52 32d.(;00 ~r~::~,~:3. ~S 2 i42S.000 ce.~].ps2 o.ooo 5,,236 493,756 4,840 623.738 ,IS Tan, e u'er~i~.!c~ti,')n l,istino, ;chiu~,er~.~.r a~,asKa ~omputine ('.enter PAGE: 18 5FR'V ICk ; FbIC b ~;. T~ : 0410]/ Curves ar~,d lon header 4ara for each pass in separate PASS ~'~ ti~4 b~R: 3 DFPwH t~,ICPE~'~F;{~',~': 0.5000 VE~;:[)OR 'I.'~C![~ CODE STla'~ DEPTH STOP DEPT~ C ~ ~' t,,~ 9585.5 9240.5 SOFTWARE VERSION: mt,:: bOGGEP, (PT): :I?CJO[, ST~ING {TOn TO 80'I'TO~'t) C~:~TD $ 5-FE~-94 CP ]~.2 9582 9250.0 9576,0 900.0 flles~ raw background pass ,in last fi Lt,.)GGER$ CAMI~t; [}~.:P'rrt (FT): FLUIO TYPk: ~'LOID D[~;$ITY (bB/G): ~"LU.iP LF, VEI~ (PT) ~ CHOKE (DEC): PRODUCED FLUIDS 2.65 BASE ~"~OR~gI.,IZING ~.,I.r~DOW (FT): f~.[,l!e.:t, INE,.. ('r~ij.~.*T,, .. . ~..iF SCALES SET BY FIELD. E~4GIIX.~EER. ~,~EAR COU~.~T RAT~ LOW SCAhE (CPS): 0 fOCaL STAD,~DOFF (l~J: TIE-IN: SW$ CK,~.~ 518/83 three passes !o~oed at ouo fi/hr ali passes l,,oa~ma on sandstone matrix count rate nor~altzatio~ Der~ormed fro~, 9400-9500'md averaoe porosity computeCi ~,lsing .Odqes=l, eymann computation 19 ** S~:T TYPE - e4EB ** TYPE REPR CE>DE VALUE t 6 b (} IS ~a~e verification Listino PA~ 2O ** SET TD O~ER # DFPT ~'T 488111 00 000 00 0 ~PHI P$~ PU 48~111 O0 CO0 O0 0 RT~ PS3 48211.1 O0 000 O0 0 ',t'~R~ P~s3 4,8~111 On 000 O0 0 RC~'r P53 CPS 4.~111 Oc uoo O0 0 RCBT P83 CPS 488111 06 000 CfTC PSt CP5 488111 O0 000 O0 0 CP' I'C P53 CPS a~al!.! Of oOu O0 0 G~ P~3 GAPT 488111 O0 000 O0 0 CC~ P53 } 488111 O0 ~0O 00 0 TYPE '-' Ct!AM ** ..... APl bPI ~PI FI E txtUg, g N ~ SIZE PR PROCESS LOG ~'YPE CbASe,.,, W, OD ~tUMB S~HP EDEi( CODE (HEX) 7 i 1 4 68 0000000000 7 ~ 1 4 68 0000000000 7 I 1 4 68 0000000000 7 I t 4 68 0000000000 7 I i 4 68 0000000000 7 ! 1 4 68 O000O00000 7 i 1 4 68 0000000000 7 1 1 4 68 o000000000 7 I I 4 68 0000000000 7 I 1 4 ~8 0000000000 7 ~ I 4 68 0000000000 DFPT. 9249. 500 i>l pa.1;. PS3 RCi,~?. ~53 t8,,73.764 RCFT.PS3 GP.PG3 i§'~.125 TEf';b. PS3 3~,.574 RT~!.R.P$3 5. CFTC:PSI 475.836 CNTC.P$3 2542, . 1030.000 CCL~P$3 0.000 28.722 641.439 CNTC.PS3 304i:480 C8 IC.PS3 1440.ou0 CCL.PS3 0.000 2b150'0°7'497 CN...C.R~b~R'PS3T~ P83 .1880:7 ~ CFTC.ps~TMRA'PS3 1415.000 C(.~b. PS3 Oi 000 5.585 455.210 4 ~88 618:71 7~3~5 253o517 18 '!'a~e veI'ifica%fon L1$t.ir:q cPl!.~n, ber,'4er AlaSKa Co,r, put:l.a,:~ C'~Pter PAGEt 21 11 000000 7777777777 000000 7777'777777 11 000000 77'77777777 000000 7777717777 1111 O0 O0 77 O0 O0 '17 1111 O0 O0 77 O0 O0 77 11 O0 0000 77 O0 0000 77 11 O0 0000 77 O0 0000 77 11 O0 O0 O0 77 O0 O0 O0 77 11 O0 O0 O0 77 O0 O0 O0 77 11 0000 O0 77 0000 O0 77 11 0000 O0 77 0000 O0 77 11 O0 O0 77 O0 O0 77 11 O0 O0 77 O0 O0 77 111111 000000 77 000000 77 111111 000000 77 000000 77 666696 000000 5555555555 2Z2222 222222 666666 000000 5555555555 222222 222222 66 O0 O0 55 22 22 22 22 66 O0 O0 55 22 22 22 22 66 O0 0000 555555 22 22 66 O0 0000 555555 22 22 66666666 O0 O0 O0 55 22 22 666~6666 O0 O0 O0 55 22 22 66 66 0000 O0 55 22 22 66 65 0000 O0 55 22 22 6b 66 O0 O0 55 55 22 22 66 66 O0 O0 55 55 22 22 066666 000000 555555 2222222222 2222222222 666666 000000 555555 2222222222 2222222222 GGGG H H BBBB PPPP RRRR U U DDDD H ~ 0OO ~LEEE G H H B B P P R R O U D D H H O O E G H ~ B B ~ P R R U U O D H H O 0 E G HHHHH BBBB ..... PPPP RRRR U U D D HHHMH O 0 EEEE G GGG H H B B P R R U O D O fl H O O ~ G G H H B B P R R U U D D ~ H O O g GGG H. H BBBB P R R UUUUU DDDD H H DUO EEEEE *START* USER PCAL [10707,605221 dO~ SHIP SEQ. b463 DATE 03-dOh-80 14:5'7:31 MONITOR SWS ~LIOE]7 APR-80. *START* *START* USER PCAL [10707,60522] dOB SHiP SEQ. 6463 DATE O~-dUh-80 14:57:31 MONITOR SWS KLIOE~7 APR-80 *START. SSSSSSSS HH HH SSSSSSSS HH HH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSS HHHHHHHHHH SSSSSS HHHHHHHHHH SS HH HH SS HH HH SS HH HH SS HH HH SSSSSSSS HH HH SSSSSSSS HH HH II II II Iiii Illi II ii ii II II II Ii Ii II II IIII Iili PPPPPPPP PPPPPPPP PP PP PP PP PP PP PP PP PPPPPPPP PPPPPPPP PP PP PP PP PP PP TTTTTTTTTT O000OO TTTTTTTTf~ 000000 TT O0 TT O0 O0 TT O0 O0 TT OO TT O0 O0 TT OO O0 TT O0 O0 TT O0 O0 TT O0 O0 TT OO OO TT O.O0000 TT 000000 *START* USER PC,AL [10707,60522] JOB SHiP SEQ. 6463 DATE 03-OUL-80 MONITOR SWS ~L10~37 APR-80. *START, FILE: DSKM:SMIP.TU<255>[10707 60522] CREATED: 03-juL-80 i4:41:57 PRINTED: O]-JUL-80 I~:57:4§ QUEUE SWITCHES: /f'ILE:FURT /COPIES:I /SPACING:! /LIMIt:lO6 /FORMS:NORMAL 14:57:31 SHIPPING INSTRUCTIONS ISSUED I-JUL-80 1~:41 SHIP TO : VENTURA, CALIf~ORNIA 93003 PCCC BY GHB PCCC VV VV ' VV VV VV VV VV VV VV VV VV YV EEEEEEEEEE R~RRRRRR V¥ EE~i;EEEEEEE RRRRRRRR VV gE RB RR VV EE RR RR VV EE RR RR VV 5E RR RR VV E~ELEEEE RRRRRRRR VV ELEEEEEE RRRRRRHR VV EE RR RR VV EE RR RR VV EE 2H RR VV Ek RR RR VV EEELLEEEEE RR RR VV E~EEEEEEEE RR RR III III I 1 i I I I I I 1 I iii III III II1 I I I i i I I I I 1 III III YY YY YY XY XY YY YX YY ~Y YY YX 000000 000000 666666 000000 000000 666666 00 O0 00 00 66 00 O0 00 00 66 00 0000 00 0000 66 00 0000 00 0000 66 00 00 O0 00 00 00 66666666 00 O0 O0 00 00 O0 66666666 0000 00 0000 00 66 0000 00 0000 00 66 00 00 00 00 66 00 00 00 00 66 000000 000000 666666 000000 000000 666666 66 66 66 66 ~START* USER PCA6 [10707,60522] dOB SHIP SEW. MONITOR $~$ KL10E]7 APR-80. *START* FILE: DS~H:VERIFY.006<057>[107~7.b0522] CREATED: PRINTED: 03-JUL-80 14.57:57 QUEUE SWITCHES: /flLE:fURT /COPIES:I /SPACING:I /blMIT:i06 /FORMS:NURMAL 6463 DAT~ 0~]-JU6-80 03-OUL-80 14:55:57 14:57:31 SCHLUMBERGER COMPUTING C~NTER 10707,~O522 REEL HEADER LENGTH: 132 ~YTES REEL NAME: P.C.A.L. SERVICE NAMe: EDIT REEL CONTiNUATiON NUMBER: 01 PREVIOUS REEL NAME: COMMENTS: LiS FORMAT CUSTOMER ~APE DATE: 80/ 7/ 3 TAPE HEADER LENGTH: 132 ~YTES TAPE NAME: 60522 SERVICE NAME: EDIT TAPE CONTINUATION NU~OER: PREVIUU$ TAPE NAME: COMMENTS: DATE: 80/ 7/ 3 EOF FlEE HEADER, LENGTH: 62 BYTES FILE NAME: EDiT .001 MAXIMUM PHYSICAL RECORD LENGTH: 1024 BYTES PREVIOUS FIL~ NAME: FiLE COMMENTS THE LAST NPHI IS FROM A DIGITIZED LOG RUN ON 16-APR-77. WELL S1T~ INFORMATION RECORD LENGRH: CtiMPANY: ~ELL: FIELD: RANGE: TO~N: SECTION: COUN~I'~: STATE: 184 BYTES AT6ANTIC RICHFIELD CO. D.S. 3-I PRUDHOE BAY 10N NORTH SLOPE ALASKA DATA ~02MAT SPEC1FiCAI'iON LENGTH: 290 UYTE6 ENTR~ BLL)C~,S: TYPE 0 SIZE 1 REP CODE ENTRY 0 DATUM SP~CIF'ICATIUN BL, OCK$: ENTRY IC TOOL 1 DEPT 2 G~ CNL NPHI CNL 4 NRAT CNL 5 NCNL CNL 6 FCNL CNh 7 NPHi CNL UNITS ;%PI AP1 AP1 API FIbE# SIZE EXP PROC SAM REP DEPT SHIf'T ~'T 0 0 0 0 0 4 0 0 I 68 0 0 GAPI 42 31 32 0 0 4 0 0 ! 68 0 0 PO 42 68 3 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 34 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 PO 42 68 3 0 0 4 O 0 1 68 0 0 DEPTH 9830,000 9800.000 9700.000 9600.000 9500.000 9400.000 9300.000 9200.000 9175.000 MNEMONIC GR FCNb G~ f'CNL GR FCNL GR F'CNb FCNJu GR fCNL GR FCNL GR FCNL V Ab -1 0 21 75 17 96 18. 81. 20. 83. 44. 93. 75. 48. 91. 48. -1200. -999. UE .000 .000 .671 .504 .711 .954, 503 510 285 655 045 522 527 O48 169 9O6 100 250 MN E~ONIC VALUE NPHi -0.020 NPHI 35.053 NPHI 34.360 NPHI 30.531 NPHI 25.320 NPHI 29.094 NPHI 33.340 NPHi 33.969 NPHI 31.3%0 NPHI 29.578 NPHI 27.260 NPHI 23.734 NPHI 48.350 NPHI 50.188 NPHI 45.400 NPHI 44.969 NPBI -99925.000 NPHI -999.250 MNEMONIC NgAT NRAT NRA~ NRAT NRAT NRAT NRAT NRAT NRAT VAGUE 0.000 3.402 2.850 3.272 3.232 2.936 4.lb0 4.170 -999.250 MNEMONIC NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb NCNb VALUE 0.000 249.249 278.850 259.116 270.270 260.832 204.533 209.352 -999.250 SUMMA~ O~ DATA N[]MBE~ 0~' RECORDS: 37 LENGTH Of RECORDS: 1014 BYTES LENGTH OF' LAST RE. CORD: 426 8¥TE$ fILE THAILER LENGTH: 62 BYTES FiLE NAMk: ED1T .001 MAXIMUM PHYSICAL RkCORD LENGTH: NEXT ~'iLE NAME: EOF 1024 BYTES TAPE TRAILER LENGTH: 132 B'YTES 'rAPE NAME: 60522 SERVICE NAME: EDIT TAPE CONTINUATION NUMBER: 01 NEXT TAPE NAM~: C{)MMENTS: DATE: 80/ 71 3
