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XHVZE Pages NOT Scanned in this Well History File This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE RESCAN [] Color items - Pages: [] GraYScale, halftones, pictures, graphs, charts- Pages: [] Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type 'OVERSIZED .Logs of various kinds [] Other Complete COMMENTS: E] Scanned by: ~ver~j Mitdred. Daretha~~owell , TO RE-SCAN Date: ~/~' /s/ /~ m , · Notes: Re-Scanned by; E~va.y Mildred Daretha Nathan Lowell Date: /si RECEIV STATE OF ALASKA DEC 19 201 ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOASOGGC 1a. Well Status: 0 Oil ❑Gas 0 SPLUG 0 Other 0 Abandoned ❑Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero 0 Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 11/26/2013✓ 197-140 313-439 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 08/26/1997 50-029-20442-01-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 09/21/1997 PBU 02-01B 651'FNL, 1696'FWL, Sec.36,T11N, R14E, UM 8. KB(ft above MSL): 65 15. Field/Pool(s) Top of Productive Horizon: 898'FSL, 1721'FWL, Sec.25,T11N, R14E, UM GL(ft above MSL): 30' Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 2908'FSL, 1513'FWL, Sec.25,T11N, R14E, UM 2914' 2912' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 688439 y- 5950571 Zone- ASP4 11772' • 8858' ADL 028308 TPI: x- 688425 y- 5952121 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 688165 y- 5954124 Zone- ASP4 None 18. Directional Survey: 0 Yes ®No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD, GR 9327' 8790' 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 Surface 75' _Surface 75' 32" 350 sx Arctic Set II 13-3/8" 72# L-80 Surface 2690' Surface 2689' 17-1/2" 2700 sx Fondu 9-5/8" 47# L-80 2082' 9327' 2082' 8790' 12-1/4" 1200 sx Class'G' 2082' 7" 29# L-80 2968' 8516' 2966' 8119' Scab Liner 992 sx Class'G' 3-1/2" 8.81# L-80 8610' 11772' 8201' 8858' 4-1/2" 35 Bbls LARC 24. Open to production or injection? 0 Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) 4-1/2", 12.6#, 13Cr80 x 3225'-8605' _ 8411'/8026' 5-1/2", 17#, L-80 8505'-8645' 8595'/8188' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED SEAMED MAY 2 .1 2014 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 ®No Sidewall Core(s)Acquired? 0 Yes 0 No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBEMS MAR 21 2,,,1-a Form 10-407 Revised 10/2012 CONTINU DON REV RSE Submit Original Only ver ��Z3 /�� ,, 0��7 }mss u"�`� Only/ 29. GEOLOGIC MARKERS(List all formations an kers encounter 30. FORMATION TESTS NAME MD TVD Well Tested? 0 Yes ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 8871' 8418' None 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: Jacob Thompson,564-5579 Email: Jacob.Thompson@bp.com Printed Name: Joe Lastu a Title: Drilling Technologist n Signature: `J Pho a 564-4091 Date: 12-II41/13 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only WELL NAME: 02-01 B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used -8425' 15 Bbls Class 'G' 8320' - 8325' Tubing Punch -7204' 32 Bbls Class 'G' 3225' Tubing Cut and Pulled 2937' Set EZSV 2914' Set Whipstock 02-01 B, Well History (Pre Rig Sidetrack) Date Summary 09/11/13 RAN 3.80 CENT,3.74 LIB,SAT DOWN ON ENTRY GUIDE @ 9590'SLM. GOOD IMPRESSION OF TOP OF ENTRY GUIDE.RDMO. 09/12/13 T/I/O =VAC/780/870.Temp. =SI.TBG FL(Full-Bore call in). No AL.TBG FL near surface. LRS in control of well. IA, OA=OTG. 1500. 09/12/13 T/I/O-2370/260/235 Temp. -SI Injectivity Test, MIT IA***PASSED***to 3500 psi. MIT OA_to 2500 psi. (Data for P&A design) Performed an injectivity test down the tubing with 10 bbls of neat and 286 bbls of 120*F 1% KCL(see data tab for rates and pressures). 09/13/13 MIT-OA***PASSED***to 2500 PSI. (See log and data tab for details). SwV, WV, SSV=Closed, MV=Open, IA/OA=OTG. FWHP=0/248/207. 09/14/13 T/I/0=SSV/0/0 Temp= SI PPPOT-T(PASS) PPPOT-IC (PASS) Pre RWO. PPPOT-T: Stung into test port(0 psi.). Functioned LDS, all moved freely(1"). Single port. Pressured test void to 5000 psi.for 30 min.test. Lost 150 psi. in 15 min. Lost 50 psi. in second 15 min. (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(0+ psi.). Bled void to 0 psi. Functioned LDS, all moved freely(3/4"). Pumped through void, good returns. Pressured test void to 3500 psi.for 30 min.test. Lost 50 psi. in 15 min. Lost 0 psi. in second 15 min. (PASS). Bled void to 0 psi. 10/09/13 T/I/O 2000/241/100 Temp=Sl Assist Schlumberger with Fullbore P&A Stage 1 (cement job) LRS pumped 5 bbls of amb meth. SLB pumped 135 bbls of 115* 1 % KCL. 10/10/13 SLB pumped an additional 82 bbls 115* 1% KCL down Tbg followed by 2 bbls of fresh water then 15 bbls of 15.8 PPG G-Cement then another 7 bbls of fresh water. LRS pumped 123 bbls of 50* Diesel. T/I/0=500/314/847 SV,WV,SSV=C MV&CV's=OTG DSO notified upon departure. 10/12/13 RAN 3.25 CENT,4 1/2 BRUSH,5' STEM,4 1/2 BRUSH,BRUSHED TREE DOWN TO TBG HANGER. RAN 3.5 CENT,2.5 S.BAILER,SAT DOWN @ 8416'SLM. RAN 2.50 CENT,1 3/4 S.BAILER,SAT DOWN @ 8425'SLM, ESTIMATED TOC @ 8425'SLM, (small sample of cement). 10/13/13 T/I/0=595/191/88.Temp= SI. MIT-T to 2500 psi**PASS on 10th attempt**(Pre-rig). No AL.T FL @ surface. IA FL near surface. Pumped 2.6 bbls total on all tests. Final test:TP lost 16 psi in 1st 15 mins& 5 psi in 2nd 15 mins for a total of 21 psi in 30 min test. Bled TP from 2484 psi to 190 psi (2.3 bbls fluid) in 6 mins. Job complete. See log for additional details. Final WHPs= 190/183/89. SV, WV&SSV=C. MV=O. IA&OA=OTG. NOVP. 10/17/13 INTIIAL T/I/O= 120/250/0. RIH W/5 FT TBG PUNCH-4 SPF. SHOT INTERVAL=8320'-8325'. GOOD INDICATION OF FIRING. COMMUNICATION OBSERVED W/A 250 PSI INCREASE IN TUBING PRESSURE AND A DECREASE IN IA PRESSURE. CCL TO TS =5.5'CCL STOP DEPTH =8314.5' CORRECTED TO TUBING TALLY DATED 6-14-2008. WELL SI AND HANDED OVER TO DSO. FINAL T/I/O=380/150/0. 10/19/13 SLB and LRS arrive on location and spot equipment. Hold PJSM. Prime lines and perform SLB low and high PT. 10/19/13 T/I/0=460/180/80 Temp= SI Assist Schlumberger w/P&A, Stage 2 (Sidetrack) Load fluids, Road to location& RU. Page 1 of 3 02-01 B, Well History (Pre Rig Sidetrack) Date Summary 10/20/13 Assist Schlumberger w/P&A, Stage 2 (Sidetrack) Speared into Tbg w/5 bbls 36*neat methanol taking resturns up IA over to 02-39 to production. SLB pumped 380 bbls 1% KCL. LRS pumped 2 bbls 36*neat methanol, 154 bbls 40*diesel&2 bbls 36*neat methanol. SLB pumped 104 bbls 1% KCL. Cement mixing issues.Job restarted from beginning. Speared into Tbg w/2 bbls 36*neat methanol followed by 154 bbls 30*diesel&2 bbls 36*neat methanol. SLB pumped 104 bbls 1% KCL, 30 bbls 15.8 ppg G- Cement, 7 bbls FW&69 bbls 1% KCL. LRS pumped 2 bbls neat methanol &36 bbls diesel to freeze protect Tbg. Freeze protect flowlline on 02-39. Pumped 10 bbls neat methanol,followed by 102 bbls of diesel. FWHP's=88/144/373. 10/20/13 Continue to PT surface lines. Pump 5 bbls Neat Spear, 380 bbls 1% KCI, 158 bbls DSL„ 104 bbls 1% KCI, 30 bbls 15.8 ppg Class"G"CMT, 7 bbls Fresh Water, 69 bbls 1% KCI, and 39 bbls DSL. SSV,WV& SV,=C; MV=O; IA&OA=OTG. FWP=T/IA/OA=214/199/436 psi. Length of CMT Plug=934' in TBG and 1018' in IA. Depth of CMT Plug=8425'. Type of CMT=Class"G". Weight of CMT Slurry= 15.8 ppg. Volume of CMT slurry pumped=32 bbls. Compressive Strength (UCA)= . Pressure Tests=2500 psi. Nagative Pressure Test= N/A. Depth of Tag=7204'SLM. 10/21/13 T/I/O vac/vac/67 Temp=S/I (SIDETRACK) CMIT TxIA to 2500 psi (PASSED) Pumped 6.13 bbls 40*diesel down TBG bleeding over to IA to reach test pressure. 1st 15 min TBG/IA lost 16/20 psi. 2nd 15 min TBG/IA lost 13/17 psi for a total loss of 29/37 psi in 30 min. Bled back-4 bbls.Tags hung DSO notified, Valve positions SV WV SSV=closed MV IA OA=open FWHPS=22/22/94. 10/23/13 DRIFT W/3.70"CENT,2.50"S-BAILER TO 971'SLM. DRIFT W/KJT, 3.25"CENT, 1-3/4"S-BAILER TO 973'SLM. DRIFT W/KJT,2.70"CENT,2.50"S-BAILER TO 7,204'SLM. RAN KJT,4-1/2" BLB, 3.25"G- RING TO 2,150'SLM. RAN KJT,4-1/2" BLB, 3.805"G-RING TO 2,150'SLM. 10/25/13 INITIAL T/I/O=0/0/0 PSI. RAN IN W/3.475" POWER CUTTER&CUT TBG @ 3225' (good indication at surface when cut and visually confirmed good cut once at surface). TIED INTO TBG TALLY DATED 06- 14-2008. FINAL T/I/O=25/0/0 PSI. 10/26/13 T/I/O=34/34/34. CMIT TxIA**PASSED**3500 psi. Pumped 7 bbls neat methanol down IA to reach test pressure.Test#1 15 min TxIA lost 109/109 30 min TxIA lost 63/63. Repressure TxIA with .39 bbl neat. Test#2 15 min TxIA lost 54/50. 30 min TxIA lost 42/42. Repressure IA with .17 bbls neat. Test#3 15 min TxIA lost 36/33. 30 min TxIA lost 27/27. Repressure IA with .17 bbls neat.Test#4 15 min TxIA lost 25/23. 30 min TxIA lost 19/19.Total loss in 30 mins on test#4 TxIA is 44/42. Bleed TxIA back to 7/11 psi. Bled back 7 bbls. DSO notified of well status and tree valve positions as follows: SV,WV,SSV=closed. MV=open. IA and OA open to gauges. FWHP=7/11/36. 10/28/13 T/I/O=40/90/40.Temp.= SI. Bleed WHPs to 0 psi (Pre Rig). No AL. Bleed TP from 40 psi to 0 psi in 1 min., bled IAP from 90 psi to 0 psi in 5 min., bled OAP from 40 psi to 0 psi in 1 min. Monitored for 30 min. Final WHPs=0/0/0. SV,WV=C. SSV,MV=O. IA&OA= OTG. NOVP. 1100 hrs. 10/30/13 T/I/O=0+/10/10.Temp=SI.WHPs(Post bleed). No AL. IAP and OAP increased 10 psi since 10/28/13. SV,WV=C. SSV, MV=O. IA, OA=OTG. NOVP. 13:10. 11/04/13 T/I/O=MV/3/13.Temp=SI.WHPs(Pre Rig). No wellhouse or scaffolding. No AL. SV,WV, SSV, MV= LOTO. IA, OA=C. NOVP. 0915. 11/06/13 T/I/O=SSV/5/11.Temp.=SI. Bleed WHPs to 0 psi (Pre Rig). IA&OA FL near surface. Bled IAP from 5 psi to 0 psi in 3 min. Bled OAP from 11 psi to 0 psi in 10 min. Monitor for 30 min. WHPs unchanged. Final WHPs= SSV/0/0. SV,WV,SSV,MV=C. IA&OA=OTG. NOVP. 1300 hrs. Page 2 of 3 02-01 B, Well History (Pre Rig Sidetrack) Date Summary 11/08/13 T/I/0=SSV/0/10. Temp= SI.WHP's (Pre Rig). No well house, scaffolding or flowline. Plywood over cellar. SV, WV, SV= C. MV=0. IA, OA=OTG. NOVP. 0430. 11/10/13 T/I/O =0/0/0. Install Temp Valve#43(FMC Model 120 2-1/16") I/A Piggyback. Verify/PT VR plug in O/A pad side. Final WHP=0/0/0. 11/10/13 T/I/0=0/0/0. Set TWC#289 Pre Rig. Removed upper tree, installed dry hole temp valve#21. See log. Final T/I/0=0/0/0. 11/10/13 T/I/0 =TWC/0/0. Install integral blind flange w/90&block valve. Final WHP=TWC/0/0. Page 3 of 3 North America-ALASKA-BP Page 1 X29 Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date. X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud DateTme:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01©77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/15/2013 00:00 - 03:00 3.00 MOB P PRE RIG DOWN -PJSM -PERFORM DERRICK INSPECTION -UN-PIN BLOCKS -BRIDLE UP -STOW OFFLINE STAND BUILD CRANE -STOW IRON DERRICKMAN MOVE PIPE SKATE INTO LOWERED POSITION CHECK AIR IN TIRES 03:00 - 06:30 3.50 MOB P PRE RIG DOWN -GREASE BRIDLE LINE SHEAVES -SECURE HOSES AND LINES IN DERRICK -UN-PIN TORQUE TUBE -FUNCTION TEST SKIDDING CYLINDERS -PIN ST-80 INTO POSITION -HOOK UP WINCH TO CATTLE CHUTE -BLOW DOWN STEAM LINES -MOVE WALKWAYS ON ROOF 06:30 - 08:00 1.50 MOB P PRE RIG DOWN -SKID RIG FLOOR -PLACE CATTLE CHUTE IN MOVE POSITION 08:00 - 10:00 2.00 MOB P PRE RIG DOWN -PJSM FOR DERRICK LOWERING -COMPLETE DERRICK LOWERING CHECKLIST -LAY OVER DERRICK _ 10:00 - 12:00 2.00 MOB P PRE 1 RIG DOWN -INSTALL TIE RODS ON WHEEL SETS -SECURE HANDRAILS AND PLATES ON ROOF -TIE DOWN PRT CRANES -SECURE PIPE SHED -DISCONNECT WATER LINES ON MOTORS 12:00 - 17:00 5.00 MOB P PRE RIG DOWN -WARM UP MOVING SYSTEM ON MOTORS -PULL CURTAINS BETWEEN COMPLEXES B/D REMAINING STEAM LINES -DISCONNECT ELECTRICAL 17:00 - 18:00 1.00 MOB P PRE RIG DOWN -JACK MOTORS,PIN SUPPORT COLUMNS -MOVE MOTORS AWAY FROM SUB -SET DOWN TURN TIRES -RE-INSTALL TIE RODS 18:00 - 19:30 1.50 MOB P PRE RIG MOVE -SNOW DRIFTING AT CRAZY HORSE ENTRANCE -WAIT ON SNOW REMOVAL EQUIPMENT 1/2 HOUR REMOVE SNOW AT CRAZY HORSE ENTRANCE -SAND ROAD FOR MOVE 19:30 - 00:00 4.50 MOB P PRE RIG MOVE 1 PJSM -TOOL SERVICE,SECURITY PRESENT AT MEETING -MOVE MOTORS F/CRAZY HORSE T/GUARD SHACK Printed 12/12/2013 10:11:39AM • North America-ALASKA-BP Page 2 of Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/16/2013 00:00 - 02:30 2.50 MOB P PRE RIG MOVE -MOVE MOTORS F/GUARD SHACK T/DS-2 02:30 06:30 4.00 MOB P PRE RIG MOVE -RE-POSITION MATS ON DS-2 SPOT MOTORS ON DS-2 06:30 - 12:00 5.50 MOB P PRE RIG MOVE -MOVE SUB F/CRAZY HORSE T/DS-2 ACCESS RD 12:00 - 16:30 4.50 MOB P PRE RIG MOVE -MOVE SUB ONTO DS-2 -PULL TIE RODS ON WHEEL SETS -CRAB TIRES,ROLL ONTO MATS -TURN TIRES BACK INTO ROADING POSITION -RE-INSTALL TIE RODS I-SPOT SUB OVER WELL 16:30 - 18:30 2.00 MOB P PRE RIG MOVE -PULL TIE RODS ON MOTORS -SPOT AGAINST SUB 18:30 - 00:00 5.50 MOB P PRE RIG MOVE MOVE PITS F/CRAZY HORSE T/DS-2 11/17/2013 00:00 - 01:30 1.50 RIGU P PRE RIG MOVE TURN TIRES -SPOT PITS 01:30 - 06:00 4.50 RIGU P PRE RIG UP -HOOK UP ELECTRICAL -HOOK UP HYDRAULIC JUMPERS -HOOK UP STEAM AND UTILITY LINES -R/U AIR HEATER ON WELL HOUSE -READY PIPE SHED PRT CRANES -R/U AIR HEATER ON CHEMICAL WARM UP SHACK 06:00 - 09:00 3.00 RIGU P PRE RIG UP -COMPLETE ELECTRICAL HOOK UP -BRING FLOOR TOOLS FROM SHED TO FLOOR -PIPE AND MATERIAL LEFT IN HOPPER ROOM -MOVE MATERIAL OUT OF HOPPER ROOM -BRING BARA-KLEEN DRUMS INTO HOPPER ROOM 09:00 - 12:00 3.00 RIGU P PRE RIG UP -PJSM ON RAISING MAST -INSPECT MAST AND WARM UP SAME -COMPLETE PRE-LIFT CHECKLIST -TEST HYD.PANEL FOR MAST PINS AND CYLINDERS -RAISE MAST,UP WT 543K 12:00 - 14:30 2.50 RIGU P PRE RIG UP PJSM ON SKIDDING FLOOR -SKID RIG FLOOR -ROLL CATTLE CHUTE INTO POSITION -INSTALL MAN RIDER WINCHES 14:30 - 20:00 5.50 RIGU P PRE RIG UP -PJSM FOR BRIDLE DOWN -R/D BRIDLE LINE -R/U KELLY HOSE,CEMENT STANDPIPE -R/U STABBING BOARD -INSTALL MOUSEHOLES Printed 12/12/2013 10:11:39AM • North America-ALASKA-BP Page 3 ot29 Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 20:00 - 22:00 2.00 WHSUR P DECOMP NIPPLE DOWN TREE -PJSM -CAMERON REP,BLEED VOID PRESSURE -FUNCTION LDS -DRAIN TREE -NIPPLE DOWN ADAPTER FLANGE -VERIFY HANGER THREADS GOOD -INSTALL HANGER X-O AND COUNT TURNS TO M/U -16 TURNS FOR TOTAL M/U -B/O HANGER X-O SIMOPS RIG UP -COMPLETE M/U CEMENT STANDPIPE -TAKE ON SEAWATER -CALIBRATE TOTCO SYSTEM -SET CUTTINGS TANK RIG ACCEPTED AT 20:00 HRS 22:00 - 00:00 2.00 BOPSUR P DECOMP NIPPLE UP BOP NIPPLE UP HIGH PRESSURE RISER 11/18/2013 00:00 - 10:30 10.50 BOPSUR P DECOMP NIPPLE UP BOP -SEND TREE OFF RIG FLOOR -CONTINUE NIPPLE UP HIGH PRESSURE RISER -ADD 30"SPOOL AND REMOVE 18"SPOOL -LOAD TEST JOINTS IN PIPE SHED -INSTALL BELL NIPPLE -INSTALL TURNBUCKLES AND TIGHTEN -M/U BOP TEST JOINT CUTTINGS BOX -FORCED TO MOVE CUTTINGS BOX,COULD NOT BERM -RE-POSITION HERCULITE UNDER BOX -INSTALL BERM AROUND CUTTINGS BOX 10:30 - 13:30 3.00 BOPSUR N RREP DECOMP CODE 8 TOP DRIVE PIPE GRABBER -SHIMMED IMPROPERLY -DAMAGED TOOL JOINT ON SAVER SUB -REPLACE SAVER SUB AND RE-SHIM PIPE GRABBER 'c0',- 13:30 - 14:00 0.50 BOPSUR P DECOMP BOP TESTf�r -TEST BOP_ "-I- - t-3 EACH GLAND NUTS ON TBG SPOOL LEAKING -BLEED PRESSURE OFF -TEST WAIVED BY AOGCC REP BOB NOBLE Printed 12/12/2013 10:11:39AM North America-ALASKA-BP Page 4 of( Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 22:00 8.00 BOPSUR N SFAL DECOMP TROUBLE SHOOT LOCKDOWN SCREWS (LDS) -CALL CAMERON BACK TO RIG -CAMERON DETERMINE LDS IMPROPERLY TORQUED -ORIGINALLY TORQUED PER MCEVOY PROCEDURE •-RE-TORQUE LDS AND APPLY TEST PRESSURE -1 EACH GLAND NUT ON TBG SPOOL LEAKING CONTACT WTL DECIDE TO CHANGE OUT LDS WTL REQUEST INVESTIGATION -CAMERON FIELD SUPV,BP HSE ARRIVE AT RIG 18:45 HRS CAMERON REP INSPECT WELL HEAD -CONFIRMS THAT LDS ARE N-STYLE,NOT MCEVOY TYPE CONTACT WTL WITH INVESTIGATION •FINDINGS REQUEST PERMISSION TO ATTEMPT RE-TORQUE LDS RECEIVE APPROVAL TO RE-TORQUE AND TEST BOP -WTL INFORM RIG NOT TO MOVE PAST BOP TEST -REQUIRE APPROVAL TO PROCEED 22:00 - 00:00 2.00 BOPSUR P DECOMP BOP TEST -TEST 250 PSI/3500 PSI,5 MIN/5 MIN -TEST WITH 4"AND 4-1/2"TEST JOINTS -TEST CHARTED -TEST WAIVED BY AOGCC REP BOB NOBLE 11/19/2013 23:30 - 00:00 0.50 PULL N SFAL DECOMP PRESSURE TEST#5 -TEST LUBRICATOR,250 PSI/3500 PSI,5MIN/ 5MIN -TEST CHART#5,SEE ATTACHED 00:00 - 04:00 4.00 BOPSUR P DECOMP BOP TEST -TEST 250 PSI/3500 PSI,5 MIN/5 MIN -TEST WITH 4"AND 4-1/2"TEST JOINTS -TEST CHARTED,SEE ATTACHED -WITNESS WAIVED BY AOGCC REP BOB NOBLE 04:00 - 05:30 1.50 BOPSUR P DECOMP BOP TEST -R/D TEST EQUIPMENT -B/D LINES -L/D TEST JOINT 05:30 - 08:00 2.50 PULL P DECOMP R/U TO PULL TWC -P/U AND M/U LANDING JOINT -LOAD DUTCH RISER IN PIPE SHED,M/U X-O 08:00 - 08:30 0.50 PULL P DECOMP RIG UP LUBRICATOR -PJSM P/U LUBRICATOR NEXT TO WELL HOUSES 08:30 - 11:30 3.00 PULL P DECOMP RIG UP LUBRICATOR -P/U LUBRICATOR AND M/U TO DUTCH RISER SIMOPS -THAW KILL LINE CHANGE PRESSURE REGULATOR ON TEST PUMP. Printed 12/12/2013 10:11:39AM • North America-ALASKA-BP Page 5 oak Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:30 - 12:00 0.50 PULL P DECOMP PRESSURE TEST -TEST LUBRICATOR,250 PSI/3500 PSI,5MIN/ 5MIN -TEST CHART#1,SEE ATTACHED 12:00 - 13:00 1.00 PULL P DECOMP PULLTWC -ATTEMPT TO PULL TWC -MONITOR WELL BREAK LUBRICATOR ATTEMPT FAILED,INSPECT RUNNING TOOL 13:00 - 13:30 0.50 PULL N SFAL DECOMP PRESSURE TEST#2 -TEST LUBRICATOR,250 PSI/3500 PSI,5MIN/ 5MIN TEST CHART#2,SEE ATTACHED 13:30 - 16:00 2.50 PULL N SFAL DECOMP PULLTWC -SECOND ATTEMPT TO PULL TWC -UNABLE TO GET TO BOTTOM(1-2 INCHES SHORT) -POSSIBLE ICE AT WELL HEAD -MONITOR WELL -BREAK LUBRICATOR -ATTEMPT FAILED,INSPECT RUNNING TOOL -BOTTOM THREAD ON RUNNING TOOL ROLLED -WRAP HERCULITE AROUND WELL HEAD -STEAM WELL HEAD,1 HOUR CONTACT WTL,ODE -PLAN TO PULL DUTCH RISER -CIRCULATE WELL CLEAN ON TOP OF TWC -USE VAC TRUCK TO SUCK STACK OUT INSPECT TWC WITH BORESCOPE 16:00 - 18:00 2.00 PULL N SFAL DECOMP PULL DUTCH RISER -ANNULAR NOT FULLY OPENING TO PULL RISER -WORK ANNULAR OPEN AND CLOSE -PULL DUTCH RISER -SUCK STACK OUT WITH VAC TRUCK -RIH W/BORE SCOPE -INSPECT ANNULAR,GOOD -INSPECT TWC,GOOD,HOLE CLEAN -NOTICED PEELED THREAD ON TUBING HANGER NOTE:NO FOREIGN OBJECTS FOUND -DUE TO HOLE BEING CLEAN -DECIDE TO BYPASS CIRCULATION,M/U DUTCH RISER 18:00 - 19:30 1.50 PULL N SFAL DECOMP R/U DUTCH RISER -CHECK CONNECTION ON TOOL STRING -ADD 1 MORE STABILIZER TO STRING -INSTALL NEW RUNNING TOOL 19:30 - 20:30 1.00 PULL N SFAL DECOMP PRESSURE TEST#3 -TEST LUBRICATOR,250 PSI/3500 PSI,5MIN/ 5MIN TEST CHART#3,SEE ATTACHED Printed 12/12/2013 10:11:39AM North America-ALASKA-BP Page 6 pit Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (us ft) 20:30 - 22:30 2.00 PULL N SFAL DECOMP PULL TWC -THIRD ATTEMPT TO PULL TWC -UNABLE TO THREAD IN TO TWC -MONITOR WELL -BREAK LUBRICATOR -ATTEMPT FAILED,INSPECT RUNNING TOOL, GOOD 22:30 - 23:00 0.50 PULL N SFAL DECOMP PRESSURE TEST#4 -TEST LUBRICATOR,250 PSI/3500 PSI,5MIN/ SMIN TEST CHART#4,SEE ATTACHED 23:00 - 23:30 0.50 PULL N SFAL DECOMP PULL TWC -FOURTH ATTEMPT TO PULL TWC -UNABLE TO THREAD IN TO TWC -MONITOR WELL -BREAK LUBRICATOR ATTEMPT FAILED,INSPECT RUNNING TOOL -STARTING THREAD SLIGHTLY GALLED -CHANGE RUNNING TOOL CONTACT WTL,ODE -DISCUSS RUNNING TOOL CONFIGURATION INSTALL SHORT SPRING ASSEMBLY '-ALLOW WEIGHT TRANSFER TO THREADS -LONG SPRING ASSEMBLY BOTTOM OUT ON •TWC BODY 11/20/2013 00:00 - 01:00 1.00 PULL N SFAL DECOMP PULL TWC -FIFTH ATTEMPT TO PULL TWC, SUCCESSFUL -SEE PICTURES OF TWC 01:00 - 02:00 1.00 PULL P DECOMP R/D LUBRICATOR -R/D LUBRICATOR -R/D DUTCH RISER R/D VAC TRUCK AND VAC HOSE 02:00 - 05:00 3.00 PULL P DECOMP CIRCULATE -PJSM W/CREW,MUD ENGINEER -WALK LINES,BLOW AIR THROUGH LINES -CLOSE BLINDS AND CIRC OUT FREEZE PROTECT -PUMP DOWN TBG,TAKE OUT IA TO TIGER TANK -50 BBL SPACER,8.5 PPG SEAWATER,210 GPM,640 PSI -25 BBL BARAKLEAN SWEEP,84 GPM,85 PSI -230 BBL,8.5 PPG SEAWATER,210 GPM,640 PSI -B/D LINES 05:00 - 07:30 2.50 PULL P DECOMP SPEAR HANGER -PJSM -PU SPEAR AND RECOVER TUBING HANGER -PU WT 69K MONITOR WELL 10 MIN,STATIC 07:30 - 08:00 0.50 PULL P DECOMP PRESSURE TEST -TEST LOCK DOWN SCREWS -TEST 250 PSI/3500 PSI,5 MIN/5MIN,GOOD 08:00 - 09:00 1.00 PULL P DECOMP CIRCULATE BOTTOMS UP,1X 315 GPM,1220 PSI 09:00 - 10:30 1.50 PULL P DECOMP L/D TUBING -PJSM WITH CREW,BAKER,DOYON CASING -L/D LANDING JT,SPEAR,AND HANGER Printed 12/12/2013 10:11:39AM North America-ALASKA-BP Page 7 oj)2,9 Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM I Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 10:30 - 11:30 1.00 PULL N RREP 3,148.00 DECOMP CODE 8 TROUBLE SHOOT HYDRAULIC SYSTEM -FILL HYDRAULIC SYSTEM -DID NOT GET REFILLED AFTER SUMMER SHUTDOWN 11:30 - 12:00 0.50 PULL P DECOMP CHANGE OUT INSERTS ON ELEVATORS -CHANGE OUT INSERTS TO 4.5" -CONTINUE LAYING DOWN LANDING JNT AND SPEAR 12:00 - 17:30 5.50 PULL P DECOMP POOH -PJSM FOR UD TUBING MONITOR WELL 10 MIN.STATIC SEAWATER 8.5 PPG IN,8.5 PPG OUT -POOH ON ELEVATORS,UD 4.5"TUBING 1-81 JTS,1 CUT JT-4'LONG,4 EA PUPS,1 EA •X NIPPLE -(SEE PICTURE OF CUT END) PU=71 K,S0=70K -R/D POWER TONGS -CLEAR AND CLEAN FLOOR -CHANGE ELEVATOR INSERTS BACK TO 4" 17:30 - 18:00 0.50 CLEAN P DECOMP INSTALL WEAR BUSHING -INSTALL 8-5/8"ID WEAR BUSHING 18:00 - 20:30 2.50 CLEAN P DECOMP BHA PJSM W/BAKER,P/U 8-1/2 CLEANOUT BHA -P/U 8-1/2 CLEAN OUT BHA 20:30 - 21:00 0.50 CLEAN P DECOMP SERVICE RIG 21:00 - 23:00 2.00 CLEAN P DECOMP BHA -P/U 8-1/2 CLEAN OUT BHA -SHALLOW HOLE TEST MWD,GOOD 23:00 - 00:00 1.00 CLEAN P DECOMP D5-DRILL -HOLD D2 DRILL FOLLOWED BY WELL KILL DRILL -CREW MEMBERS OPERATE SUPER CHOKE -FOLLOW UP WITH AAR -COMMUNICATION NEEDS TO IMPROVE DURING DRILL -CREW RESPONSE WAS EXCELLENT 1-B/D CHOKE 11/21/2013 00:00 - 00:30 0.50 CLEAN P DECOMP BHA -CONTINUE TO P/U 8-1/2"CLEANOUT BHA 00:30 - 05:00 4.50 CLEAN P ( DECOMP RIH WITH 8-1/2"CLEANOUT BHA F/803'MDT/ 2986'MD -RIH ON ELEVATORS PICKING UP 4°DP SINGLES -TAG TOP OFT'LINER AT 2986'MD -PU 102K,SO 99K AT 2986'MD 05:00 - 06:00 1.00 CLEAN P DECOMP CIRCULATE BOTTOMS-UP,1X -PUMP HIGH VIS SWEEP -550 GPM,1780 PSI 06:00 - 09:00 3.00 CLEAN P DECOMP I SLIP AND CUT DRILL LINE PJSM WITH RIG CREW -CUT 16 WRAPS/136'DRILL LINE 09:00 - 09:30 0.50 CLEAN P DECOMP RECALIBRATE BLOCKS AND MWD BLOCK HEIGHT Printed 12/12/2013 10:11:39AM • North America-ALASKA-BP Page 8 of Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01©77.00usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) � (usft) 09:30 - 10:30 1.00 CLEAN P DECOMP POOH -MWD SURVEY FOR GRAVITATIONAL TOOLFACE -CHECK SHOT SURVEYS F/2986'MD TO 2805'MD -SURVEY GOOD -380 GPM,820 PSI -PUMP DRY JOB 10:30 - 12:00 1.50 CLEAN P DECOMP POOH ON ELEVATORS -MONITOR WELL FOR 10 MINUTES:STATIC -SEAWATER 8.5 PPG IN, 8.5 PPG OUT -POOH F/2805'MD T/806'MD -PU 98K,SO 98KAT 2805'MD -LAY DOWN BAKER TOOLS 12:00 - 14:00 2.00 CLEAN P DECOMP L/D BHA -MONITOR WELL FOR 10 MINUTES:STATIC -L/D BHA FROM 806'MD TO 52'MD 14:00 - 17:30 3.50 CLEAN P DECOMP WIRELINE LOG -PJSM WITH SLB WIRELINE AND RIG UP 17:30 - 19:30 2.00 CLEAN N DFAL DECOMP WIRELINE LOG TROUBLE SHOOT -SLB SURFACE COMPUTER SYSTEM PROBLEMS 19:30 - 22:30 3.00 CLEAN N DFAL 2,870.00 DECOMP WIRELINE LOG RIH WITH GR/CCUUSIT/CBLNDL TO 2870' MD 22:30 - 00:00 1.50 CLEAN N DFAL 2,870.00 DECOMP POH WITH WIRELINE -TROUBLE SHOOT LOGGING TOOLS -SLB USIT TOOL FAILED -POH WITH WIRELINE FROM 2870'MD -PICK UP BACKUP USIT TOOL 11/22/2013 00:00 - 02:00 2.00 EVAL N DFAL 2,870.00 DECOMP WIRELINE LOG TROUBLE SHOOT -USIT TOOL FAILED -POOH TO PICK UP 2ND USIT TOOL -CHANGE OUT USIT TOOL 02:00 - 07:30 5.50 EVAL N DFAL 2,870.00 DECOMP TROUBLE SHOOT USIT -CHECK EACH SECTION ON USIT AND TROUBLE SHOOT -CHANGE OUT ACQUISITION SYSTEM ON USIT TOOL -TROUBLE SHOOT ACQUISITION SYSTEM 07:30 - 11:00 3.50 EVAL N DFAL 2,870.00 DECOMP TROUBLE SHOOT USIT -SLB CHANGE OUT -CONTINUE TROUBLE SHOOTING -SWAP OUT E-LINE TRUCKS RIG UP USIT TOOL 11:00 - 15:30 4.50 EVAL P DECOMP RIH WITH USIT TOOL 1 -RIH WITH USIT TOOL FROM SURFACE TO V5 2870' 1 0 LOG WELL AS REQUIRED -GOOD DATA ACQUIRED -LOG FROM 2800'TO SURFACE 15:30 - 16:30 1.00 EVAL P DECOMP RIG DOWN SLB USIT TOOL 16:30 - 19:00 2.50 EVAL P DECOMP RIH WITH E-LINE AND SET EZSV J -PJSM WITH SLB,HES,BP,AND PARKER PICK UP EZSV -RIH WITH EZSV AND SET AT 2937' 19:00 - 20:30 1.50 I EVAL P DECOMP POOH -POOH W/TOOL STRING -R/D E-LINE Printed 12/12/2013 10:11:39AM North America-ALASKA-BP Page 9 -- Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) ! Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 I77.00usft(above Mean Sea Level) Data From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) _ 20:30 - 21:30 1.00 CUT P DECOMP P/U BHA -PJSM -P/U AND M/U 8-1/4 CASING CUTTER - 21:30 - 00:00 2.50 CUT P DECOMP !i RIH I- RIHF/13'T/1714'MD -RIH PICKING UP 4"DP SINGLES MONITOR WELL VIA TRIP TANK, I-WELL GAVE PROPER DISPLACEMENT 11/23/2013 00:00 - 02:30 2.50 CUT P DECOMP RIH WITH 8-1/4"MULTI STRING CUTTER BHA -RIH PICKING UP 4"DP SINGLES FROM 1714' MO TO 2939'MD -MONITOR WELL VIA TRIP TANK, -WELL GAVE PROPER DISPLACEMENT -TAG EZSV AT 2939'MD DPM(2937'ELM) 02:30 - 03:30 1.00 CUT P DECOMP CBU -DISPLACE 8.6 PPG SEAWATER WITH 9.8 PPG BRINE -230 GPM,522 PSI PUMPED 270 BBLS 9.8 PPG BRINE 03:30 - 05:00 1.50 CUT P DECOMP LOCATE 95/8"CUT DEPTH -PJSM WITH BAKER,WSL,PARKER -STRAP OUT OF THE HOLE TO SECOND CEMENT FREE JOINT -PUMP ON CUTTERS i-LOCATE LOWER COLLAR AT 2115'MD DPM -P/U AND LOCATE UPPER COLLAR AT 2072' MD DPM -PU 65K,S067K -LOCATE CUTTERS 10'BELOW TOP COLLAR -2082'MD FOR CUT 05:00 - 06:30 1.50 CUT P DECOMP TEST OA VALVE -R/U ON SECONDARY OA VALVE -TEST OA VALVE 250 PSI LOW FOR 5 MIN -TEST OA VALVE 3500 PSI HIGH FOR 5 MIN 06:30 - 07:00 0.50 CUT P DECOMP I CUT 9 5/8"CASING -CUT 9 5/8"CASING AT 2082'MD 07:00 - 10:00 3.00 CUT N STUC 2,082.00 DECOMP WORK STUCK PIPE -STRING WEIGHT PU 65K,SO 67K WORK PIPE P/U 50K OVERPULL IN INCREMENTS -APPLY 10K TORQUE -PIPE BACKLASH,LOST 15K -TAG UP AND SCREW BACK IN -CONTINUE TO WORK PIPE AT 50K OVERPULL 10:00 - 11:00 1.00 DISPL P DECOMP RIG UP TO DISPLACE -PJSM WITH LRS,BAKER,WSL,PARKER -R/U LITTLE RED SERVICES AND TEST LINES 11:00 - 12:30 1.50 DISPL N SFAL DECOMP LRS GLAND PACKING LEAK -WAIT ON PART FROM LRS -TEST LRS LINES 12:30 - 14:00 1.50 DISPL P DECOMP PUMP HOT DIESEL IN ANNULUS -PUMP 23 BBL 80 DEG DIESEL DOWN DP -CLOSE ANNULAR -PUMP REMAINING 27 BBLS DIESEL DOWN DP IN 9 5/8"ANNULUS • -2 BPM,®700 PSI PUMP 23BBLS 9.8 PPG BRINE WITH RIG PUMPS -3.5 3PM,350 PSI Printed 12/12/2013 10:11:39AM • North America-ALASKA-BP Page 10041 Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 ©77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 15:00 1.00 DISPL P DECOMP SOAK ARCTIC PACK -LET ARCTIC PACK AND DIESEL SOAK OA OPEN 15:00 - 17:00 2.00 DISPL P DECOMP DISPLACE ARCTIC PACK DISPLACE ARCTIC PACK WITH 9.8 PPG BRINE -4.5 BPM,1900 PSI -PUMP 40 BBLS BARAKLEAN PILL -5BPM,2100 PSI CIRCULATE CBU 3X AT 5 BPM 17:00 - 19:00 2.00 CUT N STUC 2,082.00 DECOMP FREE STUCK PIPE -STRING WEIGHT PU 65K,SO6K -PERMISSION FROM WTL TO P/U 100K OVERPULL -WORK PIPE P/U 100K OVERPULL IN INCREMENTS -APPLY 10K TORQUE -CONTINUE TO WORK PIPE AT 100K OVERPULL -PERMISSION FROM WTL TO PROCEED TO P/U 250K -P/U TO 250K IN INCREMENTS -PIPE CAME FREE AT 248K P/U WEIGHT(183K OVERPULL) 19:00 - 22:30 3.50 CUT P DECOMP POH WITH CUTTERS ON ELEVATORS -MONITOR WELL FOR 10 MIN,WELL STATIC -BRINE 9.8 PPG IN,9.8PPG OUT -POH ON ELEVATORS FROM 2080'MD TO 13' MD -BREAK,CHECK AND M/U EVERY CONNECTION -MONITOR WELL VIA TRIP TANK WELL TOOK PROPER DISPLACEMENT 22:30 - 23:00 0.50 CUT P DECOMP LID CUTTER BHA -L/D 8 1/4"CUTTER BHA -OBSERVED CUTTER DAMAGE -MINIMAL METAL DEFORMATION AROUND CUTTER -CUTTER WEAR WAS 0.25" 23:00 - 00:00 1.00 CUT P DECOMP CHANGE UPPER PIPE RAMS -P/U TEST JOINT -M/U WEAR RING PULLER -PULL WEAR RING 11/24/2013 00:00 - 02:00 2.00 BOPSUR P DECOMP CHANGE OUT UPPER VBR'S -CHANGE OUT UPPER VBRS TO 9 5/8"SOLID BODY BARRIERS KWF AND TESTED BLIND RAMS 02:00 - 03:30 1.50 BOPSUR P DECOMP BOPE RAM TEST -TEST 9 5/8"RAMS -250 PSI/3500 PSI,5 MIN/5 MIN,GOOD R/D TEST JOINT AND L/D Printed 12/12/2013 10:11:39AM North America-ALASKA-BP Page 11 040. Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:30 - 07:00 3.50 FISH P DECOMP SPEAR 9 5/8"CASING g1) -PJSM WITH BAKER,WSL,PARKER -M/U BAKER 6 1/4"SPEAR ASSEMBLY Ci54 -ENSURE LOCK DOWN SCREWS ARE a BACKED OUT -ENGAGE CASING BELOW HANGER AND P/U -CASING RELEASED AT 13K OVERPULL(120K STRING WEIGHT) -P/U SPEAR,HANGER,PACK OFF TO SURFACE AND L/D -CHANGE OUT BTTM DIES ON CSG TONGS 07:00 - 08:30 1.50 PULL P DECOMP CBU -CIRCULATE BOTTOMS UP WITH 9.8 PPG BRINE -RECIPROCATE PIPE -510 GPM,97 PSI PU 118K,SO 118K 08:30 - 16:00 7.50 PULL P DECOMP POH WITH 9 5/8"CASING -MONITOR WELL FOR 10 MIN,STATIC -MUD WEIGHT:9.8 PPG IN,9.8 PPG OUT -POOH FROM 2082'MD TO 0'MD -AVERAGE BREAK OUT TORQUE 25-40K FTLBS -PU 118K,SO 118K AT 2082'MD -MONITOR TRIP VIA TRIP TANK -PROPER DISPLACEMENT -50 JOINTS AND CUT JOINT RECOVERED -CUT JOINT SHOWED 18"SPLIT(PICTURES ATTACHED) -8 STOP RINGS AND CENTRALIZERS RECOVERED 16:00 - 18:30 2.50 CASING P DECOMP PRESSURE TEST CASING -CLEAN RIG FLOOR AND R/U TEST ASSEMBLY -PRESSURE TEST 13 3/8"X 9 5/8"CASING -350 PSI LOW FOR 5 MIN,2500 PSI HIGH FOR 30 MIN,GOOD -BLEED OFF PRESSURE AND R/D -CONTACT WTL,RECEIVE APPROVAL TO PROCEED 18:30 - 20:00 1.50 BOPSUR P DECOMP CHANGE OUT UPPER VBR'S -CHANGE OUT UPPER VBRS BACK TO 2 7/8" X 5 1/2" 20:00 - 22:30 2.50 BOPSUR P DECOMP BOPE RAM TEST -TEST VBR RAMS -250 PSI/3500 PSI,5 MIN/5 MIN,GOOD -R/D TEST JOINT AND L/D 22:30 - 00:00 1.50 CLEAN P DECOMP M/U BAKER BHA -PJSM WITH BAKER,WSL,PARKER -M/U 12"X 9 5/8"DRESS OFF BHA 11/25/2013 00:00 - 02:00 2.00 CLEAN P DECOMP CONT M/U BAKER BHA -M/U 12"X 9 5/8"DRESS OFF BHA TO 650'MD -TAG UP AT 650'MD Printed 12/12/2013 10:11:39AM • • North America-ALASKA-BP Page 12 Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/me:4/6/1980 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UVI:500292044200 Active datum:02-01©77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:00 - 03:00 1.00 CLEAN P DECOMP WORK OBSTRUCTION -KELLY UPON BHA -PU 65K,SO 72K -BRING PUMPS UP TO 5 BPM,292 PSI DPP -COULD NOT PASS THROUGH OBSTRUCTION -ROTATE AT 10 RPM,8K TORQUE LIMIT -STALL OUT AT 650' -COULD NOT WORK PAST OBSTRUCTION -CALL ODE 03:00 - 08:00 3.00 CLEAN N DPRB 650.00 DECOMP POH WITH BHA -DISCUSS PLAN FORWARD WITH ODE AND BAKER -DISCUSS PLAN FORWARD WITH WTL -RECEIVE APPROVAL TO RIH WITH INNER DRESS MILL -POOH WHILE PLANNING NEXT BHA -MONITOR WELL FOR 10 MIN,WELL STATIC BRINE 9.8 PPG IN,9.8 PPG OUT -POOH FROM 650'AND UD DRESS OFF BHA -MONITOR WELL VIA TRIP TANK -WELL TOOK PROPER DISPLACEMENT 06:00 - 07:00 1.00 CLEAN N WAIT DECOMP CLEAN AND CLEAR RIG FLOOR -WAIT ON BAKER TOOLS. 07:00 - 10:00 3.00 CLEAN N ; DFAL 781.00 DECOMP M/U NEW 9 5/8"DRESS OFF BHA -PJSM WITH BAKER,WSL,PARKER -M/U 9 5/8"DRESS OFF BHA TO 781'MD -MONITOR WELL VIA TRIP TANK -PROPER DISPLACEMENT 10:00 - 11:00 1.00 CLEAN P DECOMP RIH ON ELEVATORS -RIH WITH 9 5/8"DRESS OFF BHA FROM 781' MD TO 2081'MD -MONITOR WELL VIA TRIP TANK -PROPER DISPLACEMENT 11:00 - 14:00 3.00 CLEAN P DECOMP DRESS OFF 9 5/8"STUB '-DRESS OFF 9 5/8"STUB FROM 2081'MD TO 2086.5'MD -250 GPM,265 PSI DPP -P/U 80K,S/O 79K -PUMP HI VIS SWEEP -670 GPM,1600 PSI DPP 14:00 - 15:30 1.50 CLEAN P DECOMP POH ON ELEVATORS -MONITOR WELL FOR 10 MIN,STATIC -POH WITH 9 5/8"DRESS OFF BHA FROM 2086'MD TO 781'MD -MONITOR WELL VIA TRIP TANK -PROPER DISPLACEMENT 15:30 - 17:30 2.00 CLEAN P DECOMP LID 9 5/8"DRESS OFF BHA -PJSM WITH BAKER,WSL,PARKER -UD 95/8"DRESS OFF BHA -MONITOR WELL VIA TRIP TANK -PROPER DISPLACEMENT 17:30 - 21:00 3.50 CLEAN P DECOMP PIPE MANAGMENT -M/U 5"HWDP AND RACK BACK IN DERRICK -TIH WITH HWDP AND CIRCULATE TO ENSURE CLEAN PIPE -POOH AND RACK BACK 21:00 - 00:00 3.00 STWHIP P WEXIT MAKE UP 8.5"WHIPSTOCK -PJSM WITH RIG CREW,WSL AND BAKER -MOBILIZE MILLS AND XO'S TO RIG FLOOR -MAKE UP 8.5"WHIPSTOCK AND MILL ASSEMBLY TO 400'MD Printed 12/12/2013 10:11:39AM • North America-ALASKA-BP Page 1369 Operation Summary Report Common Well Name:02-01A AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135,423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01 @77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11/26/2013 00:00 - 04:30 4.50 STWHIP P WEXIT RIH ON ELEVATORS -RIH WITH 8.5"WHIPST• \• L F/401 D T/2937'MD -RIH ON STANDS OF 4"DRILL PIPE -SHALLOW TEST MWD AT 1287'MD -350GPM,540 PSI -MONITOR WELL VIA TRIP TANK PROPER DISPLACEMENT �,� 04:30 - 05:30 1.00 WHIP P WEXIT SET WHIPSTOCK AT 2937' _ ORIENT WHIPSTOCK WITH MWD \Pl -PUWT117K,DNWT122K -SET DOWN 32K LBS TO SET ANCHOR -P/U 10K TO CONFIRM SET -SET DOWN 46K TO SHEAR RAMP 05:30 - 07:30 2.00 WHIP P WEXIT DISPLACE -DISPLACE 9.8 PPG BRINE TO 9.8 PPG LSND 3.,,,,r 07:30 - 15:30 8.00 STWHIP P WEXIT MILL WINDOW IN 9-5/8"CASING. A Y �,�XK/ -FROM 2914'MD TO 2954'MD. \ d" D2-0 IG -TOP OF WINDOW AT 2914'MD ,✓` -BOTTOM OF WINDOW AT 2931'MD -420 GPM;900 PSI ON BTM 875 PSI OFF BTM. 100 RPM;3-5K FT-LBS TORQUE ON,2K FT-LBS TORQUE OFF. PU=115K LBS;SO=122K LBS;ROT=115K LBS. -WOB=3-5K LBS. -MUD WEIGHTS:9.8 PPG IN,9.8 PPG OUT. SLOW PUMP RATES: -2910'MD,9.8 PPG MW. -PUMP 1:20/30 SPM=130/175PSI. PUMP 2:20/30 SPM=125/170PSI. 15:30 - 16:00 0.50 STWHIP P WEXIT CIRCULATE HOLE CLEAN. 420 GPM,900 PSI,100 RPM 16:00 - 17:00 1.00 STWHIP P WEXIT PERFORM LOT -MUD WEIGHT IN/OUT=9.8 PPG -LEAK OFF PRESSURE=440 PSI -KOP=2914'MD;2911'TVD. -EMW=12.7PPG -PUMPED 14 BBLS,4.5 BBLS BLED BACK WTLAPPROVED LOT RESULTS AND GAVE APPROVAL TO PROCEED 17:00 - 18:30 1.50 STWHIP P WEXIT POH WITH MILLING ASSEMBLY -MONITOR WELL FOR 10 MINUTES:STATIC -POH FROM 2954'MD TO 1027'MD. -MUD WEIGHT:9.8 PPG IN,9.8 PPG OUT. -PUMP SWEEP AT 1027'MD -MINIMAL CUTTINGS WITH SWEEP -MONITOR TRIP VIA TRIP TANK PROPER DISPLACEMENT 18:30 - 21:00 2.50 STWHIP P WEXIT POH AND L/D 8-1/2"MILLING ASSEMBLY -STAND BACK HWDP -LAY DOWN DRILL COLLARS -LAY DOWN MILLS UPPER MILL IN GAUGE Printed 12/12/2013 10:11:39AM North America-ALASKA-BP Page 14,84.0 Operation Summary Report Common Well Name:02-01A AFE No • Event Type:RE-ENTER-ONSHORE(RON) Start Date:11/15/2013 End Date: X3-01478-C:(10,135.423.00) Project:Prudhoe Bay Site:PB DS 02 Rig Name/No.:PARKER 272 Spud Date/Time:4/6/1980 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292044200 Active datum:02-01©77.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 21:00 - 00:00 3.00 BOPSUR P WEXIT PULL WEAR RING AND FLUSH STACK -PULL WEAR RING AND PICK UP STACK FLUSHING TOOL -FUNCTION RAMS AND FLUSH STACK -LAY DOWN STACK FLUSHING TOOL -DRAIN STACK -M/U 4"TEST JOINT -INSTALL TEST PLUG -FILL STACK 11/27/2013 00:00 - 05:30 5.50 BOPSUR P WEXIT BOPE TEST -FILL AND SHELL TEST LINES -BLEED AIR FROM SYSTEM -TEST BOPE TO 250 PSI LOW,3500 PSI HIGH 'FOR 5MIN -TEST WITH 4" TEST JOINT -ALL TESTS CHARTED,SEE ATTACHED BOP TEST CHARTS -TEST WITNESSED BYAOGCC REP JEFF TURKINGTON 05:30 - 07:30 2.00 BOPSUR P WEXIT SET WEAR RING -PULL TEST PLUG -SET WEAR RING -BLOW DOWN CHOKE AND KILL LINES. -R/D TESTING EQUIPMENT 07:30 - 14:00 6.50 DRILL 1 P WEXIT M/U 8-1/2"DRILLING ASSEMBLY -PJSM FOR P/U BHA -MAKE UP SHEAR JOINT -M/U 8 1/2"MOTOR BHA WITH MWD -SHALLOW TEST MWD:GOOD TEST -450 GPM,900 PSI -MONITOR TRIP VIA TRIP TANK -WELL LOSING APPROX 1 BBUHR 14:00 - 16:30 2.50 DRILL P WEXIT RIH WITH 8-1/2"DRILLING ASSEMBLY -RIH FROM 830'MD TO 2954'MD -P/U 4"HT-38 DRILL PIPE SINGLES FROM PIPE SHED -NO PROBLEMS THROUGH WINDOW -MONITOR WELL VIA TRIP TANK -WELL LOSING APPROX 1 BBUHR 18:30 - 00:00 7.50 DRILL P INTI DRILL 8-1/2"INTERMEDIATE HOLE FROM 2954' MD TO 3670'MD(3657'ND). -508 GPM;1650 PSI ON,1600 PSI OFF. -PU=115K LBS;SO=108K LBS,ROT=113K -WOB=0-2K LBS -MUD WEIGHT:9.8 PPG IN,9.8 PPG OUT. -SURVEY EVERY-90FT -ACTUAL ROTATE TIME=2 HRS -ACTUALSLIDE TIME=1.6 HRS -BACKREAM-90FT PRIOR TO CONNECTIONS -BENCHMARK ECD: -CALC.CLEAN HOLE ECD=10.30 PPG. -MEASURED CLEAN HOLE ECD=10.43 PPG. SLOW PUMP RATES:3529'MD,3521'ND;MW =9.8 PPG. PUMP#1:20/30 SPM=160/215 PSI. PUMP#2:20/30 SPM=160/220 PSI. Printed 12/12/2013 10:11:39AM I TREE= CW WELLHEAD= GRAY SAFETY NOTES: WELL O 2-0 1 B 511'. TOOLS HANGING P @ ANGLE /-8590'(3-1/2"9 LNTOP) ACTUATOR= BAKER C OKg aEy= 64 I NOTED ON 02/22/01. 11/29/04 NOTE: WELL 02-01 13-3/8"CSG, H 2690' \ �, BF.ELEV= N/A WAS ABANDONED,RIG SKIDDED OVER AND WELL KOP= 5450' 72#,L-80, 02-01A SPUDDED***4-1/2"CHROME TBG*** Max Angle= 99°@ 10049' ID=12.347 Datum MD= 9425 94 5' 9-5/8"WS - 2914' 2082' H9-5/8"CSG CUT(11/23/13) Datum TVD= 88000'SS2968' �9-518"X 7"BKR G2 ZXP LIP w/BKR 9-5/8"EZSV -1 2937' FLEXLOCK HGR &TIEBK SLV,ID=6.280" Minimum ID =3..813" @ 2056' 2 kr. 3225' -14-1/2"TBG CUT(10/25/13) 4-1/2" HES X NIPPLE i V4' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE ESTIMATED IA TOC(10/20/13) -1 7407' 01I =, 2 3499 3495 5 KBG2 DMY BK 0 06/14/09 ,r. 1 6033 5993 28 KBG2 DMY BK 0 06/14/09 ESTIMATED TBG TOC(10/20/13) -1 7204' , `iI �4i1# 1 ,. 9-5/8"CSG,47#,L-80 BTC XO TO S-95 BTC H 8301' 4 Iirifp i1. 8380' -I4-1/2"HES XNIP,O=3-813" TBG PUNCH(10/17/13) - 8320' -8325' _ ,' 8411' -17"X 4-1/2"BKR S-3 PKR,D=3-875" 4-1/2"TBG,12.6#,13C R-80 VA TOP -I 8457' r 8445' H4-1/2"HES X NIP,ID=3.813" I* XO TO 13CR-80 STL �, 8516' H9-5/8"X 5-1/2"UNIQUE OVERSHOT 7"SCAB LNR,29#,L-80 BTC-M,ID=6.184" -1 8478' 'ies�%�I e ;41th iq' 8580' H5-1/2"BAKER PBRASSY ESTMA I HJ TOC(10/09/13) -{ 8500' Ki `L 8589' H 12.5',3-50"ENTRY GUIDE,D=2.75"(08/29/09) 5-1/2"TBG STUB -1 8520' v►. 4t44? 'i ' 8595' -I9-5/8"X 5-1/2"BKR SAB PKR,ID=4.75" �� 4'' 'WM 8595' 15-1/2"TBG TAIL BACKED OFF BELOW PKR FISH: 16'BHA 4-11/16"MIL,XO,BOOT --I 8604' ,i BASKET JAMMED BESIDE LNR DURING '0 DURING 06/08 RWO 06/08 RWO160 8605' H4-1/2"NILE SHOE,ID=3.958" 4-1/2"TBG,12.6#,13CR-80 STL, - 8605' .0152 bpf,D=3.958" 8644' -I5-1/2"OTIS XN NIP,ID=4.455"(BEHIND LNR) 8645' I-15-1/2"BKR SHEAROUT SUB(BEHIND LNR) TOP OF 3-1/2"LNR - 8608' 8646' H5-1/2"TUBING TAIL(BEHIND LNR) 5-1/2"TBG-PC,17#,L-80,-0232 bpf,ID=4.892" - 8646' 8620' --I END TT LOGGED 04/29/80 4 9-5/8"CSG,47#,S-95 BTC,ID=8.681" H 9327' 41; IL PERFORATION SUMMARY REF LOG: BHCS ON 4/20/1980 ANGLE AT TOP PERF: 73°@ 952t7 ll Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1-11/16"&2-1/8" 4 9520-9719 S 09/20/97 10/09/13 ` 2-1/2" 4 9740-9880 C 05/17/00 1-11/16"&2-1/8" 4 9880-10040 C 09/20/97 1-11/16"&2-1/8" 4 10281 -10371 C 09/20/97 1-11/16"&2-1/8" 4 10419-10610 C 09/20/97 11706' -IPBTD 3-1/2"LC,ID=1.611" 2-1/2" 4 10610-10810 C 05/17/00 1-11/16"&2-1/8" 4 10810-11090 C 09/20/97 1-11/16"&2-1/8" 4 11130-11170 C 09/20/97 1-11/16"&2-118" 4 11280-11350 C 02/22/01 4,, 1-11/16"&2-1/8" 4 11390-11509 C 02/22/011-11/16"&2-1/8" 4 11620-11700 C 02/22/01 3-1/2"LNR,9.3#,L-80,.0087 bpf,ID=2.932" -1 11773' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/06/76 INITIAL COMPLETION 10/30/13 PJC DRAWING CORRECTIONS WELL: 02-01B 02-01 ABANDONED 10/31/13 REM/JMD CEMENT(10/09/13) PERMIT No: 1971400 04/26/80 PKR 176 02-01A COMPLETION 10/31/13 DS/JMD TBG PUNCH(10/17/13) API No: 50-029-20442-01 09/20/97 CTD SIDETRACK(02-01 B) 10/31/13 REM/JMD CEMENT(10/20/13) SEC 36,T11 N,R14E,651'FNL&1696'FWL 06/15/08 N2ES RWO 10/31/13 JCM/JMD TBG CUT(10/25/13) 03/10/10 JR/JMD DRLG DRAFT CORRECTIONS 11/28/13 PJC CMT CORRECTION BP Exploration(Alaska) V OF Ty • • ��\\I%%ye s THE • STATE Alaska it and s _ALASKA Conservation Commission :- - GOVERNOR SEAN PARNELL 333 West Seventh Avenue OF p. Anchorage, Alaska 99501-3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 E� Oki -- Mary Endacott Engineering Team Leader i / BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-01B Sundry Number: 313-439 Dear Ms. Endacott: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P oerster Chair .A-o( DATED this' day of August, 2013. End. STATE OF i- ofL ofL R EC t...-- ili" D $ z,3 Cbt)11 ALAS•OIL AND GAS CONSERVATION COMMIS ION •.L'S'13' AU H2013 (c2 ye APPLICATION FOR SUNDRY APPROVAL $ 20 AAC 25.280 AOGCC 1. Type of Request: ❑Abandon _ Plug for Redrill • ❑Perforate New Pool ❑Repair Well ❑Change Approved Program ❑Suspend ❑Plug Perforations ❑Perforate ❑Pull Tubing ❑Time Extension ❑Operations Shutdown ❑Re-Enter Suspended Well ❑Stimulate ❑Alter Casing ❑Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory ❑Stratigraphic 197-140 • 3. Address: 6. API Numbe ®Development ❑Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20442-01-00 • 7. If perforating: 8. Well Name and Number: 1 What Regulation or Conservation Order governs well spacing in this pool? pBU 02-01B • Will planned perforations require a Spacing Exception? ❑Yes ® No 9. Property Designatior 10.Field/Pool(s): ADL 028308 • 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): 11772' ' 8858' • 11706' 8857' None 8604' Casing Length Size MD TVD Burst Collapse Structural Conductor 75' 20" 75' 75' 1530 520 Surface 2690' 13-3/8" 2690' 2689' 4930 2670 Intermediate 9327' 9-5/8" _ 9327' 8790' 6870 4760 Production Liner 3162' 3-1/2" 8610'- 11772' 8201'-8858' 10160 10530 Scab Liner 5548' 7" 2968'- 8516' 2966'-8119' 8160 7020 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9520'- 11170' 8915'-8880' 4-1/2", 12.6#;5-1/2", 17# 13Cr80; L-80 8605;8505'-8645' Packers and SSSV Type: 7"x 4-1/2"Baker S-3 Packer; Packers and SSSV 8411'/8026' 9-5/8"x 5-1/2"Baker SAB Packer MD(ft)and ND(ft): 8595'/8188' 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch ❑Detailed Operations Program ❑Exploratory ❑Stratigraphic ®Development ❑Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation. August 21,2013 ❑Oil ❑WINJ ❑WDSPL ❑Plugged 16. Verbal Approval: Date ❑Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: ❑WAG ❑SPLUG ®Suspended 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jacob Thompson,564-5579 Printed Name: Mary En acott Title: Engineering Team Leader Email: Jacob.Thompson @bp.com Signature: /0 7 -hone: 564-4388 Date: � � /3 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness /�- 2 ,� Sundry Number: J"', ❑Plug Integrity BOP Test ❑Mechanical Integrity Test ❑Location Clearance A Other: ,Gp f � b 5 - f 3.5 7X 2 /s RBA' My OCT 1 0 20 Spacing Exception Required? ❑Yes ©No Subsequent Form Required: /d- 6 7_, ���//� APPROVED BY / Approved By: C17(. /9 --)4e- COMMISSIONER THE COMMISSION Date: g -Z3-L3 Form 10-403 Revised 1A/2012 Approve c ip�i v li f 1 months from the date of approval Submit In Duplicate ,1% ON 1(0113U N I /' 01.°*',i1 Øbp GP6sp Well Name: 02-01B Well Type: Producer Current Status: Oil Producer Shut-In Request: P&A—Well Prep f/Rotary Sidetrack MIT—IA passed to 3000 psi (3/4/13) MIT—OA passed to 2000 psi (3/4/13) Well History: A RWO in June-2008 installed a fully cemented 7" scab liner from the existing production packer depth (-8580' MD) back up to 2968' MD to remediate a cretaceous leak. The RWO lost a fish downhole, but the fish ended up below the production packer, and became wedged between the 9-5/8" and the 3-1/2" liner. Subsequent interventions had trouble passing the 'fish behind pipe' spot, so SL set a 13' entry guide to bridge the gap. Even with this guide shoe, no drifts have been able to get into the 3-1/2" liner. Reason for P&AIRST: 02-01B is currently shut-in for high GOR. IAxOA communication is unmanageable on gas lift (suspected thread leak). All wellwork options have been pursued on re-accessing the liner, but to no avail. That rules out CTD, and a rig sidetrack is the only remaining option for this well. Proposed Pre-rig prep work: (scheduled to begin immediately after sundry approval) 1. MIT-IA 3500 psi. MIT-OA 2000 psi. 2. Injectivity test. 3. Perform a full-bore P&A of the existing 3-1/2" coil liner with 26 bbls 15.8 ppg Class G cement(est TOC at ✓ 8550' MD). 4. PT cement to 2500 psi. 5. D&T cement. 6. R/U E-line and perform tubing punch above production packer at 8400' MD 7. Fullbore P&A(circ.) (-49 bbls of 15.8 ppg G cement. Est TOC at 6950' MD) 8. D&T cement. Drift for jet cut on tubing. 9. Jet cut tubing at—3200' MD. 10. CMIT-TXIA to 3500 psi. 11. PPPOT-T and IC. Function LDS. 12. Set BPV and test. 13. Install dry-hole tree. Planned Rig Work: (scheduled to begin November 1st, 2013) 1. MI/RU Parker 272/confirm barriers. 2. Nipple down tree. Nipple up BOPE and test to 250 psi low/3500 psi high. 3. RU and pull the 4-1/2" 12.6#tubing from the pre-rig jet cut at—3200' MD. 4. PU 8-1/2"clean-out assembly and RIH to clean-out 9-5/8"casing to top tubing stub at—3200' MD. 5. RU E-line and RIH w USIT/ CCL/ GR 3200' MD and log to surface to determine TOC behind the 9-5/8" casing in the OA(est TOC—2185' MD). 6. RU E-line, RIH with GR/CCL and 9-5/8" EZSV for 47# casing. Set the EZSV at —2910' MD (competent sand / confirm with GR) as required to avoid cutting a casing collar while milling the window. POOH. Rig down E-line. 7. Pressure test the EZSV to 3500 psi for 30 minutes and chart. 02-01B Sundry Application 1 8/7/2013 • • 8. MU a Baker 9-%" multi-string cutting assembly. Cut the 9-%" casing above the TOC as determined from USIT log. POOH, L/D assembly. 9. Change out to 9-%" rams, and test rams to 250 psi low/3500 psi high. Th,5 10. MU casing spear assembly and unseat the 9-%". Pull the 9-%" casing from the cut. 11. Change out to 2-7/8"x 5-1/2"VBR Rams. Test to 250 psi low/3500 psi high. 5vvi.21K7 12. RIH with casing scraper and clean-out the 13-%" casing and dress off the 9-%" casing stub. A 13. PU and RIH with 9-5/8" Baker bottom-trip anchor whipstock assembly and 8.5" window milling assembly (to include full gauge string mills). RIH to the top of the EZSV. Orient and set the whipstock. Shear off —_ the whipstock. 14. MU 8-1/2" intermediate hole=1 • ' ' '►Y an• Iri o I in "e o ri•: P. POOH lay down drilling assembly. 15. Change out to 7"casing rams and test to 250 psi low/3500 psi high. 16. RU, run and cement 7" casing string. Test casing to 250 psi low/3500 psi high 17. MU 6-1/8" production hole BHA(GR/RES/Neu/Den)and drill production hole to TD in Z1A/B. 18. RU and run 4-1/2" production liner and cement in place. Test liner to 250 psi low/3500 psi high 19. MU and RIH with perforation guns and perforate the 4-1/2" liner. /f"'P✓ p 20. RU and Run 4-1/2" completion, drop ball and rod and set packer, test tubing and IA to 250 psi low/3500 psi high. 21. Shear GLM circulate corrosion inhibitor, install TWC test to 250 psi low/3500 psi high. 22. ND BOP, BU tree install BPV test to 250 psi low/3500 psi high. Freeze protect well. 23. RDMO. Drilling Engineer: Jacob Thompson (907) 564-5579 Production Engineer: Ryan Rupert (907) 564-4238 Geologist: Ben Siks (907) 564-4502 66, A65 141" AG CC ►W. J wet v�?r�( c-grs Q �A fis T° t/o.. For 7-4' p�r,`�/ / �i`J". vv,i/ 1 Plui95-4 GrhrO 3 /.,"co 71(044 t o /c7ct Ole the 1 02-01B Sundry Application 2 8/7/2013 • • w TREE* A ____._,_ .caw 02-01 - SAFETY NOTES: WELL ANGLE a 70"•9511`. ACTUATOR BAKER C TOOLS HANGING UP +1-8590'(3-112"LNR Tag.ELEI/_ 7zr TOP)NOTED ON 02122101. 11129,04 NOTE: BF.ELEV= N/A 0P- 545A ( ' OVER AND WELL 02ABANDONE�o"5#00000 K Mix Angle:. 99'Ill 10049' CHROME TBG S NIPPLES*** Datum MD 9425 CatumTVD 9800'SS , 2 0 8 6' H4-1/2"1ES X MP,10=3.813" I 2690' 9=12.34 394 " j--4518"X 7°SKR C B2 ZXP LIP w tKR 1 i3-318 CSG,720,L-80,ID T' H-{ JI FLEXLOCK HGR AND TEBACK SLV,ID_6280" ; ;'r GAS LIFT MAI .S Minimum IDs 2.75" 8589" 4 :4 ST MD TVD DEV TYPE VIM LATCH PORT' DATE f 11;4 ® 3499 3495 ®KBG2 CAW 0 06/14109 3.50" ENTRY GUIDE 1 14 6033 5993 KBG2 CMY 0 06/14/09 H4-12'/ , ,�0 8411' H7"X41/7BKRS-3PKR,D-3.875- 4-1/7'TBG,12.6'1,13CR-60 YAM TOP 8457' i ._+�. XG TO 13CR 80 STL 1 II I.,7 84,45' H4-117 HES X NIP,ID=3.813" I / I7"SCAB LNR,2910.L 817 BTGM D 6.184- 8478' ,., ' H9-5/8"" I i,, 11'4 8580' HS 2 BAKER PBR ASSOiERSHOT I5-112-186 STUB —I 8505' /44' t+ = « FISH: 16'BHA 4-11116"MILL,X0,BOOT — 8804' 4'I;, �I�1 85139 I-112.5',3.50+'ENTRY GUIDE,D 2-75 (08/29109) BA SKETJA ANIED BESIDE LNR DURING AIgi 1�/+ 8595' H9-5l8"X 5-112"BKR SAB PKR,D=4.75" 06/06 RWO a MI ' 8595' 5-112"TBG TAIL BACKED OFF BELOW PKR 4-112-T80,12-61,I3CR-00 STL, —I 8605' DURING 06/08 RAO .0152 bpf,D=3.958" I )ri 8605' 4-112"MULE SHOE,D=3.958- I STOP OF 3-1/2"LNR 8810 8644' 1--15.112'OTIS XN 10,,ID-4.455"(BE6NO LNR) 8845' 5-117 BKR SHEA ROUT SUB(B9UP D LNR) 1 5.1/7 TBG-PC.176,L-80,.0232 bpf,D=4.892' H 8646' i 8645' 1-16-112"TUBING TAIL(BEN NO LNR) I 8620' H ELMD TT LOGGED 04/23!90 1 9-5/8"CSG,474,L-80,D=8 681"H 9327' 1---A I4FORATIDNSUMMARY REF LOG: OHCS ON 4120+1980 ANGLE AT TOP FERE. 73' 9520 I Note:I2sfar to Ptaduction 0B for historical pert data SIZE SPF INTERVAL Opn/Sgz BATE 1-11/10'&2-1/8" 4 9520-9719 0 09/20/97 4\4,2.1/7 4 9740-9880 0 05/17100 1-11/16'&2-118" 4 9880-10040 0 09/20/97 1-11/16"&2-1/8" 4 10281-10371 0 09/20/97 1-11/16"&2-118" 4 10419-10610 0 09/20/97 2-117 4 10610-10810 0 05/17100 11708' PBTD 34/2"LC,ID=1.611"I 1-11/112'&2-1/8" 4 1/1131/!-11t$l0 O 09/20/97 1 1-11/16'&2-1/8' 4 11130-11170 0 09/20/97 1-11/10'&2-1/8" 4 11280-11350 0 02/22/01 1-11116'&2-1/8" 4 11390-11509 0 02/22/01 't!'' 1-11/16`&2-1/8' 4 11620-11700 0 02/22/01 +17 - 13-1R'LNR,9.34,1-80,.0087 bpf,D"2.932' H 11772' DATE REV BY COMMENTS DATE REV BY COMNIFN'S PRUDHOE BAY IJNI7 11106/75 ORIGINAL COMPLETION 03/10/10 JR/JA+D DRLG DRAFT CORRECTIONS WELL.02-01B 09120/97 CID SIDETRACK(02-01131 06/12/12 OM/JMO TREE CORRECTION(OW 1/12) FERMI No:1971400 06115108 N2E13 RYYO AR No:50-029-20442-01 06/2808 GJBISV GLV CIO SEC 36,T11 N,R14E 651'FM_&1696'FWL 06/14/09 MBNYTLH OLV Cf0 1 12/14 BSEISV SET ENTRY GUIDE 108/29/09) 031'Ixploration(Alaska) 02-01B Sundry Application 3 8/7/2013 v • • • TREE= O1N/ SAFETY NOTES:WELL ANGLE>TO"la 9511'. ACTUATOR= GRAY O 2_u i B TOOLS HANGONG UP @+l-85W(3-112"LNR ACTUATC42= BAKEI2C; a ELEV= 65.0' P re-Rig TOP)ROTH)ON 02122101. 11129104 NOTE BF.ELEV= NA WELL 02-01 WAS ABMIDONH),RIG SIf7DOED KOP= 5450' OVER AM)WELL 02-01ASPUODED."'4-112" Mu Angie= 99'a 10049' Estimated 1OG 2166" CHROME TAG&NIPPt S;"' Datum ND= 9425' Daturn IVD= 8800 SS 2066' H4-1/7 FFS x NP,D=3.813" I s 113 318'CSG 721k,L-80,D=12.347' H 2680' � ,: 0-6/9'X r 8141 C-2 Zxp LIP,"18141 Jet cut 3200' ELEXLOCK HGR AND 1933ACK SLV,D=6.280" Minimum ID=2.75"@ 8589' .II GAS LFTMANDRELS 3.50"ENTRY GUIDE $ �_'7;� sr IuD TVO CEV LATCH PORT DATE --- 1 !'f 2 3499 3495 ®B OW 0 06(14/09 Est TCC on 9 5t8"Ceg �6225' 44 _ IIf 1 6033 5993 DIN 0 06/14/09 Top of DP21(Cretaceous)6388'WOsa - 6648' I- '1 4 -- 141• r $ 4 � 8380' --14-1/2"HES X NP,D=3.813" I TOG on both sides of the 4-172 Tby 69150 / ' ' 11 1.: .: 8411' j--17"X 4-112'Bl(R S-3 M(R D=3.875' 1 Tutting Flinch 8400' (� �l�f'' 8445' H4-1/7H PIP I 1 1/71613,12.07t,1201 66 VAM TOP { 8457' F i, o'; X0 TO 13CRA0 S1L . /y 141 p7"SCAB LNR,297F,1-80 BTC-M,D=6.184• 8478• 1� 11,4 1 r 14 B$1 B' 9518'X51rz-li]lEQVERSkDT I Oa ; 1 5-117 TBG STl6 860S •♦4 111 " �I♦ 14, r4i't 1 8580' 1--15-112"BAKER PER ASSY I TOG 8550 "' .14 1! IA 1 soy 12.5',350"ENTRY Gl1DE,D=2.75'(08129109) I 4-1/7 TBG,12 AP,13CR-00 STL, --I 8805' ft; , 1 $596' H9-518'X 5112'BKR SAB PKR,D'4.75' I .0152 bpi,D=3.958' ,1("*4• 0 sob' I–{4-1/2'M.LE SHOE,D=3.958' I I esseetc4 TOC of 3-12-Liner 8610- I 8�;' H5.117011SKNf '.D=4.455"(BEHINDLNR) I TOF OF 3.112'LM –I 8810' •+ ` • ' ` 8645' —15-12'BKR SFEAROUT SUB(BEANO LNR) I 15-1/7 TBG-PC.178,L-80,.0232 bpf,0=4297 j-t 8848' ..1---— «- ' 8648' H5-112'TUBING (WNW(W LNR) I Top of DPZ3(Say River)8,288'WOas 8862• 4 J–i � / 882•' HELLO TT LOGGED o42sueo J • 1 9-58'CSG,47e.L-80,D=8.991`H 8327' ` PERFORATION SUMMARY 4 REF LOG 13H CS ON 4/20/1980 ; , . I ANGLEAT T Pr OPRRE_ 73'fp 9620' .M Note:Refer to oduclion OS for historical pelf data SEE SW 99199/AL Opn/Sgz DATE 1.11116"&2-118" 4 9520-9719 S 09/20797 ` `°0, `, 2-1/2' 4 9740-9880 S 05117100 ` •` 1-11/16"&2-1/8" 4 9880-10040 S 09120/97 • " 1-11/16'&2-118' 4 10281-10371 S 09/20/97 1-11/16'&2-1/8" 4 10419-10610 S 09120/97 11700' HPBTD 3.12"LC,D=1.611j 2-1/2" 4 10610-10810 S 05/17100 1-11116"&2-118' 4 10810-11090 S 09/20/97 1-11116"&2-118' 4 11130-11170 S 09/2097 4 1.11/16'&2-1/8" 4 11280-11350 S 02(22/01 Este'. 1-11/16"&2-1/8' 4 11390-11509 S 02122/01 41.1, 1-11/16'&2-118' 4 11620-11700 S 02/22101 1 3-1/2'IM(,9.307,L-80,.0087 bpf,D=2.932' H 11777' I DATE—REV BY COMMENTS DATE REV BY ..--COMMENTS PRUDHOE BAY UNIT 1 1744175 01011iruiL GOILE11011 I U3/1WMU JVJMU UKLU UKAI-I UUIU(tGHUN'S WELL W-U1O 08/20/47 C70 SfOE TRACK(02018) j 06112/12 DMI.6D TREE CORRECTION(06111!12) PERMIT No.1971400 06/16108 N2E5 RWO API No.50-029-20442-01 06126106 G.RIISV GLV C/0 SEC 36,T11N,R148,651*FNL&1096'FNIL 06114109 MBM/FLH GLV C/C _. _ 12/14/09�_BSE/SV SET EN-RY GUIDE(08129/08) BP Espbration(Malta) 02-01 B Sundry Application 4 8/7/2013 • • TREE= aw WELLI-EAD= GRAY O ACTUATOR= BAKER C -O NOTES: ABANDONED,RIG SKIDDED OVER AND WELL 02- KB.ELEV 650' Proposed RST 01ASPUDDED BF.ELEV — N/A KOP= 5450' Max Angle= 99 @ 10049' ,/DatumhD= 9425 I tum7VD_ 8800'SS ' I —2200 IH14-1/2"I�X NP,ID=3.813" 120"CONDUCTOR.944.H-40.ID=19.124" II 110' 9-5/8"Csg Cut —2100' GAS LFT MAMJRELS ST MID TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80,D=12.347' 2690' 1 2 3 4 Minimum ID= 5 0 9-5/8'CsG,47#, L-80.D=8.68r H 2910• 11. 9-5/8" whipstock at—2910' PERFORATION SUMMARY 1�1�1�.�#* REF LOG: ••••, ANGLE AT TOP FERF: # ,(•4•.4• Note:Refer to Production DB for historical pert data 4 4.*� SIZE SPF INTERVAL Opn/Sqz DATE 8206' —14-1/2"H S X NP,$D 3.813" I ►� 0-1 8236' H 7"X 4-1/2'FxR 4-i/2"I-ES X NP,D=3.813" — 8266' I I 8336' H4-1/2"FES XN NP.ID=3.725" 14-1/2"TBG,12.64,13Cr-80,D=3.958' I—{ 8366' 8366' H TOP OF 4-1/2"LNR RA Tag and two 10'Marker Joints — 8420' ilk 7"CSG,26#,L-80,10=6.276" --I 8515 2`° T" @ TS G R RA Tag and tw o 10'Marker Joints — 11660' 4-1/2'LNR 12.5#.13Cr-85,D=3.958" — 12660' I ` 90° DATE REV BY COMMB'1TS DATE REV BY COMMENTS PRLDHOE BAY UNIT 11/06/76 ORIGINAL COMPLETION 03/10/10 JR/JMD DRLG DRAFT CORRECTIONS WELL: 02-01C. 09/20/97 CTD SIDETRACK(02-01 B) 06/12/12 OMIJMD TRH CORRECTIONS(06/11/12) PERMIT No: 06/15/08 N2ES RWO 03/15/13 GJS PROPOSED RST API No: 50-029-20442-02 06/28/08 GJBISV GLV CIO SEC 36 T11N R14E 651'FNL 1696'FWL 06/14/09 MBM/TLH GLV C/O 12/14/09 BSE/SV SET WIRY GLADE(08/29/09) BP Exploration(Alaska) 02-01B Sundry Application 5 8/7/2013 • • • • PARKER 272 BOP STACK RAM TPE BOP: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP „L______D, 13 5/8"-5M FLANGED BOTTOM ANNULAR BOP: W/(2) 14" UL2 OPERATOR, UPPER CAVITY SHAFFER LXT 13 5/5"-5M AND (2) 14" PSLK W/BSTR OPERATOR, , , 11 1 MI Ai 191 , 13-5/8" SM STUDDED TOP LOWER CAVITY 13-5/8 SM FLANGED BOTTOM 0 0 1 I DRILLING CROSS: 13 5/8"-5M FLANGED TOP 1• iii■M I: 13 5/8"-5M FLANGED BOTTOM / 1 m■IA Ci? --,7 .er•■■ : 1: *.1(.2. -• : W (2) 3 1/8"-5M SIDE OUTLETS . _ 111111■ 7 . 11 . ,,,, ... ■•••■• .....•.'Ailik 6) _ .■•■1 : 3 1■INNO 'a. gir"' .!i■Ill 1 1 - KILL LINE: '4111AT(11.11-* •,.. ..... viliA•41g;:t..1,..p..1., rOlk,,41--k, ..r.t...■iA-Ap...111. .. 2-1/16" 5M FLEX HOSE 2-1/16" 5M X 3-1/8" 5M D.S.A. l'I gwo..%”*"'Vw7/17, m' '.° ,Nit_.%ilrel:::: 1 111'■■■.. 3-1/B" 5M FLANGED MANUAL GATE VALVE 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE E a °coo qMill■I: E ■ : -- . .■•11-- .... • ■INE. 1 I CHOKE LINE: RAM TYPE BOP. 3-1/8" 5M FLANGED MANUAL GATE VALVE . . SHAFFER LXT SINGLE 13 5/8" 5M 13 5/8"-5M STUDDED TOP 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"- 5M FLANGED BOTTOM 3-1/8" 5M FLEX HOSE W/(2) 14" UL2 OPERATOR 02-01B Sundry Application 6 8/7/2013 • • • Ferguson, Victoria L (DOA) From: Thompson,Jacob <Jacob.Thompson @BP.com> Sent: Monday,August 19,2013 2:27 PM To: Ferguson,Victoria L(DOA) Subject: RE: PBU 02-01B Plug for redrill(PTD 197-140, Sundry 313-439) Follow Up Flag: Follow up Flag Status: Flagged The MASP is 2231 psi. Let me know if you need any more info. Thanks, Jacob. From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson©alaska.gov] Sent: Friday,August 16, 2013 9:27 AM To: Thompson, Jacob Subject: PBU 02-01B Plug for redrill(PTD 197-140, Sundry 313-439) Jacob, Please provide the MPSP for this well. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson a(�alaska.gov 1 • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 Hi- r 7 ikB REce Mr. Tom Maunder AUG 31 2n Alaska Oil and Gas Conservation Commission 333 West 7 Avenue it & Gas C vac G Anchorage, Alaska 99501 Ancter $ Subject: Corrosion Inhibitor Treatments of GPB DS -02 Dear Mr. Maunder, �� ZU1 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 02 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of . cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -02 Date: 07/21/2011 Vol. of Corrosion Initial top of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal C 02-01B 1971400 500292044201 Sealed NA Sealed N/A NA NA 02 -02A 1971680 500292007401 5' NA 5' N/A 74.80 5/20/2011 02 -03B 2002170 500292007702 38' 11.0 4" 7/13/11 3.40 7/21/2011 02 -04A 1961580 500292006401 0.2 NA 0.2' N/A 1.70 4/27/2011 02 -05A 2030820 500292008101 4.5' NA 4.5' N/A 68.00 5/19/2011 02 -06B 2040850 500292008602 6' NA 6' N/A 20.40 6/2/2011 02 -07A 1981070 500292015401 Sealed NA Sealed N/A NA NA 02 -08B 1980950 500292015502 Sealed NA Sealed N/A NA NA 02 -09C 2071390 _500292015303 Sealed NA Sealed N/A NA NA 02 -10B 2000640 500292016302 Sealed NA Sealed N/A NA NA 02 -11A 1981260 500292027301 Sealed NA Sealed N/A NA NA 02 -12B 2070580 500292027702 Sealed NA Sealed N/A NA NA 02 -13B 2012430 500292043302 Sealed NA Sealed N/A NA NA 02 -14A 2031250 500292044601 Sealed NA Sealed N/A NA NA 02 -15A 1960420 500292044701 Sealed NA Sealed N/A N/A NA 02 -16C 2070870 500292044803 Sealed NA Sealed N/A NA NA 02 -17B 2051300 500292045302 Sealed NA Sealed N/A NA NA 02 -18B 2061860 500292045402 Sealed NA Sealed N/A NA NA 02 -19 1811860 500292069300 Sealed NA Sealed N/A NA NA 02 -20 1820290 500292072100 Sealed NA Sealed N/A NA NA 02 -21A 2010990 500292078101 Sealed NA Sealed N/A NA NA 02 -22B 2100520 500292074002 Sealed NA Sealed N/A NA NA 02 -23A 2000530 500292079501 0.5 NA .5' N/A 5.10 5/19/2011 02 -24A 2040300 500292074401 0.5 NA .5' N/A 3.40 5/19/2011 02 -25A 2080910 500292076601 0.2 NA .2' N/A 0.85 5/19/2011 02 -26C 2050190 500292077403 0.2 NA .2' N/A 0.85 5/19/2011 02 -27A 1990930 500292199401 12.5' 8.5 3" 7/8/11 1.70 7/12/2011 02 -28A 2041640 500292201201 Sealed Sealed N/A NA NA 02 -29C 2040510 500292201103 65' Top Plate N/A NA NA 02 -30B 2001260 500292220202 Sealed NA NA N/A NA NA 02 -31A 1990150 500292222701 1.5' 1.5' N/A 11.05 5/18/2011 02 -32B 2020230 500292220902 1.1' 1.1' N/A 5.10 5/19/2011 02 -33B 2090450 500292221402 1' 1' N/A 8.50 6/1/2011 02 -34B 2100290 500292223402 0.8' 0.8' N/A 5.10 5/18/2011 02 -35B 2060020 500292222202 1.5' 1.5' N/A 10.20 6/1/2011 02 -36A 2100780 500292287701 19.6' 11.5 5" 7/8/11 2.55 7/12/2011 02 -37 1961750 500292271700 0.1 0.1 N/A 0.85 5/18/2011 02 -38 1961610 500292270800 1.5' 1.5' N/A 15.30 5/18/2011 02 -39A 1971100 500292272100 1.5' 1.5' N/A 11.90 5/18/2011 02 -40 2071620 500292337700 2.9' 2.9' N/A 25.5 5/18/2011 - ~~~ STATE OF ALASKA ~ s :, ~ . AL~ OIL AND GAS CONSERVATION COMION ~~L. ~ ~ Z~~~ REPORT OF SUNDRY WELL OPERATIOQ {~it,~ ~ ~ ~ ~~~~,~ ~:r,, fig; -~ ~rE F/~. 1. Operations Performed: ^ Abandon ®Repair Well - ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ® Alter Casing ®Pull Tubing - ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ^ Operation Shutdown ^ Perforate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. - ®Development ^ Exploratory 197-140 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20442-01-00- 7. KB Elevation (ft): 65, - 9. Well Name and Number: PBU 02-01B' 8. Property Designation: 10. Field /Pool(s): ADL 028308 ~ Prudhoe Bay Field / Prudhoe Bay Pool 11. Present well condition summary Total depth: measured 11772' feet true vertical 8858' feet Plugs (measured) 11220' Effective depth: measured 11706 feet Junk (measured) -8610' true vertical 8857 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 75" 20" 75' 75' 1530 520 Surface 2690' 13-3/8" 2690' 2689' 4930 2670 Intermediate 9327' 9-5/8" 9327' (TOW) 8790' 6870 4760 Production Liner 3168' 3-1/2" 8610' - 11772' 8195' - 8858' 10160 10530 Scab Liner 5548' 7" 2968' - 8516' 2966' - 8119' 8160 7020 ~~Nf~ JUL ~ y= 20~$ Perforation Depth MD (ft): sszo'-,1170': Below Plug (11280' -11700') Perforation De th TVD ft : asls' - 8eao', p ( ) Below Plug (8878' - 8857') 4-1/2", 12.6# 13Cr80 8605' Tubing Size (size, grade, and measured depth): Packers and SSSV (type and measured depth): 7" x 4-1 /2" Baker S-3 Packer, 8411' 9-5/8" x 5-1/2" Baker'SAB' packer 8595' 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment description including volumes used and final p ressure: Cut and pull tubing from 8505". Run 7" (29#, L-80) scab liner. Cement w/ 205 bbls Class'G' (1151 cu ft / 992 sx). Clean out and run new Chrome tubin . 13. Re resentative Dail Avera a Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ^ Copies of Logs and Surveys run 15. Well Class after work: ~ ~ ^ Explorato ry ®Development ^ Service ^ Daily Report of Well Operations 1 Status after work: ^ Well Schematic Diagram Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact John Rose, 564-5271 308-188 Printed Name Sondra Stewman Title Drilling Technologist / Sign ture Phone 564-4750 Date Prepared By Name/Number: ~-~ondra Stewman, 564-4750 Form 10-4(~4-R~c I~sed 04/2006 ~~ S ~~. ~Ui ~` .~ 1008 Submit Ig)nalOnly ~~~ a TREE = CNV 4-1/16" 5K WELLHEAD=Gray New STD ACTUATOR = KB. ELEV..- 65 BF. ELEV... KOP = 5450' Max Angle = 99 @ 10049' Datum MD = 9428' Datum TV D = 8800' SS 4-1/2" X-Nipple 2200` 02-0~ s 13-318" CSG, 72#, L-80, ID = 12.347" 2690' 9-5/8" x 7" ZXP Liner Top - 2968' MD 7", 29#, L80, BTC-M Scab-Liner w/9-5/8" x 5-1/2" Unique OS (15` 4-1/2" X-Nipple 8445' MD 4-1/2", 12.6#, 13 CR, VamTop Completion to 8457` 4-1/2",12.6#, 13Cr-80, STL Completion 8457' - 8605` 4-1/2" Mule Shoe above 3-1/2" liner 8605`MD Mill, XO, Boot Basket x2, XO jammed between 3-1 /2" and 9-5/8" Minimum ID = 2.932" @ 8610' 3-1 /2" Liner 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID = 4.892" I-I $645' 9-5/8" CSG, 47#, L-80, ID = 8.681"~-{ 9327' PERFORATION SUMMARY REF LOG: BRCS ON 4/20/1980 ANGLE AT TOPPERF: 73 @ 9520' Note: Refer to Reduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" & 2-1/8" 4 9520 - 9719 O 09/20/97 2-1/2" 4 9740 - 9880 O 05/17/00 1-11/16" & 2-1/8" 4 9880 - 10040 O 09/20/97 1-11/16" & 2-1/8" 4 10281 - 10371 O 09/20/97 1-11/16" & 2-1/8" 4 10419 - 10610 O 09/20/97 2-1/2" 4 10610 - 10810 O 05/17/00 1-11/16" & 2-1/8" 4 10810 - 11090 O 09/20/97 1-11/16" & 2-1/8" 4 11130 - 11170 O 09/20/97 1-11/16" & 2-1/8" 4 11280 - 11350 C 02/22/01 1-11/16" & 2-1/8" 4 11390 - 11509 C 02/22/01 1-11/16" & 2-1/8" 4 11620 - 11700 C 02/22/01 ~TY NOTES: WELL ANGLE > 70° @ 9511' & > 90° @ 9610'. 6/15108 Note: Fsh in hole from 8596' to 8610' next to 3-1 /2" liner top. 11/29/04 NOTE: WELL 02-01 WAS ABANDON. WELL2- 01 BHAS ASEPARATE SURFACE LOCATION FROM 02-01. ST MD TVD DEV TYPE VLV LATCH PORT DATE 2 1 3499 6033 3495 5992 5 28 KBG2 KBG2 DOME SO BK BK 16 20 06.126/08 06126/0$ 4-1/2" X-Nipple 8380` MD 7" x 4-1/2" Baker S-3 Packer 8411` MD Top of 5-1/2" Tubing Stub -8505` MD 8580' 5-1/2"BAKERPBRASSY 8595' 9-518" X 5-1/2" BKR SAB PKR, ID = 4.75" 8604' -iSLV Drilled up during workover 06/08 TOP OF 3-1/2" LNR, 9.3#, ID = 2.932" 8610' $1 644' I-~ 5-1/2" OTIS XN NIP (BEHIND LNR), ID = 4.455" 8645' 5-1/2" BAKER SHEAROUT SUB (BEHIND LNR) 8646' -15-1/2" TUBING TAIL (BEHIND LNR) 8620' ELMD TT LOGGED 04/29/80 11220' I-13-1/2"HESMCIBP(02/22/01) 11706' ~-~ PBTD 3-1/2" LC, ID = 1.611" 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.932" I~ 11772' DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06/76 ORIGINAL COMPLETION 09/20/97 CTD SIDETRACK (02-01 B) 06/15!08 N2ES RWO 06/28/08 GJB/SV GLV C/O (06/26/08) PRUDHOE BAY UNrf WELL: 02-01 B PERMrf No: 1971400 API No: 50-029-20442-01 SEC 36, T11 N, R14E, 651' FNL & 1694' FWL BP Exploration (Alaska) Page 1 of 2 ~ • Well: 02-01~ C~ /~~ Well History Well Date Summary 02-01 B 5/2/2008 ***WELL S/I ON ARRIVAL***(pre rwo) DRIFTED THRU TUBING W/ 5 1/2" GS (4.49" OD) TO LINER TOP @ 8599' SLM DRIFTED THRU LINER W/ 2.80" CENT TO 8800' SLM ***RDMO, RETURNED WELL TO DSO S/IN*** 02-01 B 5/3/2008 T/I/0=xxx/xxx/xxx Assist E-Line w. TBG load, CMIT T xIA to xxx psi (Pre RWO) Pumped 02-01 B 5/3/2008 T/I/0= 280/300/60. Temp SI. Shoot TBG & IA FL (pre E-line). TBG FL @ 900'. IA FL @ surface. 02-01 B 5/3/2008 ***WELL SHUTIN ON ARRIVAL*** (pre rwo) JOB POSTPONED DUE TO HIGH WINDS. ADVISED TO LEAVE LOCATION & WAIT FOR WEATHER TO CALM DOWN. ***WELL LEFT SHUT IN WITH DSO*** 02-01 B 5/3/2008 T/IA/OA= 0/0/0 Temp=cold PPPOT-T (PASS) PPPOT-IC (PASS) (PRE RWO) PPPOT-T RU 2 HP bleed tools onto THA 50 psi to 0 psi, flush void until clean returns achieved. Pressured to 5000 psi for 30 minute test, 5000/ 15 minutes, 4950/ 30 minutes. Bleed void to 0 psi, RD test equipment, re installed Alemite cap. Cycle and torque LDS "Standard" all move free with no bent pins. PPPOT-IC RU 2 HP bleed tools onto IC test void 0 psi, flushed void until clean returns achieved. Cycle and torque LDS "Standard" several are tight but all move free with no bent pins. Pressure void to 3500 psi for 30 minute test, 3400/ 15 minutes, 3400/ 30 minutes. Bleed IC void to 0 psi. RD test equipment re- installed Alemite caps. 02-01 B 5/9/2008 *** WELL SHUTIN ON ARRIVAL *** INITAL T/I/O 330/240/30. RU ELINE AND SET 4.47" HES FASDRILL IN 5-1/2" TUBING AT 8534 FT MID-ELEMENT, TOP OF LU AT 8533 23 ***JOB CONTINUED 10-MAY-2008*** 02-01 B 5/9/2008 Travel to location/ Stand by for E'line- **Continued on 5-10-08** 02-016 5/10/2008 ***CONTINUED FROM 9-MAY-2008*** ELINE RU LRS TO PT HES FASDRILL IN TBG / IA COMBO TO 3500 PSIA -FAILED.. RAN LDL W/ STP TOOLS, IA X TUBING LEAK FOUND AT 3807' AND PREDICT IA X FORMATION LEAK. PLUG IS NOT LEAKING AND TEMPERATURE RE SSES SHOW NO LEAK PAST PACKER. JETCUT TBG AT 8520'. JOB COMPLETED. FINAL T/I/O = 560/550/50 *** WELL LEFT SHUTIN ON DEPARTURE*** 02-01 B 5/10/2008 T/I/0=440/360/20 Assist E-line to pt plug, CMIT TxIA FAILED to 3500 psi. Established a LLR-T - 1 bpm C~ 3000 psi down tbg while IA never pressured up over 1200 psi. [RWO prep] Pumped 38 bbls crude down Tbg in attempt to CMIT. Pressured up Tbg to 3000 psi and when pump offline tbg decreased to 480 psi in 4 mins. IAP slowliy increased to 1000 psi and decreased to 460 psi w/pump offline. Decision made to assist a-line w/ production log. Pumped 156 bbls crude down tubing while a-line logged maintaining 3000 psi on the tbg. The IAP never increased over 1200 psi. Upon SD of pump pressures bled down to finals. Released from jobsite. FWHP's=600/660/140 ---IA & OA valves checked for position and tag hung upon completion of job--- 02-01 B 5/10/2008 T/I/0=700/600/80 Cric ouUBullhead, [Pre RWO] Pumped 5 bbls neat meth followed by 195 bbls 9.8 ppg NaCI brine down TBG, thru jet cut, up IA to flowline. -----In Progress----- 02-01 B 5/11/2008 ***Continue from 5-10-08*** Cric ouUBullhead, MIT OA PASSED to 2000 si. (Pre RWO) Pumped 665 bbls 9.8# brine (Total 860 bbls) down tbg, througFi jet cut, up , to ang returns to flowline. RD from tbg, RU to IA. Bullheaded 5 bbls neat meth, 225 bbls 9.8# brine down IA. Freeze protected Flowline. MIT OA to 2000 psi.. Pumped 2.3 bbls crude down OA to pressure up to 2010 psi. OA lost 80 psi in 15 min and 40 psi in 2nd 15 min for a total 30 min pressure loss of 120 psi..Bled WHP's to 0 psi. Final WHP's =Vac/0/0+ --Tags hung and wellhead valves checked for position upon departure-- 02-01 B 5/13/2008 T/I/O =Vac/0/0 Set 5" Gray BPV Pre Rig 02-01 B 5/24/2008 T/I/0=0/0/0. Rolled 1/A & O/A valves to back side of well. 02-01 B 5/31/2008 T/I/0=0/0/0. Pull 5" Gray type K BPV thru BOPE after rig test. 02-01 B 6/10/2008 ***RIG JOB ON 2ES*** CURRENTLY STANDING BY TO RIG UP SLICKLINE UNIT ***CONT WSR ON 6/11/08*** Page 2 of 2 02-01 B 6/11/2008 ***CONT WSR FROM 6/10/08***(RIG JOB ON 2ES) DRIFT TO 8621'SLM W/ 1.90" CENTW/ BULL NOSE.(UNABLE TO PASS) RAN 1.90" CENT.2'xi-1/2" STEM, 2.10" CENT.2.0" LIB TO 8621'SLM (LARGE V SHAPE CHUNK OUT OF SIDE OF LIB) RAN 2.0" LIB TO 8622' SLM.(INCONCLUSIVE MARKS ON SIDE OF LIB.) RAN 10'x1-3/4" P-BAILER TO 8657' SLM. (WORK BAIL~Ft~N6FECCFA57 RESTRICTION) RAN 1.75" TAPERED LIB TO 9500'SLM (SAW SLIGHT BOBBLE) RIH AND POOH AT 8621'SLM. (INCONCLUSIVE MARKS ON SIDE OF LIB. 02-01 B 6/14/2008 ***NABORS 2ES RIG SUPPORT*** (rwo expense) PULLED 4-1 /2" RHC-M PLUG BODY FROM 8448' SLM. DRIFTED TBG W/ 2.0" SWEDGE TO 9000' SLM W/ NO RESTRICTIONS. ***CONT. JOB ON 06/15/08 WSR*** 02-01 B 6/15/2008 ***CONT. JOB FROM 06/14/08 WSR*** (rwo expense) SET 4-1/2" XX-PLUG (4 x 1/4" & 4 x 1/8" ea-oortsl IN X-NIPPLE C~3 8448' 02-01 B 6/15/2008 T/I/0=0/0/0; Pulled 4-1/16" CIW "H" TWC #200 thru tree for 2ES Com letion; 1-2' ext. used, tagged C~3 102" ***Comp ete es ort am 02-01B 6/18/2008 T/I/0=0/0/0; Pulled 4-1/16" CIW "H" BPV thru tree ost-ri ; 1-2' ext. used, tagged @ 102"; ***Complete*** (Best/Wortham 02-01 B 6/25/2008 ***WELL SHUT-IN ON ARRIVAL*** (post rwo) PULLED DMY GLV FROM STA. #1 C~ 6033' MD PULLED DCK VLV FROM STA. #2 C~3 3499' MD ***CONT. ON 6/26/08 WSR*** 02-01 B 6/26/2008 ***CONT. FROM 6/25/08 WSR***(post rwo) SET LGLV IN STA. #2 C~3 3499' MD (16/64" PORTS, 1500# TRO) SET S/O IN STA. #1 @ 6033' MD (20/64" PORTS) PULLED XX-PLUG FROM BTM X-NIPPLE ~ 8445' MD_ ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED*** 02-01 B 6/28/2008 T/I/0=160/960/420. Temp=Sl. Bleed OAP to 0 psi (eval high OAP). No A/L. OA FL near surface. Unable to bleed because of rig traffic & no bleed tank. DSO bled OAP from 860 psi to 100 psi in 5 mins last night @ 10 pm (fluid gas mix). 02-01 B 7/1/2008 T/I/O = 200/860/490. Temp =Warm. Monitor (post OA bleed). TP unchanged, IAP decreased 20 psi, OAP increased 390 psi overnight. 02-01 B 7/1/2008 T/I/0=200/880/690. Temp=Cold. Bleed OAP to <100 psi. (eval High OAP). OA FL near surface. Bled OAP from 690 psi to 90 psi in 10 minutes, bleed was all gas. Monitor for 30 minutes. OAP increased 10 psi to 100 psi in 30 minutes. No change in TP or IAP during bleed or monitor. Final WHP's=200/880/100. 02-01 B 7/2/2008 T/I/0= 1500/850/580. Temp= Flowing (cold). Monitor (Eval high OAP). No A/L. TP increased 1300 psi, IAP decreased 30 psi, OAP increased 480 psi overnight. 02-01 B 7/4/2008 T/I/0=1500/850/740. Temp=flowing (cold). Monitor (eval high OAP). No A/L. Integral installed on IA companion valve with 3/4" CNG hose attached and SI at Quarter turn valve on manifold. TP &IAP unchanged, OAP decreased 110 psi since 07/02/08. 02-01 B 7/7/2008 T/IA/OA= 1500/10/260 Temp=hot PPPOT-IC (PASS) (Eval well) PPPOT-IC RU 1 HP bleed tools onto IC test void 0 psi, Pressure void to 3500 psi for 30 minute test, 3450/ 15 minutes, 3450/ 30 minutes. Bleed IC void to 0 psi. Did not cycle or torque LDS "Standard" all were in good visual condition. RD test equipment re-installed Alemite caps. 02-01 B 7/7/2008 T/I/0= 1500/1200/550. Temp Hot. Bleed IA <1000 psi & OA to 0 psi. (DSO call in). 3/4" AL SI. Integral on IA. IA FL C~ 8233' (s/o). OA FL near surface. Bled OAP from 550 psi to 0 psi in 15 min to a bleed tank. Bled IAP from 1200 psi to 1000 psi in 1.5 hours to a bleed tank. OAP increased 250 psi during IA bleed. Monitored for 15 min. IAP increased 10 psi. OAP increased 10 psi. Final WHP's= 1500/10/260. Print Date: 7/8/2008 Page 1 of 1 • • BP EXPLORATION Page 1 of 10 Operations Summary Report Legal Well Name: 02-01~C ~j ~~~~~~~ Common Well Name: 02-01ft' C'j Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/30/2008 00:00 - 02:00 2.00 MOB P PRE Move Shops, camp and pits from 02-19 to 02-01 B. 02:00 - 03:00 1.00 MOB P PRE Move sub off of 02-19 and move to 02-01 B. 03:00 - 05:00 2.00 MOB P PRE Lay herculite and spot sub over well. -Close cellar doors and spot pits. 05:00 - 08:00 3.00 RIGU P PRE Plug in pits, berm around required areas, spot cuttings tank, and plug in electricity. Ria accept for operations ~ 08:00 on 5/30/08 08:00 - 08:30 0.50 WHSUR P DECOMP Hold pre-spud meeting for 02-01 B RWO. 08:30 - 09:30 1.00 WHSUR P DECOMP Prepare cellar and wellhead. -Install secondary annulus valves on IA and OA. -Rig up to test BPV and OA. -OA, IA and Tbg = 0 psi 09:30 - 13:30 4.00 WHSUR P DECOMP Test OA to 2000 si for 5 minutes with diesel thr um - ood. Pum down IA to test BPV. -IA took 20 bbls ~ 50 psi. -Inject 50 bbls down IA. Inject 126 gpm ~ 350 psi, 168 gpm C~3 400 psi, 189 gpm C~3 500 psi. -Monitor IA for 15 minutes - no returns. -Blow down and rig down lines. 13:30 - 16:00 2.50 WHSUR P DECOMP Nipple down tree and adapter flange. -Remove from cellar. -Check 5-7/8" ACME threads on tbg hanger -good. -Install blanking plug in BPV to convert to TWC 16:00 - 17:30 1.50 BOPSU P DECOMP Nipple up BOP's. 17:30 - 19:00 1.50 BOPSU P DECOMP Change top rams in stack to 4-1/2" x 7" VBRs. 19:00 - 20:00 1.00 BOPSU P DECOMP Rig up test equipment. -Fill BOP's and choke. 20:00 - 00:00 4.00 BOPSU P DECOMP Test BOPE. -Test Blind Rams, Choke Manifold, mudcross, Kill and Choke lines/valves to 250 psi low / 3500 psi high. -Valve #15 failed on choke manifold - regreased and tested ok. -Rig up 7" test Joint. -Witness of test waived by AOGCC rep John Crisp. Test witnessed by WSL Mark Staudinger and NTP Bruce Simonson. 5/31/2008 00:00 - 04:00 4.00 BOPSU P DECOMP Continue testing BOPE. -Test 4-1/2" x 7" VBR with 7" and 4-1/2" test joint to 250 psi low / 3500 psi high. -Test Annular with 4-1/2" test joint to 250 psi low / 3500 psi high. -Test Top Drive to 250 psi low / 3500 psi high. Test Koomey. Witness of test waived by AOGCC rep John Crisp. Test witnessed by WSL Mark Staudinger and NTP Bruce Simonson. 04:00 - 04:30 0.50 BOPSU P DECOMP Blow down and rig down BOP testing equipment and lines. -Lay down test joints. 04:30 - 05:00 0.50 BOPSU P DECOMP D rod out blankin lu in BPV. 05:00 - 06:00 1.00 BOPSU P DECOMP Rig up DSM, test, and pull BPV. Rig down DSM. -Rig up to circulate. 06:00 - 07:30 1.50 PULL P DECOMP Make up Tubing Hanger Spear BHA. -Engage spear in hanger, back out LDS, and unseat hanger ~ Printetl: 6/30/L008 y:31:20 AM BP EXPLORATION Page 2 of 10 Operations Summary Report Legal Well Name: 02-01A Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/31/2008 06:00 - 07:30 1.50 PULL P DECOMP 205k lbs. -Pull han er to floor with 175k Ibs U Wt. 07:30 - 09:00 1.50 PULL P DECOMP Circulate ~ 8 bpm and dilute brine from 9.8 ppg to 9.4 ppg. 09:00 - 10:00 I 1.001 PULL I P 10:00 - 15:00 I 5.001 PULL I P 15:00 - 21:00 6.00 PULL P 21:00 - 22:30 1.50 PULL P 22:30 - 23:30 1.00 BOPSU P 23:30 - 00:00 0.50 BOPSU P 6/1/2008 00:00 - 02:00 2.00 BOPSU P 02:00 - 02:30 0.50 BOPSU P 02:30 - 05:00 2.50 CLEAN P 05:00 - 11:00 6.00 CLEAN P 11:00 - 13:00 I 2.001 CLEAN I P -Lost 40 bbls during dilution. -Static losses after circulation = 12 b h. DECOMP Lay down Spear BHA. -Cut control lines and break out tubing hanger. -Swap and rig up backup tongs. DECOMP Lay down 5.5" 17# L-80 LTG-ABM t~bina from 8520' to 6284'. -Spool control line with Camco unit -Lay down SSSV and rig down spooling unit. -Recovered 25 clamps and 25 pins (including 1 pulled from BOP cavity). DECOMP Lay down 5.5" tubing from 6284'. -Joints 165 through 208 had several corrosive spots on them (about an inch in diameter and 1/8" deep) randomly located on tubing. -Recovered total of 208 full joints, 1 SSSV, 1 Sliding Sleeve, and cut joint. -Cut joint strapped 14.76' with 6-1/8" OD flare at cut. DECOMP Rig down 5-1/2" handling equipment. -Clean and clear floor. -Drain stack and fish 1 clamp from BOP cavity. DECOMP Change upper rams from 4-1/2" x 7" VBR's to 3-1/2" x 6" VBR's. DECOMP Rig up 4" test joint and install test plug. DECOMP Test BOP stack with 4" test joint. -Test Upper Rams, Lower Rams, and Annular to 250 psi low, 3500 psi high - ok. -Witness of test waived by AOGCC rep John Crisp. Test witnessed by WSL Mark Staudinger and NTP Bruce Simonson. DECOMP Rig down 4" test joint, blow down and rig down test lines. -Install wear ring. DECOMP PJSM. Pick up and make up 5.5" Stub Dress-off BHA with 9-5/8" Casing Scraper. DECOMP Single in hole with drill pipe from 255' to 8499'. -Ta ~ 8499'. -Establish Parameters: Up Wt = 190k, Dn Wt = 140k, Rot Wt = 160k. 40 RPM with 4500 ft-Ibs Free TO. 300 gpm ~ 940 psi. DECOMP Wash and ream down from 8499'. -Pump pressure increase of 400 psi. Taking intermittent weight (Max WOB = 12k Ibs). -Wash and ream to 8505', then broke free (sudden loss of weight and 400 psi decrease in pump pressure). -Continue down and to ~ 8545'. -PU to 8477', slide down and tag top of 5.5" stump ~ 8505'. -Work stump into washpipe, then slide down and fy,Q~Q Printed: 6/30/2008 9:31:20 AM BP EXPLORATION Page 3 of 10 Operations Summary Report Legal Well Name: 02-01A Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABORS 2ES Rig Number: From - To Hours Task Code NPT Phase Description of Operations Date !~ ~ ~L --- 6/1/2008 11:00 - 13:00 2.00 CLEAN P DECOMP -Work pipe with and without pump. 13:00 - 14:00 1.00 CLEAN P DECOMP Circulate hi-vis sweep ~ 13 bpm, 2640 psi. -Once sweep was around bit, pick up above stump and rotate ~ 55 rpm while reciprocating pipe above stump. 14:00 - 17:00 3.00 CLEAN P DECOMP POH from 8505' to 225'. -Change out handling equipment. 17:00 - 19:00 2.00 CLEAN P DECOMP Lay down Milling/Scraper BHA. -Empty boot baskets and recovered 4 full clamps, 1 partial clamp, and 2 pins. -Clean and clear floor. 19:00 - 21:00 2.00 CLEAN P DECOMP Make up 9-5/8" RTTS and RIH to 3473'. 21:00 - 22:00 1.00 CLEAN P DECOMP Set RTTS ~ 3467' and test from above to 3500 psi for 30 minutes - ood. -Release RTTS and blow down surface equipment. 22:00 - 00:00 2.00 CLEAN P DECOMP Trip in hole from 3473' to 8335'. 6/2/2008 00:00 - 00:30 0.50 CLEAN P DECOMP Pick up drill pipe from 8335' to 8489'. 00:30 - 02:00 1.50 CLEAN P DECOMP Set RTTS ~ 8483'. -Rig up head pin and cement hose. Attempt to test from below, but found DP x IA communication through circulation valve. 02:00 - 03:00 1.00 CLEAN P DECOMP Make up top drive and reset RTTS ~ 8481' (center of elements). -Test from below to 3500 psi for 15 minutes - ood. -Attempt to test above - iniectina ra 98 aom. 750 psi - -Rig down, release RTTS, and make up top drive 03:00 - 04:30 1.50 CLEAN P DECOMP Circulate ~ 275 gpm, 675 psi. -Dilute brine from 9.4 ppg to 9.0 ppg. -Appeared to gain 70 bbls in pits during dilution. 04:30 - 06:00 1.50 CLEAN P DECOMP Monitor well -flowing back at - 130 bbl/hr static. -Flow for 1st 15 min = 36 bbls -Flow for 2nd 15 min = 34 bbls -Flow for 3rd 15 min = 28 bbls 06:00 - 08:30 2.50 CLEAN P DECOMP Shut in well with Annular Preventer. -Initial SIDPP = 20 psi, bleed off 25 bbls. -Second SIDPP = 20 psi, SICP = 40 psi, with no further build up after 1 hour. -Bleed off 25 bbls. -Third SIDPP = 20 psi, SICP = 40 psi, with no further increase after 30 minutes. 08:30 - 10:30 2.00 CLEAN P DECOMP CBU C«~ 250 gpm, 450 psi. Took returns through the choke. Max circulating psi = 550 psi. -MW in = 9.0 ppg, MW out = 8.9+ to 9.1+ ppg. -Circulate 1.25 times until returns were 9.1 ppg. 10:30 - 13:00 2.50 CLEAN P DECOMP Open bag and circulate surface to surface, increasing mud weight from 9.0 ppg to 9.2 ppg ~ 315 gpm, 850 psi. -Circulate until clean 9.2 ppg returns. -Shut down pumps and monitor well for 15 minutes. -Fluid level dro in f~ 1 bbl / 15 minutes. 13:00 - 14:30 1.50 CLEAN P DECOMP Trip out of hole from 8487' to 5810' 14:30 - 15:00 0.50 CLEAN P DECOMP Set RTTS ~ 5805'. -Attempt to test from above -Injecting at 1.7 bbl/min ~ 500 p; Printed: 6/30/2008 9:31:20 AM BP EXPLORATION Page 4 of 10 Operations Summary Report Legal Well Name: 02-01A Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABORS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours I Task Code NPT Phase I Description of Operations 6/2/2008 14:30 - 15:00 0.50 CLEAN P DECOMP and 5.4 bbl/min ~ 1000 psi. -Test from below to 3000 psi -good. 15:00 - 18:00 3.00 CLEAN P DECOMP POH from 5810'. Lay down RTTS. -Clean and clear floor. 18:00 - 19:00 1.00 CLEAN P DECOMP Pull wear ring. PU 4" test joint and test plug. -Test Annular to 250 psi low / 3500 si hi h - ood. -Pull test plug and install wear ring. 19:00 - 22:30 3.50 CLEAN P DECOMP Pick up 5.5" Tubing Stub Dress-off Mill BHA (with OD and ID mill). 22:30 - 00:00 1.50 CLEAN P DECOMP RIH from 222' to 8444'. -Well losin an avera a of -4 b h with 9.2 mud in hole. 6/3/2008 00:00 - 01:00 1.00 CLEAN P DECOMP RIH and to to of stum ~ 8505'. -Up Wt = 170k, Dn Wt = 140k, Rot = 160k. -80 RPM with 5-7k ft-Ibs. -330 gpm ~ 1100 psi. -Rotate down, swallow stump, and dress top of stump with 5-10k WOB. 01:00 - 02:30 1.50 CLEAN P DECOMP Circulate hi-vis sweep around C~? 330 gpm, 1100 psi. -Sweep was clean. 02:30 - 04:00 1.50 CLEAN P DECOMP Cut and slip drilling line. 04:00 - 05:30 1.50 CLEAN P DECOMP Service Top Drive. 05:30 - 08:00 2.50 CLEAN P DECOMP PJSM. POOH with 5-1/2" dress off assembly to 222'. 08:00 - 09:00 1.00 CLEAN P DECOMP PJSM. Lay down dress off BHA. 09:00 - 10:30 1.50 CLEAN N WAIT DECOMP Waiting on orders from town. Perform rig maintenance. 10:30 - 11:30 1.00 CLEAN P DECOMP Break and lay down washpipe assembly. Clear and clean floor. 11:30 - 13:00 1.50 BOPSU P DECOMP Chan a to rams from 3-1/2" x 6" variables to 4-1/2" x 7" variables. 13:00 - 13:30 0.50 BOPSU P DECOMP PJSM. Test 4-1/2" x 7" variable rams with 7" test joint to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. 13:30 - 14:30 1.00 CASE P DECOMP Rig up casing handling equipment. 14:30 - 22:30 8.00 CASE P DECOMP PJSM. Run 7", 29#, L-80, BTC-M scab liner. Make up hanger. Up weight 180k, down 160k. Average torque 7600 ft/Ibs. 22:30 - 23:00 0.50 CASE P DECOMP Rig down casing handling equipment. Make up XO to 4" drill pipe. 23:00 - 00:00 1.00 CASE P DECOMP Run liner on 4" drill pipe to 6506'. 6/4/2008 00:00 - 01:30 1.50 CASE P DECOMP PJSM. Run 7" liner on 4" drill pipe to 8505'. RIH slowly to swallow 5 1/2" tubin t .Saw both sets of shear pins shear at 4' in and 12' in. Bottom out and space out 2' from fully inserted. 01:30 - 02:30 1.00 REMCM P DECOMP Circulate warm fluid around well to get return brine temp to 80+ degrees. Spot trucks for cement job. 02:30 - 03:30 1.00 REMCM P DECOMP RU cementers. Run lines and spot mix water truck. 03:30 - 04:00 0.50 REMCM P DECOMP PJSM with BP, NAD, CH2M Hill, Baker prior to pumping cement. 04:00 - 06:00 2.00 REMCM P DECOMP Pump 25 bbls water. Test lines to 4500 psi. Mix & pump 70 bbls(335 sx) Class G slur .Follow with 62 bbls (300 sx) Class slurry with aggregate. Follow with 73 bbls (350 sx) Class G cement. All cement weighs 15.8 ppg. Kick out plug with 5 bbls water and displace with rig pumps and bump plug with correct displacement (-224 bbls). Lost 20 bbls during cement job. CIP at 05:50 hrs. Pressure up and set hanger at 3100 psi. Increase Printed: 6/30/2008 9:31:20 AM • • BP EXPLORATION Page 5 of 10 Operations Summary Report Legal Well Name: 02-01A Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To ', Hours Task ', Code NPT ~I Phase Description of Operations 6/4/2008 04:00 - 06:00 2.00 REMCM P DECOMP ressure to 3460 si shear and set acker. Rotate off hanger. Un-sting and pump off cement from liner top. Confirm packer set. 06:00 - 07:00 1.00 REMCM P DECOMP Circulate cement out. Divert cement to cuttings tank through IA. Cement returns of 40 bbls to surface. Shut down. Flush lines and blow down. Lay down cement head and DP singles. 07:00 - 10:00 3.00 CASE P DECOMP POOH and lay down running tool. 10:00 - 12:00 2.00 BOPSU P DECOMP Flush BOP stack. Change out upper rams to 3-1/2" x 6" variables. 12:00 - 13:00 1.00 BOPSU P DECOMP PJSM. Pick up 4" test joint. Install test plug. Test upper rams to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Charlie Henley. Pull test plug. Run in wear ring. 13:00 - 15:30 2.50 CLEAN P DECOMP PJSM. Rig up handling equipment. Pick cement drill out assembl up to rig floor. Make up BHA to 297'. Change out handling equipment. 15:30 - 16:30 1.00 CLEAN P DECOMP RIH to 2448'. 16:30 - 17:30 1.00 DHB P DECOMP PU RTTS. Set at 8' below wellhead. Up and down weight 70k. Test from above to 1000 psi for 30 minutes - OK, 17:30 - 19:00 1.50 WHSUR P DECOMP PJSM. ND BOP stack and set back. ND tubing spool and remove from cellar. Top part of 9-5/8" packoff came with tubing spool. 19:00 - 00:00 5.00 WHSUR P DECOMP Attempt to pull the rest of the 9-5/8" packoff. Dogs pulled out of running tool and damaged the top of the packoff assembly. Weld frame onto packoff. Use Porta-Power and jack out ackoff. Only one ring came out. Re eat 3 times and recover , all of ackoff. Clean and re for new ackoff. 6/5/2008 00:00 - 03:30 3.50 WHSUR P DECOMP PJSM. Install new 9-5/8" packoff. NU new tubing spool. Test packoff and void to 5000 psi for 30 minutes - OK. 03:30 - 05:30 2.00 BOPSU P DECOMP PJSM. NU BOP stack. 05:30 - 06:30 1.00 BOPSU P DECOMP PJSM. Test break on BOP stack to 250 psi low, 3500 psi high as per AOGCC. Test witnessed by WSL Mitch Skinner and Toolpusher Bruce Simonson. 06:30 - 07:00 0.50 DHB P DECOMP Pull RTTS. 07:00 - 09:00 2.00 CLEAN P DECOMP RIH to 8051'. 09:00 - 10:00 1.00 CLEAN P DECOMP PJSM. Test casin to 3500 si for 30 minutes - OK. 10:00 - 16:30 6.50 CLEAN P DECOMP RIH and to cement strin er at 8247'. Up weight 165k, down 130k, RT 145k. Pump at 484 gpm with 3270 psi. Rotate at 60 rpm with 5k torque. WOB 10-15k. Drill cement, wiper plug and landin collar to 8375'. Continue to drill up float equipment to ported XO at 8476'. 16:30 - 17:30 1.00 CLEAN P DECOMP Pump hi-vis sweep and displace well to seawater at 485 gpm with 3200 psi. 17:30 - 21:00 3.50 CLEAN P DECOMP PJSM. POOH to 297'. Change out handling equipment. 21:00 - 22:00 1.00 CLEAN P DECOMP PJSM. POOH with cement clean out assembly. Break bit and lay down with jars, boot baskets and scraper. Clear and clean floor. 22:00 - 00:00 2.00 CLEAN P DECOMP Bring mill assembly up beaver slide. Bring up 2-7/8" running tools. MU BHA to 133'. 6/6/2008 00:00 - 01:00 1.00 CLEAN P DECOMP PJSM. PU cleanout BHA to 422'. 01:00 - 03:00 2.00 CLEAN P DECOMP RIH to 8457'. Hook up blower hose. 03:00 - 06:30 3.50 CLEAN P DECOMP RIH and tag at 8475'. Establish circulation at 350 gpm with 2600 psi. Rotate at 65 rpm with 6k torque. WOB 3-10k. Up Printed: 6/30/2008 9:31:20 AM • • BP EXPLORATION Page 6 of 10 Operations Summary Report Legal Well Name: 02-01A Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABOBS 2ES Rig Number: Date From - To Hours I Task j' Code ! NPT ~ Phase Description of Operations 6/6/2008 03:00 - 06:30 3.50 CLEAN P DECOMP weight 183k, down 137k, RT 155k. Cleanout to ball seat at 8491'. Continue to mill on cement into 5-1/2" tubing sub at 8505' to 8506'. Broke through at 8506' and continued to 8517'. Taa up with no rotary and confirm top of CBP in 5 1/2" tubing 06:30 - 09:00 2.50 CLEAN P DECOMP Pump hi-vis sweep S-S at 430 gpm with 3725 psi. Rotate and reciprocate. Alluminum and cement over shaker. Pump second sweep. Pump dry job. Seawater in and out 8.5 ppg. 09:00 - 12:00 3.00 CLEAN P DECOMP PJSM. POOH to 422'. Change out handling equipment. 12:00 - 14:00 2.00 CLEAN P DECOMP PJSM. POOH with mill assembly. LD drill collars, boot baskets and mill. Clear and clean floor. 14:00 - 17:30 3.50 CLEAN P DECOMP PJSM. PU RCJB BHA to 413'. 17:30 - 19:30 2.00 CLEAN P DECOMP RIH to 8449'. 19:30 - 00:00 4.50 CLEAN P DECOMP Attempt to circulate at 100 gpm, packing off. Shut down and bleed off. Bring pumps on slowly while spudding pipe, rotating and reciprocating. Pipe still plugging off. Trouble shoot and check all surface equipment - OK. Line up and reverse circulate at 80 gpm with 475 psi. Good returns. Shut down, make up top drive, attempt to circulate through RCJB. Still packing off. Line back up and reverse circulate 2 BU at 80 aom 6/7/2008 00:00 - 00:30 0.50 CLEAN P DECOMP 00:30 - 01:30 1.00 CLEAN P DECOMP 01:30 - 03:00 1.50 CLEAN P DECOMP 03:00 - 05:30 2.50 CLEAN P DECOMP 05:30 - 08:00 2.50 CLEAN P DECOMP 08:00 - 15:30 7.50 BOPSU P DECOMP 15:30 - 17:30 2.00 FISH P DECOMP 17:30 - 19:00 1.50 FISH P DECOMP 19:00 - 19:30 0.50 FISH P DECOMP 19:30 - 22:00 2.50 FISH P DECOMP 22:00 - 00:00 2.00 FISH P DECOMP 6/8/2008 00:00 - 03:30 3.50 FISH P DECOMP PJSM. Continue to reverse circulate till clean. Line up and circulate through RCJB. Pump at 127 gpm with 2900 psi. Wash down and tag up at 8515'. Pull up, shut down pumps and dry tag with no rotary. PU, kick in pumps and work down to 8516'. Pull up to circulate. Pump sweep around corner. Drop dart and open circ sub. Pump suface to surface at 475 gpm with 2970 psi. Recovered substantial amount of metal with magnets. . PJSM. POOH to 413'. PJSM. Break, clean and lay down RCJB. Small amount of metal recovered. Clean and clear floor. PJSM. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi high minimum as per AOGCC. Test upper 3-1/2" x 6" variables and lower 2-7/8" x 5" variables with 4" and 4-1/2" test joints. Test Hydril with 4" test joint. Test witness waived by Chuck Scheve with AOGCC. Test witnessed by WSL Dick Maskell and Toolpusher Cleve Coyne. PJSM. PU Mill Catcher assembly, to 423'. RIH to 2573'. Break circulation at 200 gpm at 600 psi, clear pipe. Continue to trip to 3079'. Circulate sweep surface to surface at 400 gpm with 2000 psi. RIH to 8458'. Wash to 8516'. Mill to 8518' at 100 gpm with 300 psi. Increase to 200 gpm with 800 psi. PJSM. Continue to mill ahead to 8520' at 200 gpm with 750 psi. WOB 5-10k. Rotate at 50 rpm with 5-8k torque. At 8520' packoff and lose returns. Spike to 3000 psi. Shut down. Up weight 185k, down 140k, RT 160k. Pull up and break free at 195k. Pump and push down to deployment sleeve at 8604'. Shut down pump and rotary. Latch plug and pull up to 225k. Jar and pull several times and break free. Run back down and latch up again. Pull to 250k. Pull several times and again break Printed: 6/30/2008 9:31:20 AM • • BP EXPLORATION Page 7 of 10 Operations Summary Report Legal Well Name: 0 2-01A Common W ell Name: 0 2-01A Spud Date: 4/6/1980 Event Nam e: WORKO VER Start : 5/30/2008 End: Contractor Name: NABORS ALASK A DRI LLING I Rig Release: 6/15/2008 Rig Name: NABORS 2ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/8/2008 00:00 - 03:30 3.50 FISH P DECOMP free. Losing minimal fluid at 6-8 bph. Pull up out of 5-1/2" tubing stub, hang up several times pulling up and as pulling through top of stub. Still only losing minimal fluid. Run back in to 8604', stack 40k down, pipe slipped down 4' to 8608'. Latch up on plug. Pull up out of 5-1/2" tubing stub and again hang up at top of tubing stub. Drop dart and prepare to POOH. 03:30 - 04:30 1.00 FISH P DECOMP MU top drive. Bring pumps up to 1800 psi and open circ sub. Pump sweep surface to surface at 500 gpm with 2400 psi. Some small pieces of composite and rubber to surface. 04:30 - 07:00 2.50 FISH P DECOMP PJSM. POOH to 423'. 07:00 - 10:00 3.00 FISH P DECOMP PJSM. Break and lay down Mill Catcher BHA. No fish. Clear and clean floor. Recover a gallon or so of metal, rubber and composite. 10:00 - 11:00 1.00 FISH P DECOMP Make u short catch overshot with ra le BHA to 439'. 11:00 - 12:30 1.50 FISH P DECOMP RIH to 5577'. 12:30 - 13:00 0.50 FISH P DECOMP Break circulation at 200 gpm to verify clear pipe. 13:00 - 14:00 1.00 FISH P DECOMP RIH to 8380. MU top drive. 14:00 - 16:00 2.00 FISH P DECOMP PJSM. Slip and cut 103' of drilling line. Service and tube the rig. 16:00 - 19:00 3.00 FISH P DECOMP Work overshot down and attempt to engage CBP at 8610'. Set 20k down. Pull up with 5 overpull. Attempt to set down several times. Spud down on top of plug. Pump and rotate down. Pull up with only 5k overpull. Minimal losses of 5-8 bph. No lost returns. Up weight 180k, down 140k, RT 160k. Mud weight in and out 8.5 ppg. 19:00 - 22:00 3.00 FISH P DECOMP POOH to 439'. 22:00 - 00:00 2.00 FISH P DECOMP PJSM. POOH with grapple BHA. No fish. Break and lay down grapple. Clear and clean floor. 6/9/2008 00:00 - 01:30 1.50 CLEAN P DECOMP PJSM. Make up 4.4" mill and 2-7/8" motor BHA to 450'. Break circulation to verify motor working and fill pipe. 01:30 - 03:30 2.00 CLEAN P DECOMP RIH to 3300', fill pipe and again at 8500'. 03:30 - 08:30 5.00 CLEAN P DECOMP Circulate at 76 gpm with 300 psi. Work down to 8610' and tag u . Up weight 190k, down weight 140k. Increase pump rate to 120 gpm with 600 psi. Attempt to mill ahead with no success. 08:30 - 09:00 0.50 CLEAN P DECOMP Drop dart and open circ sub with 1200 psi. Pump dry job. 09:00 - 11:00 2.00 CLEAN P DECOMP PJSM. POOH to 449'. 11:00 - 12:00 1.00 CLEAN P DECOMP PJSM. Break moter and lay down. Clear and clean floor. 12:00 - 13:30 1.50 CLEAN P DECOMP PJSM. PU 4-11/16" concave mill assembly to 452'. 13:30 - 16:00 2.50 CLEAN P DECOMP RIH to 8580'. Fill and verify clear pipe at 3068'. 16:00 - 22:00 6.00 CLEAN P DECOMP Make up top drive. Wash to 8610'. Pump at 400 gpm with 2400 psi. Rotate at 70 rpm with 6-7k torque. WOB 2-12k. Up weight 185k, weight 140k, RT 155k. Mill ahead to 8624 and tag up hard. Continue to mill to 8629'. but own and pull up. ttempt to o bac own, a u a 11' and could not go down futher. Pump dry job. Mud weight in and out 8.5 ppg. 22:00 - 00:00 2.00 CLEAN P DECOMP PJSM. POOH strapping pipe to 5310'. 6/10/2008 00:00 - 02:30 2.50 CLEAN P DECOMP PJSM. POOH strapping pipe to 452'. Drill pipe strap within .90' of tally strap. 02:30 - 04:00 1.50 CLEAN P DECOMP PJSM. POOH with milling BHA. Correct number of 3-1/2" collars and BHA components. Lay down jar and 4 PAC drill ollars. Collar number 5 twisted off on the in end. Left a bit sub, boot basket X2, XO and mill in the hole with a total length of 16.77'. 04:00 - 06:00 2.00 FISH P DECOMP Pull PAC collars from the shed and load out new collars for Printed: 6/30/2008 9:31:20 AM • • BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Common W Event Nam Contractor Rig Name: Date Name: 0 ell Name: 0 e: Name: From - To 2-01 A 2-01A WORKO NABOB NABOB Hours VER S ALASK S 2ES Task DRI Code LING NPT Start I Rig Rig Phase Spud Date: 4/6/1980 : 5/30/2008 End: Release: 6/15/2008 Number: Description of Operations 6/10/2008 04:00 - 06:00 2.00 FISH P DECOMP fishing run. Clear and clean floor. Prepare to run in hole for fish. 06:00 - 08:00 2.00 FISH P DECOMP PJSM. Pick up Overshot Granule BHA to 437'. 08:00 - 10:00 2.00 FISH P DECOMP RIH to 8596'. Make up top drive. 10:00 - 11:00 1.00 FISH P DECOMP Break circulation at 125 gpm with 220 psi. Slack off to 8596'. Tag with 5k down. Pull and repeat with 20k down twice. Rotate string 180 degrees, slack off to 25k. Able to work down to 8608'. Ta and en a e fish. Pressure increase to 900 psi, indicating latch up. Pull up with 5k drag to 8596'. Drop dart. Mud weight 8.5 ppg in and out. 11:00 - 15:00 4.00 FISH P DECOMP POOH to 437'. 15:00 - 18:30 3.50 FISH P DECOMP PJSM. Lay down BHA, no fish. No signs of entry into grapple on overshot. Clear and clean floor. 18:30 - 21:30 3.00 EVAL P DECOMP PJSM. PU STL tubing and XO's. Bring up handling equipment. MU 4-1/2" tubin with mule shoe to 152'. 21:30 - 00:00 2.50 EVAL P DECOMP RIH with 4-1/2" tubing on drill pipe to 8469'. PU a single and pup for spaceout. 6/11/2008 00:00 - 01:00 1.00 EVAL P DECOMP PJSM. RIH with last stand tag up at 8596'. Set down 5k, no go. Pull up rotate pipe. Slack off and tag up again at 8596', no go. Attempt again without success. Space out pipe an_d set down in sli s 'ust off bottom. 01:00 - 03:00 2.00 EVAL P DECOMP PJSM. PU slickline tools. Rig up BOPE. Make up TIW and lubricator. Test to 500 psi - OK. 03:00 - 04:30 1.50 EVAL P DECOMP Make a drift run with 1.90" OD centralizer and 1.0" OD bullnose. Taa up at 8621' WLM. Work up and down several times. Not able to go any deeper. POOH. Centralizer shows small amount of side wear call ered out at 1.5". 04:30 - 07:00 2.50 EVAL P DECOMP PU 2" OD lead impression. Stab in. Test lubricator to 500 psi - OK. RIH to 8621' SLM. POOH. Rig down lubricator and BOPE. 07:00 - 08:00 1.00 EVAL P DECOMP PU 15' pup joint. Attempt to work through to 8610'. Rotate 1/4 turn and set down to 5k, 10k, 15k, 20k and 25k. No go. Make up top drive. Circulate at 300 gpm with 1450 psi. Slack off and make 1/4 turns several times. Work throw h to 8610'. 08:00 - 10:00 2.00 EVAL P DECOMP Reverse circulate at 250 gpm with 1200 psi. Increase to 300 gpm with 1800 psi. Pump sweep surface to surface. No increase in cuttings to surface. 10:00 - 13:00 3.00 EVAL P DECOMP PJSM. Rig up lubricator and BOP. Make up 2" LIB and stab in lubricator. Test to 500 psi - 13:00 - 15:00 2.00 EVAL P DECOMP RIH and to u at 8620 WLM. POOH. 15:00 - 18:00 3.00 EVAL P DECOMP PJSM. MU bailer and stab in lubricator. Test to 500 psi - OK. RIH to 8620' and tag up. Work through to 8647' WLM. Tool dragging. POOH. Nothing in bailer. 18:00 - 21:00 3.00 EVAL P DECOMP PJSM. MU 2" tapered LIB. Stab in lubricator and test to 500 psi - OK. RIH and get past obstruction at 8610'. Continue in hole to 9500'. POOH. Rig down slickline. 21:00 - 23:30 2.50 EVAL P DECOMP PJSM. Displace well to clean seawater. Pump at 500 gpm with 3500 psi. Chase with 110 bbls filtered and clarified KCL water to prep well for fiber optic, real time camera operations. HES 0 oa mg and rigging up wireline unit. 23:30 - 0.00 EVAL P DECOMP PJSM. Pick wireline tools up beaver slide. 6/12/2008 00:00 - 03:00 3.00 EVAL P DECOMP PJSM. Rig up HES wireline unit and fiber optic tools. Make up BOPE and lubricator. Stab camera in lubricator. MU and test lubricator to 500 psi - OK. Printed: 6/30/2008 9:31:20 AM • • BP EXPLORATION Operations Summary Report Legal Well Name: 02-01A Page 9 of 10 ~ Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABOBS 2ES Rig Number: Date !From - To ', Hours Task j Code ~ NPT I Phase Description of Operations 6/12/2008 03:00 - 08:30 5.50 EVAL ~ P ~ ~ DECOMP RIH with real time fiber o tic downhole camera. Stand back 08:30 - 10:00 I 1.50 I EVAL I P 10:00 - 14:00 4.00 EVAL P 14:00 - 16:00 2.00 EVAL P 16:00 - 17:00 1.00 EVAL P 17:00 - 20:00 3.00 EVAL P 20:00 - 21:00 1.00 EVAL P 21:00 - 22:30 1.50 EVAL P 22:30 - 00:00 I 1.50 I EVAL I P 6/13/2008 00:00 - 01:30 1.50 EVAL P 01:30 - 03:30 2.00 EVAL P 03:30 - 04:00 0.50 EVAL P 04:00 - 09:30 5.50 EVAL P 09:30 - 10:30 1.00 EVAL P 10:30 - 11:00 0.50 EVAL P 11:00 - 15:30 4.50 EVAL P 15:30 - 17:30 2.00 EVAL P 17:30 - 23:30 I 6.001 BOPSURP 23:30 - 00:00 I 0.501 BUNCO 6/14/2008 ~ 00:00 - 01:00 ~ 1.00 BOPE and lubricator in derrick. DECOMP Make up top drive. Slack off and attempt to work down past 8596'. Set down 5k. Pull up and make 1/4 turn. Slack off again, set down 5k - no go. Attempt several times without success. Circulate at 225 gpm with 920 psi. Continue attempts to work down - no go. Pump dry job. Brine weight in and out 8.5 ppg. DECOMP POOH to 152'. DECOMP PJSM. Lay down BHA. Re-cut mule shoe. Clear and clean floor. DECOMP PSJM. PU tubing BHA to 152'. DECOMP RIH to 8596', tag up. Work 1/4 turns in pipe, set down 5k and work through on 6th try. Run in to 8605'. DECOMP Circulate filtered KCL water around tailpipe at 125 gpm with 330 psi. DECOMP PJSM. Rig up wireline BOPE and lubricator. Test to 500 psi - OK. DECOMP RIH with fiber optic, real time, downhole camera to 8610' on to of the 3-1/2" liner. Spotted fish off to side of hole (boot basket). DECOMP PJSM. RIH with camera to top of 3-1/2" liner. Spot bottom boot basket then the XO to mill behind 3-1/2" liner. Camera landin out on ed a of liner. Check mule shoe and POOH. DECOMP PJSM. Rig down wireline BOPE and lubricator. Lay tools down beaver slide. Clear and clean floor. DECOMP Pull u above fish. Pump at 235 gpm with 950 psi. Slack off and attem t to ass b fish. Set down 5k. Pull up. Make 1/4 turn each attempt. Pass through on 6th attempt. Double check by passing through 3 times with no weig t. urn pipe 1/4 turn and attempt to pass, take 2-3k down and drop off past fish. Pull up. Brina oioe back to mark and pass through with no weight. Pump dry job. Brine weight in and out 8.5 ppg. DECOMP PJSM. POOH laving down drill pipe to 4075'. DECOMP PJSM. Cut and slip 89' of drilling line. DECOMP Service top drive. DECOMP POOH laying down drill pipe to 152'. DECOMP Lay down mule shoe assembly and re-dress mule shoe. RIH with drill collars from derrick. POH and lay down collars. DECOMP PJSM. Remove wear ring, run in test plug. Make up test joint with TIW and dart valve. Test BOPE to 250 psi low, 3500 psi high and Hydril to 250 psi low, 2500 psi minimum high as per AOGCC. Tested 3-1/2" x 6" and 2-7/8" x 5-1/2" rams with 4-1/2" test joint. Tested Hydril with 4-1/2" test joint. Test witnessed by Bob Noble with AOGCC. Rig down. Clear and clean floor. RUNCMP PJSM. Pick up tools and equipment for completion run. Prepare to rig up to run 4-1/2", 12.6#, 13Cr-80, Vam Top completion tubing. RUNCMP PJSM. Rig up to run 4-1/2", 12.6#, 13Cr-80, Vam Top completion. 01:00 - 17:30 16.50 BUNCO RUNCMP PJSM. Run 4-1/2", 12.6#, 13Cr-80, Vam Top completion tubing. Tag top of 3-1/2" liner at 8610'. Up weight 135k, down 110k. and space out. Run in and set at 8605'. Average MU torque 4440. Printed: 6/30(2008 9:31:20 AM • • BP EXPLORATION Page 10 of 10 Operations Summary Report Legal Well Name: 02-01A Common Well Name: 02-01A Spud Date: 4/6/1980 Event Name: WORKOVER Start: 5/30/2008 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 6/15/2008 Rig Name: NABOBS 2ES Rig Number: Date: From - To Hours Task Code NPT Phase Description of Operations 6/14/2008 17:30 - 19:00 1.50 BUNCO RUNCMP Reverse circulate corrosion inhibitor at 126 gpm with 340 psi in 90 bbls clean seawater. Chase with 170 bbls clean seawater with no inhibitor. Hold PJSM with slickline. Rig up slickline. 19:00 - 00:00 5.00 DHEOP P RUNCMP RIH with slickline and pull RHC-M plug from X nipple profile at 8445'. POOH and PU 2" drift. RIH to 9000' with no problems. Slight bobble passing through 3-1/2" liner top. PU into 4-1/2" tubing. Run back through 3-1/2" liner top, again with slight bobble. No problems. 6/15/2008 00:00 - 06:00 6.00 DHEOP P RUNCMP PJSM. POOH with drift. Rig up and RIH with XX plug and set in rofile at 8445'. Shear off and POOH. Rig up and run in hole with check set tool to verify plug on seat. POOH and check tool. Set verified. 06:00 - 08:00 2.00 BUNCO RUNCMP PJSM. Pressure up tubing to 3500 psi for 10 minutes and set packer. Continue to hold for a total of 30 minutes and test tubin - OK. Bleed off to 1500 si ressure u annulus to 3500 si and test for 30 minutes - OK. Bleed off annulus and tubing. Pressure up on annulus and shear DCK valve at 2600 psi. Line up and pump both ways to verify good shear. 08:00 - 08:30 0.50 BOPSU P RUNCMP PJSM. Run in TWC. Test from above and below to 1000 psi for 10 minutes - OK. 08:30 - 09:30 1.00 BOPSU P RUNCMP Rig down slickline tools and set down. Rig down unit. 09:30 - 11:00 1.50 BOPSU P RUNCMP PJSM. Nipple down BOP stack. 11:00 - 14:00 3.00 WHSUR P RUNCMP NU tree and adapter flange. 14:00 - 16:30 2.50 WHSUR P RUNCMP PJSM. Test void to 5000 psi for 30 minutes - OK. Bleed off and fill tree with diesel. Function all valves. Test tree to 5000 psi for 5 minutes - OK. 16:30 - 18:00 1.50 WHSUR P RUNCMP PJSM. Rig up DSM lubricator. Test to 500 psi - OK. Run in and remove TWC. Rig down lubricator. Rig up LRS to freeze protect. 18:00 - 20:30 2.50 WHSUR P RUNCMP PJSM. Fill lines and pressure test to 4000 psi - OK. Pump 80 degree diesel at 3 bpm with 450 psi. Pump 150 bbls diesel. Shut down, open lines and allow to u-tube. 20:30 - 21:30 1.00 WHSUR P RUNCMP PJSM. Run in BPV. Test from below to 1000 psi - OK. Rig down LRS. 21:30 - 00:00 2.50 WHSUR P RUNCMP Remove secondary annulus valves. Secure tree. Move out-buildings, camp and shop. Rig down sub and pits. Spot matting boards for ramp. Notify Drill Site Operator. Release rig at 00.00 hours. Printetl: 6/30/2008 9:31:20 ,4Ni Nabors 2ES, OZ-OlB Regg, James B (DOA) Page 1 of 1 ~ i~~ 7- From: Jones, Jeffery B (DOA) Sent: Monday, June 02, 2008 9:54 PM \ ~~ ~~3~cJ~ To: Crisp, John H (DOA); Noble, Robert C (DOA); Regg, James B (DOA); Scheve, Charles M (DOA) Subject: FW: Nabors 2ES, 02-01 B FYI From: LeBlanc, Joseph G [mailto:Joseph.LeBlanc@bp.com] Sent: Monday, June 02, 2008 8:50 AM To: Jones, Jeffery B (DOA) Subject: Nabors 2ES, 02-01B ~~t~NNE®JUN 4 9 20D8 Mr. Jones, Nabors 2ES is performing a workover on well 02-01 B. The well had 9.4 ppg brine and losing 7 BPH. The brine weight was reduced to 9.0 ppg and the well started flowing back. The assumption is the well is breathing back the fluid loss. The Annular was closed at 06:00 am to perform a exhale test. The SIDP stabilized at 20 psi, SICP stabilized at 40 psi. The plan is to monitor pressure build up after multiple 25 bbl bleed offs. If we determine it is breathing we will allow the well to flow back, if we determine it is under balance we will weight the system back up before opening the well. Thanks, Joey 6/3/2008 DS 02-O1B RWO • • Maunder, Thomas E (DOA) Page 1 of 2 From: Rose, John G (FAIRWEATHER} [John.G.Rose@bp.com] Sent: Friday, May 23, 2008 9:56 PM To: NSU, ADW Drlg Rig 2es Cc: Hobbs, Greg S (ANC); Maunder, Thomas E (DOA) Subject: RE: DS 02-01 B (197-140) RWO Bill, As you begin work on the 02-01 B well and if it is determined that we do have a PC leak which will require ascab- liner, please give me a call directly and I will work directly with Tom Maunder in regards to the Sundry approval which will be required, i.e., disregard the instructions on the previous a-mail about calling the North Slope inspector. If you have any questions or concerns, please advise. - jr From: Rose, John G (FAIRWEATHER) Sent: Friday, May 23, 2008 6:54 PM To: NSU, ADW Drlg Rig 2es Cc: Hobbs, Greg S (ANC) Subject: FW: DS 02-01B (197-140) RWO Bill, ~,N~~ JUL ~ ~ ~~~~ Please note the a-mail exchange between Tom Maunder and this office in regards to the possible need for a Sundry permit if a scab liner is required on the 02-01 B RWO. As you can see, the agency (AOGCC) is aware of our situation and if we need to move toward a Sundry approval to run the scab liner over the weekend, I suggest you start with the agency Inspector on the Slope and we'll go from there. Thanks for your help. - jr From: Rose, John G (FAIRWEATHER) Sent: Wed 5/21/2008 10:05 AM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC) Subject: RE: DS 02-01B (197-140) RWO Tom, In the event we move onto the planned 02-01 B RWO over the long Memorial Day weekend and determine that a scab-liner is required due to a leak in the 9-5/8" production casing (a planned RTTS run will be made to confirm the integrity of the PC), our plan will be to run a 7" scab-liner from the top of the current pre-rig 5-1/2" tubing cut at 8520' MD back up the well to 3000' (310' below the existing surface casing shoe at 2690' MD). That being the case, how would you like us to proceed in regards to the Sundry approval that will be required should that casing repair work be required? Thanks for your help. - jr From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, May 12, 2008 4:23 PM To: Rose, John G (FAIRWEATHER) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC) Subject: RE: DS 02-01B (197-140) RWO John, Thanks for the heads up. You are correct that the scab would require a sundry. Keep me advised as planned. 7/22/2008 DS 02-O1B RWO • • Tom Maunder, PE AOGCC Page 2 of 2 From: Rase, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Monday, May 12, 2008 4:19 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC) Subject: DS 02-016 RWO Tom, Nabors 2ES is scheduled to move onto the DS 02-01 B RWO later this week (the rig is currently working on the DS 02-28A RWO) for what was to be basic tubing swap (cut and pull the current 5-1/2" completion and re-run a 4- 1/2" chrome stacker-packer completion), however, recent pre-rig work has identified the possibility of a production casing leak. The purpose of this memo is to advise you that the requirements of this RWO may expand to include the need fora "fix" for a PC leak and that Sundry approval may required. As of now, we will move onto the well and further analyze the condition of the production casing with an RTTS. If the casing is good we will move forward with the tubing swap as planned. If a leak is found, the possibility of a scab-liner fix may be required which would require Sundry approval. That being the case, I will keep you advised as to our progress on the well in regards to the need for a casing repair and please do not hesitate to call if you have any questions or concerns. Thanks - jr John G. Xose BPX - Drilling Consuhanx Office 907/569-5271 Cell 907/748-5223 FAX 907/564-4040 Horae 907/293-8813 7/22/2008 • ~v ~~7T~~++~t~yg~ -~~~A ®~a i~®ld-7idi6~~lY®1d ~® s7e'S®AS Greg Hobbs Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 ~~~~~ SUN ~' ~ 200 Anchorage, AK 99519-6612 SARAH PALIIV, GOVERAIOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 02-OlB Sundry Number: 308-188 ~ (' Dear Mr. Hobbs: • 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. Sincerely, ~. ~.~„ ~: y,. '; Daniel T. Seamount, Jr. Chair ~~ .. DATED this ' day of May, 2008 Encl. STATE OF ALASKA ALA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extension ^ After Casing ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ®Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 197-140 3. Address: ^ Service ^ Stratigraphic 6. API Number. P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20442-01-00 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 02-01 B Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028308 65' Prudhoe Bay Field J Prudhoe Bay Pool 12- PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 11772 8858 11706 8857 11220' None Casin Len th Size MD TVD Burst Colla se Structural ondu r 75' 20" 75' 75' 1530 520 Surface 2690' 13-318" 2690' 2689' 4930 2670 Intermediate 932T 9-5/8" 9327 TOW 8790' 6870 4760 Production Liner 3168' 3-1/2" 8604' - 11772' 8195' - 8858' 10160 10530 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9520' - 11700' 8915' - 8857 5-1 /2", 17# L-80 8645' Packers and SSSV Type: 9-5/8" x 5-1/2" Baker'SAB' packer Packers and SSSV MD (ft): 8595' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 27, 2008 ®Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose,. 564-5271 Printed Name Gre -ijlob Title Engineering Team Leader Prepared By Name/Number: Signature t/ Phone 564-4191 Date ~ .,. ,, v Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity .BOP Test. ^ Mechanical Integrity Test ^ Location Clearance ~w c ~ / Other: ?J~ V °~ ~~~-~E~~ ~t~G~V ~~ ~ NAY 200 ~~ ~~ Subsequent Form Required: ~--~~, ~laSka all & G9S C©nS. Commission Anchorage '~/' ~ APPROVED BY ' ~r7 A roved B . COMMISSIONER THE COMMISSION Date Form 10-403 R~{rise~d 120 6 Submit Iri Duplicate ~~, ~a~ ~ ~ ~QO~ p~~~ 0 LATE • by GP~~¢erP~r~h~P.Bay To: Tom Maunder - AOGCC From: John Rose - BPXA GPB Rotary Drilling Subject: 02-01B Application for Sundry Approval for RWO Date: May 24, 2008 Approval is requested for the proposed work over of the 02-018 well which is an Ivishak producer that is currently shut-in in preparation for the RWO. Originally, the primary objective of the planned RWO was to eliminate T X IA communication with a new stacker-packer completion, however, a PC leak at -5700' was discovered during the pre-rig wells work and now ascab-liner will also be installed within the scope of this planned RWO. 02-016 was drilled and completed as a Z1 CT sidetrack in Sept 1997. In May 2000, 340' of Z1A additional perts were shot in heel with minimal affect on production. In February 2001, a CIBP was set at 11,220' to shut-off suspected gas production from the toe. The CIBP resulted in a significant decrease in gas production. 02-01 B failed a TIFL in September 2004 and on 09/28/04 the well was secured with a 3-1/2" liner plug (PGSL tool) set at 8590'. A 2004 caliper indicated the tubing was in poor condition with several areas with greater than 60% body penetration and during the pre-rig work a PC leak was detected at -5700' MD. Therefore, the primary focus for this RWO will be to fix the PC leak by the installation of -5500' of 7" scab liner and eliminate the T x IA leak by cutting and pulling a portion of the existing 5-%" tubing which will then be replaced with 4- ", 12.6#, 13Cr80, VAM TOP tubing and 9-s/e" x 4-%Z" Baker stacker-packer completion. Other work to be done on this RWO will include change out the 9-5/8" pack-off and converting the wellhead from a Gray Gen 2 system to a Gray New Standard system which will dictate an S-riser modification. Estimated Pre-Rig Start: DONE Estimated Work-Over Date: 05/27/08 MASP: 2370 psi Drilling Engineer: John Rose - 564-5271 Production Engineer: Alice Kaminski - 564-5676 Geologist: Priya Maraj - 564-4181 CC: Well file Terrie Hubble / Sondra Stewman ATTACH: Current Schematic Proposed Schematic • Pa e2of2 g 02-01 B Operations Summary Current Status• 1. Well shut-in waiting on RWO. 2. MIT-OA to 2000 psi on 5/11/08. 3. CMITXIA to 3500 psi failed on 5/10/08. 4. PPPOT - IC passed to 3500 psi on 5/3/08. 5. PPPOT - T passed to 5000 psi on 5/3/08. Pre-Rip Operations: 1. Set composite bridge plug (HES Fastdrill) at 8534' MD. DONE. 2. Cut tubing at 8520' MD. DONE. 3. Displace well to 9.8 ppg brine and freeze protect well to -2200' MD on both sides of the tubing. DONE. Ria Operations: 1. MIRU Nabors 2ES. ,,,~,-. ~~ ~ ~ S'~` ~C~ -~~~ ~°~ ~~ ..,~5^ 1.. i~~-- 2. Pull 5-1/2" tubing from pre-rig cut at 8520' MD. ~ 3. Confirm PC leak location with RTTS. ~~`~ 4. Make external cut on 5-1/2" tubing at -8548' MD to recover 5-1/2" Fastdrill set pre-rig at 8534' MD. 5. Set 5-1/2" RBP at -8600' MD. 6. Run and cement 7" scab-liner (-8548' to 3000' MD). 7. Set storm packer and change-out wellhead equipment as planned (change Gray Gen 2 equipment to Gray New Standard equipment and change-out 9-5/8" pack-off). 8. Clean-out 7" scab-liner and test to 3500 psi. _ 9. Recover the 5-1/2" RBP from -8600' MD. 10. Run new 4-1/2" chrome stacker-packer completion and test production packer at -8476' MD. 11. ND BOP/NU Tree and secure well. 12. RDMO well 02-01 B RWO Application for Sundry TREE = 6" MCEV OY WELLHEAD = GRAY ACTUATOR= AXELSON KB. ELEV = 65.0' BF. ELEV = N/A KOP = 5450' Max Angle = 99 @ 10049' Datum MD = 9428' Datum TVD = 8800' SS S~1f NOTES: WELL ANGLE> 70° @ 9511' & > 90° Q 9610'. TOOLS HANgNG UP ~ +/.8590' (3-1/2" LNR TOP) NOTED ON 02/22/01. 11/29/04 NOTE: WELL 02-01 WAS ABANDONED, RIG SKIDDED OVER AND W ELL 02- ~ 01 A SPUDDED. ~ oz-a~e 2245' 5-1/2" OTIS ROM SSSV N~, ~ = 4.562" 13-3/8" CSG, 72#, L-80, ~ = 12.347" ~-~ 26g0' Minimum ID = 2.917" @ 8604' 3-1/2" BKR LNR DEPLOYMENT SLV TOP OF 3-1/2" LNR 9.3#, ID = 2.932" 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID = 4.892" 9-518" CSG, 47#, L-80, ~ = 8.681" PERFORATION SUMMARY REF LOG: BRCS ON 4/20/1980 ANGLE AT TOP PERF: 73 @ 9520' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz GATE 1-11/16" & 2-1/8" 4 9520 - 9719 O 09/20/97 2-1/2" 4 9740 - 9880 O 05/17/00 1-11/16" & 2-1/8" 4 9880 - 10040 O 09/20/97 1-11/16" & 2-1/8" 4 10281 - 10371 O 09/20/97 1-11/16" 8 2-1/8" 4 10419 - 10610 O 09/20/97 2-1/2" 4 10610 - 10810 O 05/17/00 1-11/16" & 2-1/8" 4 10810 - 11090 O 09/20/97 1-11/16" 8 2-1/8" 4 11130 - 11170 O 09/20/97 1-11/16"&2-1/8" 4 11280-11350 C 02/22/01 1-.11/16" 8 2-1/8" 4 11390 - 11509 C 02/22/01 1-11/16" & 2-1/8" 4 11620 - 11700 C 02/22/01 ~ 3-112" LNR 9.3#, L-80, .0087 bpf, ~ = 2.932" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06/76 ORIGINAL COMPLETION 09120/97 CTD SIDETRACK (02-01 B 01/27/02 CWKAK CORRECTIONS 08/18/03 CMO/TLP PERF ANGLE CORRECTION 09/28/04 KSB/TLP SET PGSL TOOL IN DULY SLV 11/29/04 DFR/TLP SAFETY NOTE PRUDHOE BAY UNIT WELL: 02-01 B PERMfT No: 1971400 API No: 50-029-20442-01 SEC 36, T11 N, R14E, 651' FNL & 1694' FWL BP t3cploration (Alaska) 5-1/2" OTIS XA SL~IG SLV, ID = 4.562" 5-1/2" BAKER PBR ASSY 9-5/8" X 5-112" BKR SAB PKR, 0 = 4.75" 4-1/4" BKR DEPLOYMENT SLV, ~ = 2.917" j 8644' ~ 5-1/2" OTIS XN NIP (BEHNVD LNR), ID = 4.455" $645' 5-1/2" BAKER BREAKOUT SUB (BEHYVD LNR) $646' 5-1/2" TUBNVG TAL (BEHgVD LNR) 8620' ELMD TT LOGG® 04/29/80 11220' ~-{ 3-1/2" HES M CBP (02/22/01) ~~ 11706' PBTD 3-1l2" LC, ~ =1.611" r TREE = CIW 4-i/18" 5K WELLHEAD Gra New STD ACTUATOR= --•__, _,,.....-.--_ K B . ELEV B ELEV = KOP = 5450' Max A n le = 99 10049' Datum MD = 9428' Datum TV D = 8800' SS 02-01 B RWO (Propose) 4-1/2" X-Nipple 2200` MD '2#, L-80, ID = 12.347" 2690' 9-5/8" x 7" ZXP Liner Top - 3000` MD 7", 29#, L80, BTC-M Scab-Liner - w/9-5/8" x 5-1/2" Unique OS (15`) 4-1/2", 12.6#, 13 CR, VamTop Completion 4-1/2" X-Nipple 8512' MD 4-1/2" Mule Shoe Into 5-1/2" Stub 8563'MD- Minimum ID = 2.917" @ 8604' 3-1 /2" BKR LNR DEPLOYMENT SLV Top of 5-1/2" Tubing Stub -'8548` MD $G' $0' S-1/2" BAKER PBR ASSY $- 5~ 9-5/8" X 5-1 /2" BKR SAB PKR, ID = 4.75" 8604' I-I4-1/4" BKR DEPLOYMBJT SLV, ID = 2.917" TOP OF 3-1/2" LNR, 9.3#, ID = 2.932" I-i $60$' 5-1/2" OTIS XN NIP (BEHIND LNR), ID = 4.455" $~' S-1/2" BAKER SHEAROUT SUB (BEHIND LNR) 5-1/2" TBG-PC,17#, L-80, .0232 bpf, ID=4.892" ~-{ $645' 9-5/8" CSG, 47#, L-80, ID = 8.681"I-I 9327' PERFORATION SUMMARY REF LOG: BRCS ON 4/20/1980 ANGLE AT TOP PERF: 73 @ 9520' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1-11/16" & 2-1/8" 4 9520 - 9719 O 09/20/97 2-1/2" 4 9740 - 9880 O 05/17/00 1-11/16" & 2-1/8" 4 9880 - 10040 O 09/20/97 1-11/16" & 2-1/8" 4 10281 - 10371 O 09/20/97 1-11/16" & 2-1/8" 4 10419 - 10610 O 09/20/97 2-1/2" 4 10610 - 10810 O 05/17/00 1-11/16" & 2-1/8" 4 10810 - 11090 O 09/20/97 1-11/16" & 2-1/8" 4 11130 - 11170 O 09/20/97 1-11/16" 8 2-1/8" 4 11280 - 11350 C 02/22/01 1-11 / 16" 8 2-1 /8" 4 11390 - 11509 C 02/22/01 1-11/16" & 2-1/8" 4 11620 - 11700 C 02/22/01 11220' I-i3-1/2" HES M CAP PBTD 3-1/2" LC, ID= 1.611" 13-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.932" I DATE REV BY COMMENTS DATE REV BY COMMENTS 11/06176 ORIGINAL COMPLETION 05/15/08 JGR Planned 02-01B RWO 09/20/97 CTD SIDETRACK (02-01 B) 01/27/02 CWKAK CORRECTIONS 08/18/03 CMO/TLP PERF ANGLE CORRECTION 09/28/04 KSB/11P SET PGSL TOOL IN DEPLY SLV 11/29/04 DFR/TLP SAFETY NOTE PRUDHOE BAY UNIT WELL: 02-01 B PERMIT No:1971400 API No: 50-029-20442-01 SEC 36, T11N, R14E, 651' FNL & 1694' FWL BP Exploration (Alaska) NOTES: WELL ANGLE > 70° @ 9511' & > @ 9610'. TOOLS HANGING UP @ +/.8590' (3-1 /2" LNR TOP) NOTED ON 02/22/01. 11/29/04 NOTE: WELL 02-01 WAS ABANDON. WELL 2-01 B HAS A SEPARATE SURFACE LOCATION FROM 02-01. GLM's - 4-1/2" x 1" KBG-2 #2 3504' MD /3500' ND w/DCK2 SV #1 6041' MD /6000' ND w/DGLM 4-1/2" X-Nipple 844' MD 7" x 4-1/2" Baker S-3 Packer 8476` MD u15-1/2" TUB~IG TAIL (BEHNVD LNR) 8620' ELMD TT LOGGED 04/29/80 05/20/08 ~C~~III~U~iI1~I1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Wall _Inh it NO.4712 Company: State of Alaska G.~1~it"~v~~~ ~~~~ `" ~ ~~~ Alaska Oil & Gas Cons Comm G'C7~0~ Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ n.. MPB-04A 12021150 MEM PROD PROFILE ~ 04/17/08 1~ 1 MPG-13 12021151 MEM INJECTION PROFILE C. 04/18/08 1 1 Z-26A 11978454 MEM GLS ap(p-v 04/23/08 1 1 Z-29 11978453 MEM GLS - 04/22/08 1 1 Y-36 12005204 MEM GLS [,/ 02/12/08 1 1 4-14A/S-37 12031471 _ PRODUCTION PROFILE W/FSI 04/12/08 1 1 Y-07A 11966254 SCMT 3! 05/02/08 1 1 02-01 B 11966257 LDL ~ /p 05/10/08 1 1 X-16A 11975771 USIT L- C 05!14/08 1 1 07-26 12061688 USIT - 05/16/08 1 1 05-34 11966251 USIT - 04/13/08 1 1 05-23A 118966257 USIT 1 05/13/08 1 1 S-33 11962596 USIT 04/15/08 1 1 V-223 12061688 CH EDIT PDC GR (USIT ~ - i 03/23/08 1 V-220 40016600 OH MWD/LWD EDIT ab _ 03/03/08 2 1 4-14A/S-37 40016545 OH MWD/LWD EDIT ~p~.-U ( ! 02/18/08 2 1 05-226 11628800 MCNL 10/22/07 1 1 05-13B 12021140 MCNL ~ 01/31!08 1 1 Z-10 12066520 RST (~~- 04/10/08 1 1 D-10 11975766 RST 04/25/08 1 1 . ...-.,.,~ .... ~.,.., .. ~~.v.a~ n~..c~r ~ o. anarvnv~a falvv nC ~ Vn1V 11VU VIVO IiVYT GAGn I V: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: ;e /fl(h~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • ~\ DS 02-OlB RWO Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA} Sent: Monday, May 12, 2008 4:23 PM To: 'Rose, John G (FAIRWEATHER)' Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC) Subject: RE: DS 02-01 B (197-140) RWO John, Thanks for the heads up. You are correct that the scab would require a sundry. Keep me advised as planned. Tom Maunder, PE AOGCC From: Rose, John G (FAIRWEATHER) [mailto:John.G.Rose@bp.com] Sent: Monday, May 12, 2008 4:19 PM To: Maunder, Thomas E (DOA) Cc: Hobbs, Greg S (ANC); Smith, Phil G (ASRC) Subject: DS 02-O1B RWO MAY 2 2DD8 Tom, Nabors 2ES is scheduled to move onto the DS 02-016 RWO later this week (the rig is currently working on the DS 02-28A RWO) for what was to be basic tubing swap (cut and pull the current 5-1/2" completion and re-run a 4- 112" chrome stacker-packer completion), however, recent pre-rig work has identified the possibility of a production casing leak. The purpose of this memo is to advise you that the requirements of this RWO may expand to include the need fora "fix" for a PC teak and that Sundry approval may required. As of now, we will move onto the well and further analyze the condition of the production casing with an RTTS. If the casing is goad we will move forward with the tubing swap as planned. If a leak is found, the possibility of a scab-liner fix may be required which would require Sundry approval. That being the case, I will keep you advised as to our progress on the well in regards to the need for a casing repair and please do not hesitate to call if you have any questions or concerns. Thanks - jr John G. Rose BPX -Drilling Consultant Office 907/564-5271 Celt 9Q71T4$-5223 F,~X 907/564-4f140 Home 90?I243-&513 5/12!2008 SCP Notice: 02-01B (PTD #1971400) ') Subject: SCP Notice: 02-01B (PTD #1971400) From: "NSU, ADW Well Integrity Engineer" <NSUADWWeIlIntegrityEngineer@BP.com> Date: Thu, 16 Sep 2004 16:08:46 -0800 To:'''GPB~'FSl TL" <GPBFSITL@BP.com>, "GPB, FsfDS2 Operator", " <Q}!BFS1DS2Operator@BP.com>, "GPB, Wells Opt Eng" <GPBWeUsO¡:)tEn'g@BP.com>,"GPB, FS'l' DS Ops Lead" <GPBFS 1 DSOpsLead@BP.com>, :"GPB, Ops Mgr" <GPBOpsMgr@BP.coin>, "N~U, ADW WL& Completion Supervisor't<NSlJADWWL&CompletionSupervisor@BP;com>, , "N~U;ADW Well Operations Supervisor" <NSUADWWellOperationsSupervisor@BP.com>, , , "AþGCC~ Jim Regg (E-mailt <jim~regg@admin.state.ak.us>,,:'AOGCC'-:Winton Aubert (E-mail)" <~inton~aubert@admin.state.ak.us>, "Dean, ,James A" <deanja@BP.coin>, "Rossberg, R Stev~"', <Rr°ssþeRS@BP,.com>', ' """"'" ,', ,,','" " C~: "NSU, ADW . Well, Integrity, Engineer" <N8U ADWWellIritegrityEngineer@BP .com>; "Reeves, DQuald,Ftf <ReevesDf@BP.com> ',', '""",, ' " " '"," , ' ) All, Well 02-01B (PTD #1971400) has sustained pressure greater than 2000 psi on the lA, and has been reclassified as a Problem Well. TIO pressures on 9/15/04 are 2150/2150/760. Current plans are to: 1) Conduct an MITIA to determine the leak size 2) Evaluate for an LDL and patch Attached is a wellbore schematic. Please call if you have any questions. «02-01B.pdf» Joe Anders, P.E. Well Integrity Coordinator, BP Exploration, (Alaska) Inc. Work: 1-907-659-5102 Mobile: 943-1154 Pager: 659-5100, xl154 Email: ~.§'y.?::J2.~!.~..~..~..~..~..~.!:..~9..!.:~.~..!:..Y..~!.:?:9..~.~~..~..~.~f¥..!.:?.P....:....s.:?!~ Content-Description: 02-01B.pdf Content-Type: application/octet-stream Content-Encoding: base64 SCANNED NOV 0 2 2004 1 of 1 9/22/2004 12:23 PM lREE= 6" MCEVOY VVEL LH I;A 0 = GRAY "AcTÜIi;i6R';'"'' , 'Äxï~LS6N' KEf' ELEV';;'"''-''' .. 65.0' ---_._--_._~~~~~ . BF. ELEV = f\.VA KOP = 5450' rJlax Angle = 99 @ 10049' Datúm rvÐ = 9428' t~túm'i\ïb;"" '""àaÖóï'sS" 1 13-3/8"CSG, 72#,L-80, 10=12.347" 1-1 2690' Minimum ID = 2.917" @ 8604' 3-1/2" BKR LNR DEPLOYMENT SLV ITOPOF 3-1/2" LNR, 9.3#,10 = 2.932" 1-1 8608' 15-112"TBG-PC,17#, L-80,.0232bpf,10=4.892" 1-1 8645' 19-5/8" CSG, 47#, L-80, 10= 8.681"1-1 9327 ~ ÆRFORA TlON SlJIJ1MARY REF LOG: BHCS ON 4/20/1980 ANGLE AT TOP PERF: 73 @ 9520' Note: Refer to Production OB for historical perf data SIZE SPF INfER\! AL OpnlSqz 0A.1E 1-11/16" & 2-1/8" 4 9520 - 9719 0 09/20/97 2-1/2" 4 9740-9880 0 05/17/00 1-11/16" & 2-1/8" 4 9880 - 10040 0 09/20/97 1-11/16" & 2-1/8" 4 10281 - 10371 0 09/20/97 1-11/16" &2-1/8" 4 10419 -10610 0 09/20/97 2-1/2" 4 10610-10810 0 05/17/00 1-11/16"&2-1/8" 4 10810-11090 0 09/20/97 1-11/16"&2-1/8" 4 11130-11170 0 09/20/97 1-11/16"&2-1/8" 4 11280-11350 C 02122/01 1-11/16" &2-1/8" 4 11390 -11509 C 02122/01 1-11/16"&2-1/8" 4 11620-11700 C 02122/01 OATE 11/06/76 09/20/97 01/27/02 08/18/03 CO Mv18'JTS ORIGINAL COM PLETION CTO SIDETRACK (02-01B) CI-VKAK CORRECTIONS CMOITLP ÆRF ANGLE CORRECTION OA. 1E RBI BY REV BY ) 02-01 B SAFETY NOTES: WELL ANGLE> 70° @ 9511' & > 90° @ 9610'. TOOLS HANGING UP @ +/- 8590' (3- 1/2" LNR TOP) NOTED ON 02/22/01. 8 2245' 1-f5-1/2" OTIS RQMSSSV NP, 10= 4.562" 1 ~ ~ I I 8500' H5-1/2" OTlSXA SLIDING SLV, 10 =4.562" 1 I J 1 8580' H5-1/2" BAKffi A3RASSY 1 :8: ~ 8595' 1-19-5/8" X 5-1/2" BKRSAB A<R, 10= 4.75" 1 r J r 8604' H4-1/4" BKR OEPLOYIVENf SLV, 10 = 2.917" 1 I 8644' 1-15-1/2" OTIS XN NIP (BEHINO LNR), 10= 4.455" I 8645' 1--15-1/2" BAKffi SHEAROUT SUB (BEHINO LNR) 1 8646' 1-f5-1/2" TUBING TAIL (BEHINO LNR) 1 8620' I., ELMO TT LOGGID 04/29/80 1 I .. I 1-13-1/2" HES M CIBP (02/22/01) 1 1 11706' H PBTO 3-1/2" LC, 10 = 1.611" 1 13-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.932" 1--1 11772' I COMIVENTS ffiUDHOE SA Y um WELL: 02-01B PERMIT No: 1971400 AA No: 50-029-20442-01 SEC36, T11N, R14E, 651' FNL & 1694' FWL BP Explo ration (Alas ka) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Pedorate _ Pull tubing _ Alter casing _ Repair well _ Other _X CIBP 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__X RKB 65 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Servia__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 648' FNL, 3584' FEL, Sec. 36, T11 N, R14E, UM (asp's 688439, 5950571) 02-01B At top of productive interval 9. Permit number / approval number 4369' FNL, 3573' FEL, Sec.25, T11 N, R14E, UM (asp's 688410, 5952132) 197-140 At effective depth 10. APl number 50-029-20442-01 At total depth 11. Field / Pool 2374' FNL, 3774' FEL, Sec. 25, T11N, R14E, UM (asp's 688158, 5954121) Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11772 feet Plugs (measured) PBTD tagged (2/21/2001) @ 11702' MD. true vertical 8858 feet Effective depth: measured 11702 feet Junk (measured) true vertical 8857 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 75' 20" 350 Sx AS ~ 75' 75' Surface 2625' 13-3/8" 2700 Sx Fondu 2690' 2689' Production 9262' 9-5/8" 42oo Sx C~ass G 9327' 8790' Liner 3168' 3-1/2" 35 bbls LARC 11772' 8858' Perforation depth: measured 9520' - 9719'; 9740' - 10040'; 10281' - 10371" 10419' - 11090'; 11130' - 11170'; (Isolated below CIBP are 11280' - 11350'; 11390'- 11509'; 11620'- 11700'). true vertical 8915' - 8924'; 8922' - 8899'; 8887' - 8890'; 8889' - 8881'; 8881' - 8880'; (Isolated below CIBP are 8878' - 8871'; 8866' - 8855'; 8855' - 8857'). Tubing (size, grade, and measured depth) 5.1/2", 17#, L-80 POT @ 8645' MD.RECEIVED Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8595' MD. MAR 1 & 001 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Alaska Oil & Gas Cons. Commission Treatment description including volumes used and final pressure Anchorage 14. Representative Daily Average Production or Injection Data OiFBbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 861 27528 0 - 1898 Subsequent to operation 890 1765 21 - 275 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations .__X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed "'~%~-~-- )~ ~ Title DS 2 Surveillance Engineer Date March 9, 2001 Brian Cadson Prepared by Paul Rauf 584-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE'~ 02-01B DESCRIPTION OF WORK COMPLETED SET CAST IRON BRIDGE PLUG FOR GSO 'Date ! 2/21/2001: 2/22/2001: Event Summary A Cast Iron Bridge Plug was set f/GSO as follows: MIRU CTU. PT'd BOPE. Liquid packed wellbore w/1% KCL Water & 60/40 MEOH water (down bs). RIH w/mere GR/CCL logging tools but was unable to penetrate the 3-1/2" liner. POOH w/logging tools. No data was collected. RIH &tagged PBTD @ 11702' MD. POOH. RIH & set a 3-1/2" CIBP in the horizontal liner @ 11220' to isolate the following perforation intervals: 11280'- 11350' MD (Zone lB) 11390'- 11509' MD (Zone lB) 11620'- 11700' MD (Zone lB) POOH w/CT - hung up @ the top of the liner but eventually worked free. FP'd well. RD. Placed well BOL on 2/23/2001 & obtained representative well test data. Page I THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE P L E MATE IA L U N D W E R TH IS M ARK ER C:LORBMFILM.DOC STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 648' FNL, 3584' FEL, Sec. 36, TllN, R14E, UM At top of productive interval 4369' FNL, 3573' FEL, Sec.25, T11 N, R14E, UM At effective depth At total depth 2374' FNL, 3774' FEL, Sec. 25, T11N, R14E, UM 5. Type of Well: Development __X Exploratory__ Stratigraphic__ Service__ (asp's 688439, 5950571) (asp's 688410, 5952132) (asp's 688158, 5954121) 6. Datum elevation (DF or KB feet) RKB 65 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 02-01 B 9. Permit number / approval number 197-140 10. APl number 50-029-20442-01 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 1 1772 feet Plugs (measured) 8858 feet PBTD tagged (5/16/2000) @ 1 1706' MD. Effective depth: measured 11706 feet Junk (measured) true vertical 8857 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 75' 20" 350 Sx AS II 75' 75' Surface 2625' 13-3/8" 2700 Sx Fondu 2690' 2689' Production 9262' 9-5/8" 12oo sx Class G 9327' 8790' Liner 3168' 3-1/2" 35 bbls LARC 1 1772' 8858' ORIGINAL Perforation depth: 11390'- 11509'; 11620'- 11700'. true vertical 8915' - 8924'; 8922' - 8899'; 8887' - 8890'; 8889' - 8881'; 8881' - 8880'; 8878' - 8871'; 8866' - 8855'; 8855' - 8857'. Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80 PCT @ 8645' MD. Packers & SSSV (type & measured depth) measured 9520'-9719'; 9740'-10040'; 10281'-10371'; 10419'-11090'; 11130'-11170'; 11280'-11350'; 9-5/8" X 5-1/2" BAKER SAB PACKER @ 8595' MD. 5-1/2" OTIS RQM SSSV @ 2245' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 1120 Subsequent to operation 1144 Representative Daily Average Production orlnjection Data Gas-Mcr Water-Bbl 31663 0 30953 0 Casing Pressure Tubing Pre~ure - 1751 1471 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations ._X 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 PAl Wellwork Design & Optimization Supervisor Erin Oba Date ~.///~.~~ 4.~ Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 02-01 B DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 5/16/2000 - 5/17/2000: MIRU CTU & work platform. PT'd equip to 3000 psi. Killed well w/300 bbls of 1% KCL Water. RIH w/perforation guns & GR/CCL logging tools f/tie-in. Logged f/9600' to PBTD @ 11706' MD. Layed FIo Pro in liner. Shot 340' of perforations as follows: Add perforated: 9740' - 9880' MD (Zone lA) Reference Log: BCNL 3/15/1999. 10610' - 10810' MD (Zone 1 A) Used 2-1/2" carriers & all shots @ 4 SPF, overbalanced press, & random orientation. POOH w/guns. ASF. FP'd well. RD CTU & work platform. Placed well BOL & obtained representative welltest data. Page 1 AOGCC Geological Materials Inventory PERMIT 97-140 ARCO Log 8166 9175 MCNL MWD SRVY NGP-MD NGP -TVD {L,ktf~407 Completion Date Are dry ditch samples required? Was the well cored? yes Are tests required? yes Well is in compliance Comments Data Sent Recieved ~RRY GR 10/29/97 10/30/97 ~LUM MCNL 4/20/99 5/13/99 ~0-11700 4/20/99 5/13/99 C ~I~RRY 9300.-H772. 10/7/97 10/15/97 ~g00-11772 11/5/97 11/5/97 ~8-8801 11/5/97 11/5/97 ~/'~ t/¢? ? Daily well ops yes ~o And received? ~---~---~---~---~---~---~no Analysis _description recieved? ~ ms .... :... no -,~no Received? Initial Box Thursday, September 23, 1999 Page I of l 4/20/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12517 Companl Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy CD-R Well Job # Log Description Date BL Sepia Disk D.S. 1-11 ~C~l~q 99164 CNTG 990406 1 1 1 D.S. 2-01B 4~.c[t~1'~ 99156 MCNL 990315 1 1 1 D.S. 5-39 ~ ~t~/(p 99162 RST 990326 1 1 1 D.S. 11-05A .1~1~"~ 99161 MCNL 990327 1 1 1 D.S. 11-27 ~. c~t~ 99165 CNTG 990406 1 1 1 D.S. 11-37 ~t. ~1~[ 99167 MCNL 990413 1 1 1 ~..,~ ~ ..... ~' ~ ~-. t~ ~ ~.:- I.i.q'( 1 [5 '199~-) SIGNE DATE: ~ch0raBe Please sign ~nd return one copy of this tmnsmi~l to $herrie ~t lbo ~bove ~ddress or f~x to (907) 562-6521. lhonk you STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well Oil X Gas Suspended Abandoned Service__ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 97-140 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360., . 50-029-20442-01 9 Unit or Lease Name 651' S & 1694' E of NW cr, Sec 36, T11 N, R14E, UM. ~ ~lliB~l~i ~ PRUDHOE BAY UNIT At Top Producing interval ~~ 10 Well Number 910' N & 1707' E of SW or, Sec 25, T11N, R14E, UM. ~,-Z~'.'. 2-01B At Total Depth ~Z' ' 11 Field and Pool 2359' FNL, 3805' FEL, Sec 25, T11N, R14E, UM. ! -/~'"' ~-~" ' ' .......... PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. 64' RKB ADL 28308 PRUDHOE BAY OIL POOL 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp., or Aband. 15 Water Depth, if offshore 16 No. of Completions 8/26/97 9/15/97 9/21/97 N/A 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 20 Depth where SSSV set 21 Thickness of Permafrost 11772' MD / 8869' TVD 11706' MD / 8869' TVD YES X NO 2245' feet MD 1900' feet (approx) 22 Type Electric or Other Logs Run MWD, GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH CASING SIZE WT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMT PULLED 20" 94# H-40 Surf 75' 32" 350 Sx Arcticset II 13-3/8" 72# L-80 Surf 2690' 17.5" 2700 Sx Fondu 9-5/8" 47# L-80 Surf 9630' 12.25" 1200 Sx Class G ' :' '-"~.' ~ ,2:'~;.,~ ~ .. 3-1/2" 8.8# L-80 8604' 11772' 4.55" 35 Bbls LARC ., " 24 Pedorations open to Production (.D+TVD of Top and Bottomand 111 I 1/4'L ., TUBING RECORD interval, size and number) SiZE DEPTH SET MD 9520- 9719' MD; 8927- 8935' TVD; at 4 spf. :5-1/2" Tbg 8654' 8595' 9880 - 10040' MD; 8926 - 8911' TVD; at 4 spf. I 10281 - 10371' MD; 8899- 8902' TVD; at 4 spf. 10419 - 10610' MD; 8899 - 8895' TVD; at 4 spf. 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10810 - 11090' MD; 8890 - 8892' TVD; at 4 spf. DEPTH INTERVAL MD ~,MT & KIND MATERIAL USED 11130 - 11170' MD; 8892 - 8892' TVD; at 4 spf. 11280 - 11350' MD; 8890 - 8883' TVD; at 4 spf. 11390 - 11509' MD; 8877 - 8865' TVD; at 4 spf. 11620 - 11700' MD; 8866 - 8868' TVD; at 4 spf. 27 PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) 9/24/97 Flowing Date of Test Hours Tested PRODUCTION FOR OIL - BBL GAS - MCF WATER - BBL CHOKE SIZE GOR 10/1/97 4.4 TEST PERIOD __ 642 Flow Tubing Press Casing Pressure CALCULATED OIL - BBL GAS - MCF WATER - BBL OIL GRAVITY - APl (corr) 529 24 HOUR RATE _X 4247 2725 0 28 CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas, or water. Submit core chips. * This 10-407 submitted as directed per the 10-401 form approved 7/31/97 (issued Permit # 97-140). Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, and fluids recovered and gravity, MEAS DEPTH TRUE VERT DEPTH GOR, and time of each phase. Top Sadlerochit 8871' 8434' N/A 31 LIST OF ATTACHMENTS Summary of 2-01B Coil Tubing Sidetrack Drilling Operations. 32 1 hereby cedify that the foregoing is true and correct to the best of my knowledge Signed ~'~ .,~-~ '~.- ~ Engineering Supervisor 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. 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 cementing and the location of the cementing tool. Item 27: Method of operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection Gas Injection, Shut-In, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 2-01 B DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS 8/22/97: WOC. RIH w/milling BHA. in hole & POOH w/BHA. Milled pilot hole through cement plug from 8660' to 9200' MD. Circulated biozan pill 8/23/97: RIH w/milling BHA. Unable to pass obstruction tagged at 8703' MD. POOH w/BHA. Tagged & milled on obstruction at 8703' MD. Worked through & pushed junk to 8977' MD. RIH w/milling BHA. 8/24/97: Continued milling junk & pilot hole to 9295' MD. reamed 4.55" pilot hole from 9171' to 9285' MD. Circulated hole clean. POOH w/BHA. RIH w/milling BHA & 8/25/97: Reamed pilot hole to 9295' MD. POOH w/BHA. w/BHA. RIH w/window milling BHA. RIH w/milling BHA. Milled pilot hole to 9327' MD. POOH 8/26/97: Started milling a window through the 9-5/8" casing from 9326' MD. POOH w/BHA. Lost mill & end of broken motor output shaft in hole. Milled window to 9335', where progress ceased. RIH w/grapple. Tagged fish at 9331' MD. 8/27/97: POOH w/fishing BHA; no recovery. RIH w/grapple. Latched fish at 9326' MD. RIH w/milling BHA. Noted pinhole in CT. POOH & blew down reel. POOH w/mill & output shaft. 8/28/97: MIRU ROC spooling unit. Stab pipe. MU & PT drilling connector. RIH w/window milling BHA. Tagged window at 9332' MD. Finished window to 9333' MD, then drilled formation to 9341' MD. Backreamed window & POOH. 8/29/97: PT BOPE. RIH w/window reamer & reamed window smooth. 8/30/97: POOH w/BHA. RD CTU for injector equipment replacement. 8/31/97: Standby for injector changeout. MIRU CTU. 9/1/97: RIH w/drilling BHA & displaced well to FIo Pro. Unable to orient BHA. Oriented through window & drilled 4.55" build hole to 9390' MD. POOH w/BHA. RIH w/drilling BHA. 9/2/97: Drilled build to 9410' MD. POOH w/BHA. RIH w/drilling BHA. Drilled build to 9530' MD, w/periodic shod trips. 9/3/97: Jetted OOH w/BHA. RIH w/drilling BHA. Completed build, then drilled horizontal hole from 9624' to 9675' MD. 9/4/97: POOH w/BHA. RIH w/drilling BHA. Continued drilling to 9875' MD. Drilled to 9721' MD w/periodic short trips, then circulated in new FIo Pro. 9/5/97: Drilled to 9900' MD. POOH w/BHA. PT BOPE. 9948' MD. POOH w/BHA. RIH w/drilling BHA. Repaired rig equipment. RIH w/drilling BHA. Drilled to 9/6/97: Drilled to 10137' MD w/periodic wiper trips. 2-01 B DESCRIPTION OF WORK COMPLETED COIL TUBING SIDETRACK DRILLING OPERATIONS 9/7/97: Backreamed shale section from 10137' to 10050' MD. to window. RIH & continued drilling to 10490' MD w/periodic wiper trips 9/8/97: Circulated OOH w/BHA. RIH w/drilling BHA. Drilled to 10735' MD. 9/9/97: CBU & drilled to 11010' MD w/periodic wiper trips to window. 9/10/97: Drilled to 11053' MD. Wiper tripped to 10700' MD & circulated in new FIo Pro. RIH & drilled to 11285' MD. Tripped to window. Noted weld leak in coil at surface. POOH displacing reel w/Seawater. 9/11/97: Blew down reel w/N2. RD ROC. PT BOPE. Standby; repaired coil. 9/12/97: Standby. ROC on location. Stab coil & RU on hole. RIH w/drilling BHA. Continued drilling to 11455' MD. 9/13/97: Drilled to 11460' MD. Circulated in new FIo Pro, then drilled to 11638' MD. POOH w/BHA. RIH w/drilling BHA. 9/14/97: Reamed shales at 10250'; couldn't pass 10255' MD. POOH w/BHA. hole at 10250 - 10256', then RIH & drilled to 11705' MD. RIH w/drilling BHA & reamed through tight 9/15/97: Drilled to 11730' MD while circulating in new 25 bbl FIo Pro pills. Drilled to TD at 11772' MD. bbls new FIo Pro. Made MAD pass to 11500', then RIH & pumped 60 bbls Hi Vis sweep. POOH. chain & bolts while POOH. Standby for ROC repairs. Circulated in 35 Broke injector 9/16/97: Repaired rig & replaced chain. POOH circulating well to 1% KCI Water from 1800'. RIH w/3-1/2" liner assembly. 9/17~97: Ran liner to bottom to set at 8604' - 11772' MD. Released liner. PU & circulated, then pumped 35 bbls of 15.8 ppg Latex Acid Resistive Cement. Displaced cement w/1% KCI Water, bumped plug, unstung from liner, & displaced coil water w/mud. CBU & POOH w/liner running tools. RIH w/2.8" milling assembly. Couldn't start pump w/BHAat linertop. POOH. RIH w/milling BHA. 9/18/97: Washed through liner to 11706' MD. Circulated liner clean, then POOH pumping new FIo Pro. Swapped to water in top 1000' of hole. PT BOPE. PT linerto 2000 psi for 15 minutes. Lost 100 psi. RIH w/perf guns. 9/19/97 - 9/20/97: Displaced well to water & shot initial perforation intervals at: 9520 - 9719' MD 9880 - 10040' MD 10281 - 10371' MD 10419- 10610' MD 10810- 11090' MD 11130- 11170' MD 11280- 11350' MD 11390- 11509' MD 11620 - 11700' MD Used 2-1/8" & 1-11/16" carriers & shot all perfs at 4 spf. POOH w/perf guns. 9/21/97: Blow down coilw/N2. RD. ND BOPE. NU & PT tree. MOL. Placed the well on initial production & obtained a valid well test. SPERRY-SUN DRILLING SERVICES 1 ARCO ALASKA INC. PBU / 2- 0lB 500292044201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF sURVEY: 091597 M~D SURVEY GOB NI~BER: AK-M~-70248 KELLY BUSHING ELEV. = 65.00 ~T. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9300.00 8788.60 8723.60 9320.00 8805.14 8740.14 9333.00 8815.78 8750.78 9363.40 8839.29 8774.29 9387.47 8856.47 8791.47 34 30 33 55 36 7 42 32 46 24 N 12.00 E .00 1797.31N 60.82E N 12.62 E 3.38 1808.30N 63.22E N 13.00 E 17.01 1815.57N 64.87E N 16.00 E 22.02 1834.20N 69.73E N 22.00 E 23.73 1850.12N 75.24E 1784.40 1795.12 1802.22 1820.33 1835.68 9420.34 8878.66 8813.66 9450.07 8896.78 8831.78 9479.14 8911.45 8846.45 9511.17 8924.02 8859.02 9538.94 8931~81 8866.81 48 46 56 4 63 16 70 29 76 54 N 31.67 E 22.86 1871.70N 86.20E N 32.69 E 24.70 1891.63N 98.75E N 34.27 E 25.24 1912.53N 112.59E N 34.62 E 22.53 1936.81N 129.25E N 36.03 E 23.59 1958.54N 144.65E 1856.19 1874.89 1894.46 1917.12 1937.37 9572.84 8937.86 8872.86 9604.32 8940.35 8875.35 9630.52 8940.21 8875.21 9659.12 8939.20 8874.20 9688.87 8937.47 8872.47 82 31 88 25 92 11 91 50 94 49 N 39.90 E 20.05 1984.81N 165.17E N 43.94 E 22.66 2008.15N 186.12E N 46.22 E 16.85 2026.64N 204.67E N 44.29 E 6.86 2046.76N 224.97E N 43.59 E 10.32 2068.14N 245.58E 1961.68 1983.01 1999.75 2017.95 2037.37 9721.82 8934.62 8869.62 9751.74 8932.67 8867.67 9784.12 8931.37 8866.37 9811.97 8930.33 8865.33 9840.27 8929.28 8864.28 95 92 92 92 92 5 22 11 6 6 N 42.18 E 4.34 2092.19N 267.91E N 40.25 E 11.17 2114.65N 287.58E N 34.27 E 18.46 2140.39N 307.16E N 26.71 E 27.13 2164.35N 321.27E N 23.37 E 11.79 2189.97N 333.24E 2059.30 2079.88 2103.74 2126.33 2150.76 9869.17 8927.47 8862.47 9905.39 8924.28 8859.28 9927.24 8922.53 8857.53 9961.52 8919.82 8854.82 9991.99 8916.93 8851.93 95 5 94 58 94 13 94 49 96 3 N 27.06 E 16.41 2216.06N 345.52E N 33.77 E 18.46 2247.16N 363.78E N 31.11 E 12.62 2265.54N ~75.46E N 29.00 E 6.39 2295.11N 392.57E N 26.89 E 7.99 2321.90N 406.78E 2175.62 2204.94 2222.18 2250.08 2275.48 10020.12 8913.55 8848.55 10049.32 8909.34 8844.34 10075.87 8905.66 8840.66 10105.69 8902.54 8837.54 10133.94 8900.15 8835.15 97 43 98 52 97 1 95 0 94 39 N 26.54 E 6.06 2346.84N 419.34E N 30.23 E 13.11 2372.26N 433.07E N 30.40 E 7.00 239~.95N 446.34E N 29.35 E 7.63 2420.66N 461.11E N 28.12 E 4.51 2445.34N 474.64E 2299.18 2323.24 2344.64 2368.91 2392.26 10172.59 8898.08 8833.08 10196.52 8897.29 8832.29 10225.12 8896.72 8831.72 10248.12 8897.22 8832.22 10280.39 8898.68 8833.68 91 29 92 16 90 0 87 32 87 16 N 27.06 E 8.65 2479.55N 492.51E N 27.06 E 3.30 2500.84N 503.39E N 27.77 E 8.35 2526.22N 516.55E N 26.76 E 11.56 2546.66N 527.09E N 24.95 E 5.66 2575.67N 541.14E 2424.70 2444.93 2469.01 2488.41 2516.02 ORIGINAL NOV 1997 Oil & Gas Cons. Commissior, .~ora§e SPF~'Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC. PBU / 2-0lB 500292044201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091597 MWD SURVEY JOB NUMBER: AK-MW-70248 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 10310.72 8900.02 8835.02 10356.02 8901.62 8836.62 10381.09 8901.82 8836.82 10410.37 8900.72 8835.72 10444.49 8898.46 8833.46 87 37 88 19 90 46 93 31 94 5 N 22.32 E 8.74 2603.42N 553.29E N 17.75 E 10.20 2645.94N 568.80E N 16.11 E 11.73 2669.92N 576.09E N 15.46 E 9.65 2698.08N 584.05E N 11.72 E 11.06 2731.16N 592.05E 2542.56 2583.50 2606.72 2634.04 2666.26 10485.54 8895.80 8830.80 10518.42 8894.19 8829.19 10548.37 8893.54 8828.54 10575.22 8893.83 8828.83 10604.37 8894.52 8829.52 93 20 92 16 90 10 88 35 88 40 N 8.78 E 7.38 2771.47N 599.34E N 5.44 E 10.65 2804.05N 603.40E N 1.40 E 15.20 2833.93N 605.19E N 2.29 W 14.96 2860.77N 604.98E N 4.23 W 6.66 2889.86N 603.32E 2705.74 2737.82 2767.42 2794.17 2823.29 10637.34 8894.75 8829.75 10665.42 8893.98 8828.98 10695.92 8892.13 8827.13 10730.42 8890.20 8825.20 10778.12 8889.65 8824.65 90 31 92 38 94 18 92 6 89 12 N 6.51 W 8.91 2922.68N 600.24E N 9.15 W 12.03 2950.49N 596.42E N 12.31 W 11.70 2980.40N 590.75E N 15.12 W 10.33 3013.85N 582.58E N 20.57 W 12.94 3059.23N 567.97E 2856.25 2884.29 2914.59 2948.65 2995.17 10805.49 8890.04 8825.04 10822.79 8890.26 8825.26 10861.39 8890.47 8825.47 10884.97 8890.19 8825.19 10915.44 8889.26 8824.26 89 7 89 28 89 54 91 24 92 6 N 22.16 W 5.82 3084.72N 558.00E N 24.26 W 12.30 3100.61N 551.19E N 26.73 W 6.50 3135.45N 534.58E N 28.31 W 9.24 3156.35N 523.68E N 31.30 W 10.07 3182.78N 508.55E 3021.45 3037.90 3074.09 3095.90 3123.59 10947.77 8888.32 8823.32 10983.49 8888.32 8823.32 11010.97 8889.26 8824.26 11047.59 8890.98 8825.98 11071.84 8892.00 8827.00 91 13 88 46 87 16 87 21 87 48 N 34.81 W 11.19 3209.86N 490.92E N 37.98 W 11.23 3238.60N 469.73E N 39.56 W 7.90 3260.01N 452.54E N 42.20 W 7.20 3287.67N 428.60E N 45.01 W 11.72 3305.21N 411.89E 3152.15 3182.70 3205.58 3235.29 3254.28 11104.42 8892.70 8827.70 11131.49 8892.45 8827.45 11163.07 8891.77 8826.77 11196.19 8891.52 8826.52 11235.44 8891.30 8826.30 89 44 91 19 91 8 89 44 90 52 N 48.70 W 12.79 3327.48N 388.13E N 52.04 W 13.65 334-4.74N 367.29E N 56.26 W 13.37 3363.23N 341.70E N 60.30 W 12.91 3380.64N 313.54E N 65.75 W 14.19 3398.43N 278.57E 3278.61 3297.69 3318.42 3338.31 3359.20 11253.79 8890.84 8825.84 11282.38 8889.50 8824.50 11321.86 8886.08 8821.08 11349.63 8882.60 8817.60 11388.98 8877.37 8812.37 92 1 93 20 96 35 97 49 97 28 N 68.21 W 14.77 3405.61N 261.69E N 69.09 W 5.55 3416.00N 235.09E N 71.02 W 9.56 3429.42N 198.13E N 74.01 W 11.56 3437.70N 171.85E N 77.00 W 7.58 3447.46N 134.10E 3367.87 3380.64 3397.35 3407.97 3421.12 SP¥~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC. PBU / 2- 0lB 500292044201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091597 MWD SURVEY JOB NUMBER: AK-MW-70248 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 11417.83 8873.66 8808.66 11452.43 8869.55 8804.55 11477.76 8867.32 8802.32 11505.78 8865.95 8800.95 11550.76 8865.19 8800.19 97 17 N 80.16 W 10.88 3453.12N 106.06E 96 19 N 82.80 W 8.07 3458.21N 72.09E 93 46 N 81.74 W 10.90 3461.60N 47.09E 91 50 N 80.52 W 8.18 3465.92N 19.44E 90 5 N 73.84 W 15.35 3475.89N 24.39W 3429.30 3437.44 3443.09 3449.89 3463.80 11575.83 8865.36 8800.36 11595.12 8865.76 8800.76 11631.92 8866.72 8801.72 11651.09 8867.26 8802.26 11679.54 8868.12 8803.12 89 7 N 72.43 W 6.83 3483.16N 48.38W 88 31 N 69.05 W 17.79 3489.52N 66.58W 88 30 N 66.10 W 8.01 3503.56N 100.58W 88 14 N 65.05 W 5.64 3511.48N 118.03W 88 19 N 63.46 W 5.59 3523.83N 143.64W 3473.21 3481.20 3498.25 3507.72 3522.35 11703.99 8868.51 8803.51 11733.77 8868.74 8803.74 11772.00 8869.43 8804.43 89 49 N 61.00 W 11.76 3535.22N 165.27W 89 18 N 58.19 W 9.60 3550.29N 190.95W 88 37 N 54.60 W 9.55 3571.44N 222.78W 3535.65 3552.98 3576.93 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3578.38 FEET AT NORTH 3 DEG. 34 MIN. WEST AT MD = 11772 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 354.80 DEG. TIE-IN SURVEY AT 9,300.00' MD WINDOW POINT AT 9,320.00' MD PROJECTED SURVEY AT 11,772.00' MD SPF Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 4 ARCO ALASKA INC. PBU / 2-0lB 500292044201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091597 JOB NUMBER: AK-MW-70248 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9300.00 10300.00 11300.00 11772.00 8788.60 8723.60 8899.57 8834.57 8888.25 8823.25 8869.43 8804.43 1797.31 N 60.82 E 511.40 2593.55 N 549.14 E 1400.43 889.03 3422.15 N 218.63 E 2411.75 1011.32 3571.44 N 222.78 W 2902.57 490.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPP~'~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 5 ARCO ALASKA INC. PBU / 2- 0lB 500292044201 NORTH SLOPE BOROUGH COMPUTATION DATE: 10/ 3/97 DATE OF SURVEY: 091597 JOB NUMBER: AK-MW-70248 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 9300.00 8788.60 8723.60 1797.31 N 60.82 E 511.40 9399.93 8865.00 8800.00 1858.42 N 78.92 E 534.93 23.53 9420.00 8878.44 8813.44 1871.49 N 86.07 E 541.56 6.63 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS D I::t I I--I-- I ~i G S I~ !::! ~./I I~ ~:: c: To~ State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. ~ Anchorage, Alaska 99501 ~1[[ ' RE: MWD Formation Evaluation Logs D.S. 02-0lB, AK-MW-70248 November 5, 1997 The technic~ data listed below is being submitted herewith. Please address any problems or concerns to the attention off Ytrn Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 D.S. 02-0lB: 2" × 5"MD Gamma Ray Logs: 50-029-20442-01 2"x 5" TVD Gamma Ray Logs: 50-029-20442-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company n Ft I I_1_1 ~J G October 31, 1997 AOGCC Lori Taylor 3001 Porcupine Dr Anchorage, AK 99501 Re: Distribution of Survey Data 2-01B Dear Ms. Taylor, The original distributed MWD surveys for this well had an error. The AP1 number was incorrect. Please destroy the previous data delivered and replace it with this corrected information. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:t I I--I-- I I~ G October 27, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 tq° Re: Distribution of Survey Data 2-01B Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 2-0lB MWD survey tie-in point at 9,300.00', window point at 9,320.00' and a projected survey at 11,772.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments .&nch0ra~e 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company r~ I::! I L_L_ I I~ 13 SEFt~Ir'ES WELL LOG TRANSMITTAL To: State of Alaska October 29, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Lori Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - D.S. 2-0lB, AK-MW-70248 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. APl#: 50-029-20442-01. OCT 30 199:/' 5631 Siiverado Way, Suite G · Anchorage, Alaska 99518 · (9¢7) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company m I:! I I__1__1 IM G S I:: I:! L~ I r' I~ S October 7, 1997 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 qq. Re: Distribution of Survey Data 02-0lB Dear Ms. Taylor: Enclosed are two hard copies of the above mentioned file(s). Well 02-0lB MWD survey tie-in point at 9,300.00', window point at 9,320.00' and a projected survey at 11,772.00'. Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Operations Support Engineer Attachments OCT 15 199'/' Anchorage 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM TO' David Johnsto.~~ Chairman THRU' State of Alaska Alaska Oil and Gas Conservation Commission DATE' September 17, 1997 Blair Wondzeil, P. I. Supervisor FROM: Chuck Scheve ~--_5 SUBJECT: Petroleum Inspector FILE NO: ae8kiqee.doc BOPE Test Nabors 3S PBU DS2-01B PTD 97-140 Wednesday, September 17, 1997: I traveled to ARCO's PBU DS 2-01B well being drilled by the CTU rig Dowel / Nabors 3S and witnessed the weekly BOPE test. As the attached AOGCC BOPE Test Report shows there were no failures on the equipment tested. The remote BOP control station in the CTU operators cab was not functional at the time of this test due to recent electrical problems. The rig floor will be maned at all times until repairs can be efected to this remote station. The rig was clean and all equipment seemed to be in good working order. The location was clean and all extra equipment was stored properly. Summary: I witnessed the weekly BOPE test on ARCO's DS2-01B being drilled by Dowell/Nabors Rig 3S. Nabors 3S, 9117/97, test time 3 hours, 0 failures Attachment: aeSkiqee. XLS X Unclassified Confidential (Unclassified if doc. removed ) Confidential STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION Coil Tubing Unit BOPE Test Report OPERATION: Drlg: X Workover: Drlg Contractor: Nabors/Dowelt Operator: Arco Well Name: DS2-01B Casing Size: Set @ Test: Initial Weekly DATE: 9/17/97 Rig No. 3ES PTD# g7-140 Rig Ph.# 448-1334 Rep.: Gary Goodrich Rig Rep.: Bob Mize Location: Sec. 36 T. 11N R. 14E Meridian UM , , x Other BOP STACK: Coil Tubinq Unit: Pipe/Slip Rams Pipe/Slip Rams Blind Rams Reel Isolation Valve Deployment: Annular Preventer Pipe Rams Lower Pipe Rams Blind Rams Choke Ln. Valves HCR Valves Kill Line Valves Test Test Quan. Pressure P/F Pressure P/F 250-3500 P 250-3500 P 250-3500 P 250-3500 P 250-3500 P 250-2500 1 250-3500 1 250-3500 2 250-3500 CHOKE MANIFOLD: Quan. No. Valves 13 No. Flanges Manual Chokes Hydraulic Chokes I 26 250-3500 P 1 Functioned Functioned ACCUMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Master: Nitgn. Btl's: 2800 I 2300 minutes 15 sec. 1 minutes 15 sec. Yes Remote: Yes 4~2000average Psig. MUD SYSTEM: Visual Alarm MISC. INSPECTIONS: Trip Tank Location Gen.: OK Pit Level Indicators Housekeeping: OK Meth Gas Detector 4 P Permit to drill: YES H2S Gas Detector 4 P Standing Order Posted YES Well Sign Drl. Rig OK Hazard Sec. YES Number of Failures: 0 ,Test Time:"'3.0 CHours. Number of valves tested 20 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 If your call is not returned by the inspector within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Distribution: odg-Well File c - Oper.lRig c - Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: Chuck Scheve Form Revised 1/6/97 DA. ctboptst MEMORANDUM State of Alaska Alaska Oil a-nd Gas Conservation Commission TO: David John~ DATE' Chairman -~ THRU' Blair Wondzell, .;~ FILE NO' P. I. Supervisor FROM' Lou G ri m a Id i,/, .~'~./c,.~ SUBJECT: Petroleum InSpector September 12, 1997 QE8JILEE.DOC Rig/BOPE inspection Dowell/Nabors 4/3ES ARCO well #DS2-01B PTD #97-140 Friday, September 12, 1997;I made a Rig/BOPE inspection on Dowell/Nabors 4/3ES which is performing a sidetrack on ARCO's well # DS2-01B. The CTU was tripping in the hole after a repair on the tubing. I spoke with Bob Mize (Neighbors toolpusher) toured the rig with me and I found all equipment to be in place and in apparent good shape. SUMMARY' I made a Rig/BOPE inspection on Dowell/Nabors 4/3ES. I f,_.ound all to be in compliance. Attachments: QE8JILEE.XLS cc' Bruce Smith (CTU drilling supr.) NON-CONFIDENTIAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG I BPS INSPECTION REPORT OPERATION: Drilling X Workover Compl. UIC DATE: 9/12/97 Well Name: DS 2-01B PTD# 97-140 Drig Contractor: Dowell/Nabors Rig# Dowell#4/3-NS Rep. Bob Mize Operator: Arco Alaska Rep. Arville Bass Rig Ph.# 448-1334 Location: Section 36 T. 11N R. 14E M. U INSPECTION ITEMS IN COMPLIANCE INSPECTION ITEMS IN COMPLIANCE (A.) B.O.P. STACK YES NO N/A (C.) MUD SYSTEM YES NO N/A 1 Wellhead fig wkg press X 29 Pit level floats installed X 2 Stackwkg press X 30 Flow rate sensor X 3 Annular preventer X 31 Mud gas separator X 4 Pipe rams X 32 Degasser X 5 ~Blind rams X 33 Separator bypass X 6 Stack anchored X 34 Gas sensors X 7 Chke/kill line size X 35 Choke line connections X 8 All turns targeted ( chke & kill Ln.) X 36 ~Trip tank X 9 HCR valves (chke & kill Ln.) X INSPECTION ITEMS IN COMPLIANCE 10 Manual valves (chke & kill Ln.) X (D.) RIG FLOOR YES NO N/A 11 Connections (Flgd, Whd, Clamped X 37 Kelly cocks (upper, lower, IBOP) X 12 Drilling spool X 38 Floor valves (dart, ball, ect.) X 13 Flow Nipple X 39 Kelly & floorvalve wrenches X 14 Flow monitor X 40 Drillers console (flow monitor, X 15 Control lines fire protected X flow rate indicator, pit level INSPECTION ITEMS IN COMPLIANCE indicators, gauges) (B.) CLOSING UNIT YES NO NIA 41 Kill sheet up-to-date X 16 Working pressure X 42 Gas detection monitors X 17 Fluid level X (H2S & methane) 18 Operating pressure X 43 Hydraulic choke panel I X 19 Pressure gauges X 44 Choke manifold X 20 Sufficient valves X INSPECTION ITEMS IN COMPLIANCE 21 Regulator bypass X (E.) MISC. EQUIPMENT YES NO NIA 22 4-way valves (actuators) X 45 Flare/vent line X 23 Blind rams handle cover X 46 All turns targeted X 24 Driller control panel X (downstream choke lines) 25 Remote control panel X .I 47 Reserve pittankage X 26 Firewall X 48 Personnel protective equip, avail. X 27 Nitrogen power source (backup) X 49 All Drillsite Supervisors Trained X 28 Condition (leaks, hoses, ect.) X For Procedures 50 H2S probes X 51 Rig housekeeping X REMARKS: Rig in good shape RECORDS: Date of Last Rig / BPS Inspection ? Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? Yes 9/10/97 None Kill Sheet Current? Yes Distribution: orig - Well File c- Oper./Rig c - Database c - Trip Rpt File c- Inspector AOGCC REP: Lou Grimaldi OPERATOR REP: Bob Mize QE8JILEE.XLS (Rev. 12/92) TONY KNOWLE$, GOVERNOR ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 July 31. 1997 Erin Oba Engineering Supervisor ARCO Alaska P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bav Unit 2-01B ARCO Alaska. Inc. Permit No. 97-t 40 Sur. Loc.: 651'S & 1694'E of NW ct. Sec. 36. T11N. RI4E. UM Btmnhole Loc.: 2196'FNL. 3728'FEL. Sec. 25. T1 IN. RI4E. UM Dear Ms. Oba: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice mav be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures Department of Fish & Game. Habitat Section w/o encl. Department of Environmental Conservation xv/o encl. STATE OF ALASKA ALASr,,A OIL AND GAS CONSERVATION COMI~SION PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Ddll _ Redrill X [ lb. Type of Well Exploratory_ Stratigraphic Test _ Development Oil ~X Re-Entry__ Deepen -I Service_ Development Gas_ Single Zone X Multiple Zone_ 2. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P.O. Box 100360 Prudhoe Bay Field Anchorage, AK 99510-0360 ADL 28308 Prudhoe Bay Oil Pool 4. Location of well at sudace 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 651' S & 1694' E of NW cr, Sec 36, T11 N, R14E, UM. Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 910' N & 1707' E of SW cr, Sec 25, T11 N, R14E, UM. 2-01B #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 2196' FNL, 3728' FEL, Sec 25, T11 N, R14E, UM. August, 1997 $200,000 12. Distance to nearest I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line No Close Approach 11800' MD / 8840' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 2O AAC 25.035(e)(2)) kickoff depth 9300' MD Maximum hole angle 90° Maximum surface 2800 psig At total depth (TVD) 8840' 18. Casing program Setting Depth Size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 4-3/8" 3-1/2" 9.3 L-80 FL4S 3185' 8515' 8136' 11800' 8840' 33 bbls 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 9640 feet Plugs(measured) A 1 true vertical 9076 feet ORIGIN Effective depth: measured 9591 feet Junk (measured) true vertical 9035 feet Casing Length Size Cemented Measured depth True Vertical depth Conductor 75' 20" 350 Sx Arcticset II 75' 75' Surface 2626' 13-3/8" 2700 Sx Fondu 2690' 2690' Production 9556' 9-5/8" 1200 Sx Class G 9630' 9068' REC iVED Perforation depth: measured 9434 - 9442; 9450 - 9458'; 9472 - 9498' jul. '1G '199Z true vertical 8902 - 8909'; 8916 - 8923'; 8935 - 8956' Alaska 0il & Gas Cons. Commission Anchorage 20. Attachments Filing fee ~ Property plat _ BOP Sketch ~ Diverter Sketch _ Ddlling program Drilling fluid program __ Time vs depth plot ~ Refraction analysis _ Seabed report 20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge (~d ¢_..%f [0 ~% ~ 5~(~',,/~ ~/0.¢'c~. 2 (o ~-- ./_ 50% · Signed _~::2~ % ' ~ Titlle Engineering Supervisor Date Commission Use Only Permit Number I APInumber I Approvaldate I See cover letter for ~'7 'Z/~/'",~ 50- <C, P__.'~ --~--~ ~Z'/.ZZ.~ _ ~/. ~ "'~--/"'" f¢ other requirements ~Condltions of approval Samples required Yes ,~_No Mud log required _ Yes ~4No Hydrogen sulfide measures ~ Yes _ No Directional survey required ,~( Yes _ No Required working pressure for BOPE _ 2M; _ 3M; _ 5M; _ 10M; _ 15M _X 3500 psi for CTU Other: dngi,~al $~gnecl By 0avid W. Johnston by order of ?---2/----~'~'"'~ Approved by Commissioner the commission Date Form 10-401 Rev. 7-24-89 Submit in triplicate DS 2-lB CT Sidetrack and Completion Intended Procedure Objective: Plugback existing wellbore. Directionally drill a horizontal well from the existing wellbore. Complete with 3-1/2" cemented liner. Intended Procedure: · Cement squeeze and plugback the existing completion to - 925U md. Mill window in 9-5/8" casing at -9280' md. D~511 10' of formation and perfmTn Leak off test to 0.5 ppg above the highest anticipated mud weight. Build angle to -93°. Directionally drill 4-3/8" x 2100' horizontal well to access Lower Romeo reserves. · Run and cement 3-1/2" liner to TD. · Perforate selected intervals. · Place well on production. July 15, 1997 DS 2-1B Proposed CT Sidetrack Horizontal 5-1/2" Packer 5-1/2" RQM SSSV Nipple ID = 4.562,' 5-1/2" XA Sliding Sleeve ID = 4.562" XN Nipple 8644' Tbg Tail 8645' Top of 3-1/2" Liner in 5-1/2" Tbg. tail. Initial Perfs- 1200' 9-5/8" Casing shoe @ 9630' Window cut in 9-5/8" at -928O- 9285' 4-3/8" Open hole Current perforations cement squeezed 3-1/2" liner TD @ - 11700' DRILE ARCO ALASKA INC. 2-01 BT 2-010RTR DS 2-01B PRUDHOE BAY ALASKA 4000 NORTH RELi To TRUE N. rue (+0) ag (+28,53) I I I 84OO 8600 88OO 9OOO PLANE OF VERT SECTn 354.79° RELATIVE TO TRUE NORTH 2 1500 1 TIP o o o o o 00Tf Departure Scale 1 inch: 500 ft - 30'~ KOP O o o o o 1',3 o o O O o o o o o o o o O o o o o Vertical Section Scale 1 inch: 200 ft FILE NAME: C;\ARCOALK~2-01B\2-01BA1. DW2 PLANNED BY: BIMO HADIPUTRO DATE :JULY 15. 1997 Client Well Name Location : Arco Alaska Inc. : 2-01 B in True Relative Coordinates : 2-01 B Directional Sidetrack No Interpolat Page 1 of 3 )_.EiIen~me : 2-01BT Prudhoe Bay ion Height of Platform Datum above Customer ~A~m-,.-~ -.~ ..... ft Height of Well Datum above Platform Datum '0.00 ft Ail TVDs are relative to the Well Datum Level MD ft 9100 9120 9150 9180 9210 INC deg 35.O 35.0 35.0 35.0 35.0 DIR SS TVD LAT DEP VS D'LEG BUILD TURN COMMENT deg ft ft ft ft °/100 °/100 °/100 11.0 8557 1689 40 0 0.0 0.0 0.0 11.0 8573 1701 42 11 0.0 0.0 0.0 11.0 8598 1717 46 28 0.0 0.0 0.0 11.0 8622 1734 49 44 0.0 0.0 0.0 11.0 8647 1751 52 61 0.0 0.0 0.0 9240 9270 9280 9300 933~0 35 35 35 37 41 .0 .0 .0 .6 .6 11.0 8671 1768 56 77 0.0 0.0 0.0 11.0 8696 1785 59 94 0.0 0.0 0.0 11.0 8704 1791 60 99 0.0 0.0 0.0 13.4 8720 1802 62 110 14.9 13.0 12.2 16.6 8743 1821 67 128 14.9 13.3 10.5 9360 9390 9420 9450 9480 45 49 53 58 62 .7 .8 .9 .1 .4 19.3 8765 1840 74 147 14.9 13.5 9.0 21.6 8785 1861 82 167 14.9 13.7 7.8 23.7 8804 1883 91 188 14.9 13.9 6.9 25.6 8820 1905 101 210 14.9 14.0 6.2 27.3 8835 1929 113 232 14.9 14.1 5.7 9510 9540 9570 9600 9630 66 70 75 79 83 .6 .8 .1 .4 .7 28.9 8848 1953 125 255 14.9 14.1 5.3 30.3 8859 1977 139 278 14.9 14.2 4.9 31.7 8868 2001 154 301 14.9 14.2 4.7 33.1 8874 2026 170 324 14.9 14.2 4.5 34.4 8879 2051 186 347 14.9 14.3 4.4 9660 9690 9699 9720 9750 87 92 93 93 93 .9 .2 .5 .5 .6 35.7 8881 2075 203 370 14.9 14.3 4.3 37.0 8881 2099 221 392 14.9 14.3 4.3 37.4 8881 2107 227 399 14.9 14.3 4.3 36.6 8879 2123 239 414 3.6 0.1 -3.6 35.5 8877 2148 257 437 3.6 0.1 -3.6 9780 9810 9840 9870 9900 93 93 93 93 93 .6 .6 .6 .7 .7 34.4 8876 2172 274 460 3.6 0.1 -3.6 33.3 8874 2197 291 483 3.6 0.1 -3.6 32.2 8872 2222 307 507 3.6 0.1 -3.6 31.1 8870 2248 323 531 3.6 0.1 -3.6 30.0 8868 2273 338 555 3.6 0.1 -3.6 9930 9960 9990 10020 1O05O 93 .7 93.7 93.8 93.8 93.8 28.9 8866 2300 353 579 3.6 0.1 -3.6 27.8 8864 2326 367 604 3.6 0.1 -3.6 26.7 8862 2352 381 630 3.6 0.1 -3.6 25.7 8860 2379 394 655 3.6 0.1 -3.6 24.6 8858 2406 406 681 3.6 0.1 -3.6 Client : Arco Alaska Inc. Well Name : 2-01 B in True Relative Coordinates Location : 2-01 B Directional Sidetrack : : Prudhoe Bay No Interpolation Page 2 of 3 Date Filename : 2-01BT Height of Platform Datum above Customer Datum Height of Well Datum above Platform Datum 0.00 All TVDs are relative to the Well Datum Level 0.00 ft ft MD ft 10080 10110 10140 10170 10200 INC deg 93.8 93.8 93.8 93.8 93.9 DIR SS TVD LAT DEP VS D'LEG BUILD deg ft ft ft ft °/100 °/100 23.5 8856 2434 419 707 3.6 0.1 22.4 8854 2461 430 734 3.6 0.0 21.3 8852 2489 441 760 3.6 0.0 20.2 8850 2517 452 787 3.6 0.0 19.1 8848 2545 462 814 3.6 0.0 TURN COMMENT °/100 -3.6 -3.6 -3.6 -3.6 -3.6 10230 10260 10290 10320 10350 93 93 93 93 93 .9 18.0 8846 2574 472 842 3.6 0.0 .9 16.9 8844 2602 481 869 3.6 0.0 .9 15.8 8842 2631 489 897 3.6 0.0 .9 14.7 8840 2660 497 925 3.6 0.0 .9 13.6 8838 2689 504 953 3.6 0.0 -3.6 -3.6 -3.6 -3.6 -3.6 10380 10410 10440 10470 10500 93 93 93 93 93 .9 12.5 8836 2718 511 982 3.6 0.0 .9 11.4 8834 2747 517 1010 3.6 0.0 .9 10.3 8832 2777 523 1039 3.6 -0.0 .9 9.2 8830 2806 528 1068 3.6 -0.0 .9 8.1 8828 2836 532 1097 3.6 -0.0 -3 -3 -3 -3 -3 .6 .6 .6 .6 .6 10530 10560 10590 10617 10620 93 93 93 93 93 .9 7.0 8826 2865 536 1126 3.6 .9 6.0 8824 2895 540 1156 3.6 .9 4.9 8822 2925 543 1185 3.6 .9 3.9 8820 2951 545 1211 3.6 .8 3.6 8820 2955 545 1215 7.5 -0.0 -0.0 -0.0 -0.0 -0.3 -3 -3 -3 -3 -7 .6 .6 .6 .6 .5 10650 10680 10710 10740 10770 93 93 93 93 93 .8 .7 .6 .5 .4 1.4 8818 2985 546 1244 7.5 359.1 8816 3015 546 1274 7.5 356.9 8814 3045 545 1304 7.5 354.6 8812 3074 543 1334 7.5 352.4 8810 3104 540 1364 7.5 -0.3 -0.3 -0.3 -0.3 -0.3 -7 -7 -7 -7 -7 .5 .5 .5 .5 .5 10800 10830 10860 10890 10920 93 93 93 92 92 .3 .2 .0 .9 .8 350.1 8809 3134 535 1394 7.5 347.9 8807 3163 529 1424 7.5 345.6 8805 3192 522 1453 7.5 343.4 8804 3221 514 1483 7.5 341.1 8802 3250 505 1512 7.5 -0.4 -0.4 -0.4 -0.4 -0.4 -7 -7 -7 -7 -7 .5 .5 .5 .5 .5 10950 10980 11010 11040 11070 92.7 92.5 92.4 92.2 92.1 338.9 8801 3278 495 1541 7.5 336.6 8799 3306 484 1570 7.5 334.4 8798 3333 471 1598 7.5 332.1 8797 3360 458 1626 7.5 329.9 8796 3386 443 1653 7.5 -0.4 -0.5 -0.5 -0.5 -0.5 -7.5 -7.5 -7.5 -7.5 -7.5 Client : Arco Alaska Inc. Well Name : 2-01 B in True Relative Coordinates Location : 2-01 B Directional Sidetrack : : Prudhoe Bay No Interpolation Page 3 Date Filename of 3 : 2-01BT Height of Platform Datum above Customer Datum 0.00 Height of Well Datum above Platform Datum 0.00 ft All TVDs are relative to the Well Datum Level ft MD INC ft deg 11100 91.9 11130 91.8 11160 91.6 11190 91.5 11220 91.3 DIR SS TVD LAT DEP VS D'LEG BUILD deg ft ft ft ft °/100 °/100 327.6 8795 3412 428 1680 7.5 -0.5 325.4 8794 3437 411 1706 7.5 -0.5 323.1 8793 3461 394 1732 7.5 -0.5 320.9 8792 3484 375 1757 7.5 -0.5 318.6 8791 3507 356 1782 7.5 -0.5 TURN COMMENT °/100 7.5 7.5 7.5 7.5 7.5 11250 91.1 316.4 8791 3529 336 1806 7.5 -0.5 11280 91.0 314.2 8790 3551 314 1829 7.5 -0.6 11310 90.8 311.9 8790 3571 293 1851 7.5 -0.6 1134,0 90.6 309.7 8789 3591 270 1873 7.5 -0.6 11370 90.5 307.4 8789 3610 246- 1894 7.5 -0.6 -7. 11400 90.3 305.2 8789 3627 222 1914 7.5 -0.6 11430 90.1 302.9 8789 3644 197 1933 7.5 -0.6 11460 90.0 300.7 8789 3660 172 1951 7.5 -0.6 11490 89.8 298.5 8789 3675 146 1968 7.5 -0.6 11520 89.6 296.2 8789 3689 119 1984 7.5 -0.6 -7. 11550 89.4 294.0 8789 3701 92 1999 7.5 -0.6 11580 89.3 291.7 8790 3713 64 2013 7.5 -0.6 11610 89.1 289.5 8790 3723 36 2026 7.5 -0.6 11617 89.1 289.0 8790 3726 30 2029 7.5 -0.6 11640 90.7 290.1 8790 3733 8 2039 8.5 7.1 -7. 11670 92.9 291.5 8789 3744 -20 2052 8.5 7.1 11700 95.0 292.9 8787 3755 -48 2066 8.5 7.1 11730 97.2 294.3 8784 3767 -75 2080 8.5 7.1 11760 99.3 295.7 8780 3780 -102 2095 8.5 7.1 11786 101.1 296.9 8775 3791 -125 2108 8.5 7.1 4.6 4.7 4.7 4.7 4.8 Origin of Bottom Hole Closure PLATFORM CENTRE Bottom Hole Closure 3793 ft 358.1° C T Drilling Wellhead Detail Methanol Injection ~,~ Otis 7" WLA Quick Connect ~ CT Injector Head Stuffing Box (Pack-Off), 10,000 psi Working Pressure -- 7" Riser Annular BOP (Hydril),7-1/16" ID 5,000 psi working pressure Alignment Guide Flange 7-1/16", 5M Ram Type Dual Gate BOPE Flanged Fire Resistant Kelly Hose to Dual HCR Choke Manifold \ Cutters or Combination Cutter/Blinds Slip / Pipe rams Manual Valves Drilling spool 7-1/16", 5M by 7-1/16", 5M Ram Type Dual Gate BOPE Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Master Valve 0.458' (5.5") 2" Pump-In Hanger Fire resistant Kelly Hose to Flange by Hammer up 1/4 Turn Valve on DS Hardline to Standpipe manifold 9-5/8" Annulus 13-3/8" Annulus Mu( Tan ks 60/40 I'TrplxI h~re Ext. Shop Fuel Boilers Water Pump Fire Ext. Ext. ,~Pipe rack ~c~ ~c EDOWell Drilling quipment Trailer Preferred Major Equipment Layout for CT Drilling ..... STATE OF ALASKA A,. LA OIL AND GAS CONSERVATION COMMISSIL * . APPLICATION FOR SUNDRY APPROVALS 1. Type ct request: Abandon _X Suspend _ Operation Shutdown _ Reenter suspended well __ Alter casing _ Repair well _ Plugging _X Time extension _ Stimulate __ Change approved program Pull tubing Variance _ Perforate _ Other _ 2. Name of Operator: 5. Type of Well: 6. Datum ol elevation (DF or KB feet): ARCO Alaska, Inc. Development_X 64' RKB 3. Address: Exploratory_ 7. Unit or Property: P.O. Box 100360 stratagrapic_ Anchorage, AK 99510-0360 Service_ Prudhoe Bay Unit 4. Location of well at surface: 8. Well number: 651' S & 1694' E of NW or, Sec 36, T11 N, R14E, UM 2-01A At top of productive interval: 9. Permit number: 910' N & 1707' E of SW cr, Sec 25, T11 N, R14E, UM 80-14 At effective depth: 10. APl number: 50-029-20442 At total depth: 11. Field/Pool: 1156' N & 1539' E of SW cr, Sec 34, T11N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total Depth: measured 9640 feet Plugs (measured) true vertical 9076 feet Effective Depth: measured 9591 feet Junk (measured) true vertical 9035 feet Casing Length Size Cemented Measured depth True vertical depth Conductor 75' 20" 350 Sx Arcticset II 75' 75' Surface 2626' 13-3/8" 2700 Sx Fondu 2690' 2690' Production 9556' 9-5/8" 1200 Sx Class G 9630' 9068' Perforation Depth measured 9434 - 9442'; 9450 - 9458'; 9472 - 9498' ORIGINAL true vertical 8902 - 8909'; 8916 - 8923'; 8935- 8956' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 8645' MD. Packers and SSSV (type and measured depth) Baker SAD Packer @ 8595' MD; Otis RQM SSSV @ 2245' MD. · 13. Attachments Description summary of proposal_ X Detailed operations program _ BOP sketch _ X 14. Estimated date for commencing operation 15. Status of well classification as: August, 1997 Oil _ X Gas _ Suspended _ 16. If proposal was verbally approved Name o! approver Date approved Service 17. I hereby certify that the forgoing is true and correct to the best of my knowledge. ~ ~ esr; o,~ s ' G re. ,., ~ ',,,,/,:,..¢ &. ¢ 2.-G ~-.[ ~'oC,- Signed ~¢,~ -~'~ , ~ Title: Engineering Supervisor Date "~""'t/..,,('-''' '¢ 7 FOIl COMMISSION USE ONLY Conditions of approval: Notify Comission so representitive may witness ]Approval Noz~.,~ ! ,,~ Plug integrety _ BOP test _ Location clearance _ ,.~- Mechanical integrety test __ Subsequent form required 10-__ Approved by order of the Commissioner Commissioner Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE · WELLPERMIT CHECKLISTCOMPANY WELL NAME ./Z~Z-~'_ .~..- c:~/'X~ PROGRAM: exp [] dev~redrll'~ serv [] wellbore segE] ann. disposal para req [3 FIELD & POOL C ~X~ INIT CLASS ~:~z.-' /-,~>,) Y GEOL AREA _f?~¢ <3 UNIT# /'~ ~'3'<:3 ON/OFF SHORE ~-J/~.J ADMINISTRATION 1. Permit fee attached ....................... 2. Lease number appropriate ................... 3. Unique well name and number .................. 4. Well located in a defined pool .................. 5. Well located proper distance from drilling unit boundary .... 6. Well located proper distance from other wells .......... 7. Sufficient acreage available in drilling unit ............ 8. If deviated, is wellbore plat included ............... 9. Operator only affected party ................... 10. Operator has appropriate bond in force ............. 11. Permit can be issued without conservation order ........ 12. Permit can be issued without administrative approval ...... 13. Can permit be approved before 15-day wait ........... ENGINEERING APPR DA~E 14. Conductor string provided ................... Y N 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ N 18. CMT will cover all known productive horizons .......... N 19. Casing designs adequate for C, T, B & permafrost ....... N 20. Adequate tankage or reserve pit ................. N 21. If a re-drill, has a 10-403 for abandonment been approved... N 22. Adequate wellbore separation proposed ............. N 23. If diverter required, does it meet regulations .......... N 24. Drilling fluid program schematic & equip list adequate ..... N 25. BOPEs, do they meet regulation ..... N 26. BOPE press rating appropriate; test to ~'~"Z~ ' ' ' .l~sig: N 27. Choke manifold complies w/APl RP-53 (May 84) ........ N 28. Work will occur without operation shutdown ........... N 29. Is presence of H2S gas probable ................. N REMARKS, GEOLOGY / 30. Permit can be issued w/o hydrogen sulfide measures ..... YY N// .., /~ 31. Data presented on potential overpressure zones ....... y~NN ,//~,/.~ 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............. / 34. Contact name/phone for we.ekly,oro.qress reports .... .,/'i'. Y N l expmra'tory only] GEOLOGY: ENGINEERING: COMe, SION: R PC~.~__ B EV~.~__~/~ 8 DWJ_~ Comments/Instructions: HOW/Ijt - A:\FORMS\cheklist rev 07/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Mon Oct 27 10:32:09 1997 Reel Header Service name ............. LISTPE Date ..................... 97/10/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/10/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: M C OF LM[D Date 0CT ~0 i99'/' DS 2-0lB 500292044201 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 27-OCT-97 MWD RUN 2 AK-MW-70248 A. WORTHINGT GARY GOODRIC MWD RUN 3 AK-MW-70248 A. WORTHINGT GARY GOODRIC MWD RUN 4 AK-MW-70248 A. WORTHINGT GARY GOODRIC JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 AK-MW-70248 A. WORTHINGT GARY GOODRIC MWD RUN 9 AK-MW-70248 A. WORTHINGT GARY GOODRI C MWD RUN 10 AK-MW-70248 A. WORTHINGT GARY GOODRIC JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 11 AK-MW-70248 W.C. JACKSON GARY GOODRIC MWD RUN 12 AK-MW-70248 W.C. JACKSON GARY GOODRIC MWD RUN 13 AK-MW-70248 W.C. JACKSON A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 14 AK-MW-70248 W.C. JACKSON A. BASS MWD RUN 15 AK-MW-70248 W.C. JACKSON A. BASS MWD RUN 16 AK-MW-70248 W.C. JACKSON A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 17 AK-MW-70248 W.C. JACKSON A. BASS MWD RUN 18 AK-MW-70248 A. WORTHINGT A. BASS MWD RUN 19 AK-MW-70248 A. WORTHINGT A. BASS JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MWD RUN 22 AK-MW-70248 A. WORTHINGT A. BASS 36 liN 14E 651 1694 64.00 .00 .00 SGRD = SMOOTHED GAMMA RAY. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 13.375 2690.0 2ND STRING 9.625 9333.0 3RD STRING 5.500 8645.0 PRODUCTION STRING 4.500 11772.0 REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1-22 ARE NATURAL GAMMA RAY PROBE (NGP) UTILIZING SCINTILLATION -- DETECTOR. 3. MWD RUNS 1, 5, 7, 8, 20, AND 21 MADE NO FOOTAGE AND ARE NOT PRESENTED. 4. MWD RUNS 2-4,6,9-19,AND 22 REPRESENT WELL 2-lB WITH API#: 50-029-20442-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 11772'MD, 8801'SSTVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH GR 9201.0 ROP 9227.5 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) -- BASELINE DEPTH 9201~0 9208 9214 9237 9240 9241 9244 9246 9250 9308 9311 9318 9325 9329 9330 9333. 11772. $ MERGED PBU MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD $ GR 9198.0 5 9205.5 5 9211.0 5 9235.0 5 9238.5 5 9239.0 5 9241.0 0 9243.0 0 9247.0 5 9305.0 5 9311.0 0 9316.5 0 9322.5 0 9326.5 0 9328.0 5 9331.5 5 11770.5 DATA SOURCE TOOL CODE BIT RUN NO 2 3 4 6 9 10 11 12 13 14 15 16 17 18 19 22 all bit runs merged. STOP DEPTH 11739.0 11772.5 EQUIVALENT UNSHIFTED DEPTH -- MERGE 9200 9295 9327 9334 9340 9410 9627. 9675. 9905. 9946. 10080. 10501. 10600. 11072. 11293. 11649. TOP MERGE BASE 0 9295.0 0 9327.0 0 9334.0 0 9340.0 0 9410.0 0 9627.0 0 9675.0 0 9905.0 0 9946.0 0 10080.0 0 10501.0 0 10600.0 0 11072.0 0 11293.0 0 11649.0 0 11772.0 REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD AAPI 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9201 11772.5 10486.8 5144 9201 ROP 0.8 3636 124.162 5091 9227.5 GR 16.36 745.5 77.9594 5077 9201 Last Reading 11772.5 11772.5 11739 First Reading For Entire File .......... 9201 Last Reading For Entire File ........... 11772.5 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9198.0 ROP 9225.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9269.0 9294.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 24-AUG- 97 MSC 1.32 NGP 5.74, DEP MEMORY 9295.0 9200.0 9295.0 34.6 35.0 TOOL NUMBER NGP SPC 184 4.550 4.6 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max. frames per record ............. Undefined Absent value ...................... -999,25 Depth Units ....................... Datum Specification Block sub-type.,,0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR I~WD 2 AAPI 4 1 68 4 2 ROP MWD 2 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9198 9294.5 9246,25 194 9198 GR 16.36 48,93 22,8217 143 9198 ROP 11.87 105.2 29,5042 140 9225 Last Reading 9294.5 9269 9294,5 First Reading For Entire File .......... 9198 Last Reading For Entire File ........... 9294.5 File Trailer Service name ............. STSLIB,002 Service Sub Level Name.,. Version Number ........... 1.0,0 Date of Generation ....... 97/10/27 Maximum Physical Record,,65535 File Type ................ LO Next File Name ........... STSLIB,003 Physical EOF File Header Service name ............. STSLIB,003 Service Sub Level Name,., Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record,.65535 File Type ................ LO Previous File Name ....... STSLIB,002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files, BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9273.5 9302,5 ROP 9295.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 9326.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL G~ PROBE $ . BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G) : MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMS) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL M~TRIX: NLATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 24-AUG-97 MSC 1.32 NGP 5.74, DEP MEMORY 9327.0 9295.0 9327.0 34.6 35.1 TOOL NUMBER NGP SPC 184 4.550 4.6 S EA-WAT ER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 3 AAPI 4 1 68 4 2 ROP MWD 3 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9273.5 9326.5 9300 107 9273.5 GR 19.57 23.02 21.8922 59 9273.5 ROP 4.11 1523.8 172.679 64 9295 Last Reading 9326.5 9302.5 9326.5 First Reading For Entire File .......... 9273.5 Last Reading For Entire File ........... 9326.5 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9303.0 ROP 9327.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 9310.0 9334.0 25-AUG-97 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 NGP 5.74, DEP MEMORY 9334.0 9327.0 9334.0 35.1 36.3 TOOL NUMBER NGP SPC 184 4.550 4.6 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 79.7 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 4 A3~PI 4 1 68 4 2 ROP I~WD 4 FT/H 4 1 68 Name Min Max Mean DEPT 9303 9334 9318.5 GR 17.72 22 20.3793 ROP 0.8 1465.5 210.013 Nsam 63 15 15 First Reading 9303 9303 9327 Last Reading 9334 9310 9334 First Reading For Entire File .......... 9303 Last Reading For Entire File ........... 9334 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9310.5 9316.0 ROP 9334.5 9340.0 $ LOG HEADER DATA DATE LOGGED: 28-AUG-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 9340.0 TOP LOG INTERVAL (FT) : 9334.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM~d~GLE: MAXIMUM~GLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 9340.0 36.3 37.6 TOOL NUMBER NGP SPC 184 4.550 4.6 SEA-WATER .00 .0 .0 0 .0 .000 .000 .000 .000 77.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 6 AAPI 4 1 68 4 2 ROP MWD 6 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEPT 9310.5 9340 9325.25 60 GR 19.57 22.07 20.5917 12 ROP 23.62 79.2 45.5092 12 '9310.5 9310.5 9334.5 9340 9316 9340 First Reading For Entire File .......... 9310.5 Last Reading For Entire File ........... 9340 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9316.5 9383.5 ROP 9340.5 9410.0 $ LOG HEADER DATA DATE LOGGED: 01-SEP-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9410.0 TOP LOG INTERVAL (FT) : 9340.0 BOTTOM LOG INTERVAL (FT) : 9410.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 37.6 MAXIMUM ANGLE: 47.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 239 4.550 4.6 FLO- PRO 9.50 .0 9.0 6.2 .000 .000 .000 .000 56.2 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 9 AAPI 4 1 68 4 2 ROP MWD 9 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9316.5 9410 9363.25 188 9316.5 GR 29.76 123.44 47.4256 135 9316.5 ROP 11.39 250.21 34.2354 140 9340.5 Last Reading 9410 9383.5 9410 First Reading For Entire File .......... 9316.5 Last Reading For Entire File ........... 9410 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF File Header Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9384.0 9599.5 ROP 9410.5 9625.5 $ LOG HEADER DATA DATE LOGGED: 02-SEP-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5~74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9627.0 TOP LOG INTERVAL (FT): 9410.0 BOTTOM LOG INTERVAL (FT): 9627.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 47.9 MAXIMUM ANGLE: 91.7 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA TOOL NUMBER NGP SPC 239 Dat OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION ~(IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.550 4.6 FLO- PRO 9.50 .0 10.0 6.0 .000 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD 10 FT/H 4 1 68 4 2 53.9 First Name Min Max Mean Nsam Reading DEPT 9410.5 9625.5 9518 431 9410.5 ROP 7.23 1134.28 56.0687 431 9410.5 Last Reading 9625.5 9625.5 First Reading For Entire File .......... 9410.5 Last Reading For Entire File ........... 9625.5 File Trailer Service name ............. STSLIB.007 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.008 Physical EOF File Header Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 9600.0 9646.5 ROP 9626.0 9675.0 $ LOG HEADER DATA DATE LOGGED: 03-SEP-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 9675.0 TOP LOG INTERVAL (FT) : 9627.0 BOTTOM LOG INTERVAL (FT): 9675.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 91.7 MAXIMUM ANGLE: 93.4 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: TOOL NUMBER NGP SPC 239 4.550 4.6 FLO- PRO 9.50 .0 10.0 MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OKM~)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 6.0 .000 .000 .000 ,000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 11 AAPI 4 1 68 4 2 GR MWD 11 AAPI 4 1 68 8 3 ROP MWD 11 FT/H 4 1 68 12 4 53.9 First Name Min Max Mean Nsam Reading DEPT 9384 9675 9529.5 583 9384 GR 31.64 183.37 70.4711 432 9384 GR 57.84 78.9 65.4931 94 9600 ROP 24.59 783.26 79.5697 99 9626 Last Reading 9675 9599.5 9646.5 9675 First Reading For Entire File .......... 9384 Last Reading For Entire File ........... 9675 File Trailer Service name ............. STSLIB.008 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.009 Physical EOF File Header Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.008 Comment Record FILE HEADER FILE NUMBER: 9 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 12 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9647.0 ROP 9675.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXI MUMA/qGLE: STOP DEPTH 9877.5 9904.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/S): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 04-SEP-97 MSC 1.32 NGP 5.74, DEP MEMORY 9905.0 9675.0 9905.0 92.1 98.8 TOOL NUMBER NGP SPC 239 4.550 4.6 FLO-PRO 9.50 .0 9.4 6.7 .000 MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL ~ATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame-Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .000 .000 .000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 12 AAPI 4 1 68 4 2 ROP MWD 12 FT/H 4 1 68 8 3 58.6 First Name Min Max Mean Nsam Reading DEPT 9647 9904.5 9775.75 516 9647 GR 57.88 137.16 81.1199 462 9647 ROP 16.14 3096 117.67 459 9675.5 Last Reading 9904.5 9877.5 9904.5 First Reading For Entire File .......... 9647 Last Reading For Entire File ........... 9904.5 File Trailer Service name ............. STSLIB.009 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.010 Physical EOF File Header Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.009 Comment Record FILE HEADER FILE NUMBER: 10 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 13 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9878.0 ROP 9905.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 9916.0 9943.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMI~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: 05-SEP-97 MSC 1.32 NGP 5.74, DEP MEMORY 9946.0 9905.0 9946.0 94.2 95.0 TOOL NUMBER NGP SPC 184 4.550 476 FLO-PRO 9.50 .0 9.0 6.4 .000 .000 .000 .000 60.9 MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR. FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEFT FT 4 1 68 0 1 GR MWD 13 AAPI 4 1 68 4 2 ROP MWD 13 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEFT 9878 9943.5 9910.75 132 9878 GR 62.8 74.92 66.8431 77 9878 ROP 17.12 52.22 28.2732 78 9905 Last Reading 9943.5 9916 9943.5 First Reading For Entire File .......... 9878 Last Reading For Entire File ........... 9943.5 File Trailer Service name ............. STSLIB.010 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.011 Physical EOF File Header Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.010 Comment Record FILE HEADER FILE NUMBER: 11 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 14 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 9925.5 ROP 9944.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (PT): TOP LOG INTERVAL (PT): BOTTOM LOG INTERVAL (PT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10053.0 10080.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OR-MM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 05-SEP-97 NSC 1.32 NGP 5.74, DEP MEMORY 10080.0 9946.0 10080.0 94.8 98.9 TOOL NUMBER NGP SPC 184 4.550 4.6 FLO-PRO 9.60 .0 9.0 5.8 .000 .000 .000 .000 65.6 .3 REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 14 AAPI 4 1 68 4 2 ROP MWD 14 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 9925.5 10080 10002.8 310 9925.5 GR 63.73 90.97 72.8283 256 9925.5 ROP 20.67 3217.1 325.23 273 9944 Last Reading 10080 10053 10080 First Reading For Entire File .......... 9925.5 Last Reading For Entire File ........... 10080 File Trailer Service name ............. STSLIB.011 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.012 Physical EOF File Header Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 'Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.011 Comment Record FILE HEADER FILE NUMBER: 12 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 15 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10053.5 ROP 10080.5 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 10467.5 10500.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 07-SEP-97 MSC 1.32 NGP 5.74, DEP MEMORY 10501.0 10080.0 10501.0 87.3 97.0 TOOL NUMBER NGP SPC 184 4.550 4.6 FLO-PRO 9.60 .0 9.0 5.0 .000 .000 .000 .000 60.9 .3 Logging Direction ................. 'Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max~ frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 15 AAPI 4 1 68 4 2 ROP MWD 15 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10053.5 10500.5 10277 895 10053.5 GR 59.47 179.44 109.267 829 10053.5 ROP 16.79 2196 147.51 841 10080.5 Last Reading 10500.5 10467.5 10500.5 First Reading For Entire File .......... 10053.5 Last Reading For Entire File ........... 10500.5 File Trailer Service name ............. STSLIB.012 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.013 Physical EOF File Header Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.012 Comment Record FILE HEADER FILE NUMBER: 13 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 16 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 10471.0 10567.0 ROP 10501.0 $ LOG HEADER DATA DATE LOGGED: S O FTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2. 042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: 10597.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OPhMI~) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 07-SEP-97 MSC 1.32 NGP 5.74, DEP MEMORY 10600.0 10501.0 10600.0 88.6 93.3 TOOL NUMBER NGP SPC 239 4.550 4.6 FLO-PRO .00 .0 .0 0 .0 .000 .000 .000 .000 .0 .3 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 16 AAPI 4 1 68 4 2 ROP PrWD 16 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 10471 10597.5 10534.2 254 10471 GR 66.98 90.01 76.3151 193 10471 ROP 43.66 3225.51 258.04 194 10501 Last Reading 10597.5 10567 10597.5 First Reading For Entire File .......... 10471 Last Reading For Entire File ........... 10597.5 File Trailer Service name ............. STSLIB.013 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB,014 Physical EOF File Header Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.013 Comment Record FILE HEADER FILE NUMBER: 14 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 17 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10570.0 ROP 10598.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE STOP DEPTH 11039.0 11072.0 09-SEP-97 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREH©LE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 MSC 1.32 NGP 5.74, DEP MEMORY 11072.0 10600.0 11072.0 87.3 94.3 TOOL NUMBER NGP SPC 239 4.550 4.6 FLO-PRO 9.50 .0 9.2 5.6 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 17 AAPI 4 1 68 4 2 ROP MWD 17 FT/H 4 1 68 Name Min Max Mean DEPT 10570 11072 10821 GR 56.95 89.82 71.2456 ROP 18.58 3636 130.65 Nsam 1005 939 949 First Reading 10570 10570 10598 Last Reading 11072 11039 11072 First Reading For Entire File .......... 10570 Last Reading For Entire File ........... 11072 File Trailer Service name ............. STSLIB.014 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.015 Physical EOF File Header Service name ............. STSLIB.015 Service Sub Level Name... Version Nunlber ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.014 Comment Record FILE HEADER FILE NUMBER: 15 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 18 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11039.5 11259.5 ROP 11072.5 11292.5 $ LOG HEADER DATA DATE LOGGED: 10-SEP-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11293.0 TOP LOG INTERVAL (FT) : 11072.0 BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHM}4) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 11293.0 87.4 91.3 TOOL NUMBER NGP SPC 234 4.500 4.5 FLO-PRO 9.50 .0 9.2 5.5 .000 .000 .000 .000 68.0 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 18 AAPI 4 1 68 4 2 ROP MWD 18 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading Last Reading DEPT 11039.5 11292.5 11166 507 GR 64.35 745.5 90.0582 441 ROP 22.62 2069.76 111.633 441 11039.5 11039.5 11072.5 11292.5 11259.5 11292.5 First Reading For Entire File .......... 11039.5 Last Reading For Entire File ........... 11292.5 File Trailer Service name ............. STSLIB.015 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.016 Physical EOF File Header Service name ............. STSLIB.016 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.015 Comment Record FILE HEADER FILE NUMBER: 16 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 19 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11260.0 11616.0 ROP 11293.0 11647.0 $ LOG HEADER DATA DATE LOGGED: 12-SEP-97 SOFTWARE SURFACE SOFTWARE VERSION: MSC 1.32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 11649.0 TOP LOG INTERVAL {FT): 11293.0 BOTTOM LOG INTERVAL (FT): 11649.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMITM ANGLE: 89.1 MAXIMUM ANGLE: 97.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMS4)AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 TOOL NUMBER NGP SPC 239 4.500 4.5 FLO- PRO 9.50 .0 9.0 5.9 .000 .000 .000 .000 70.3 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 19 AAPI 4 1 68 4 2 ROP MWD 19 FT/H 4 1 68 8 3 First Name Min Max Mean Nsam Reading DEPT 11260 11647 11453.5 775 11260 GR 39.87 174 67.303 713 11260 ROP 18.12 1179.44 87.8756 709 11293 Last Reading 11647 11616 11647 First Reading For Entire File .......... 11260 Last Reading For Entire File ........... 11647 File Trailer Service name ............. STSLIB.016 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.017 Physical EOF File Header Service name ............. STSLIB.017 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.016 Comment Record FILE HEADER FILE NUMBER: 17 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 22 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11616.5 11737.0 ROP 11647.5 11770.5 $ LOG HEADER DATA DATE LOGGED: 14-SEP-97 SOFTWARE SURFACE SOFTWTkRE VERSION: MSC 1_32 DOWNHOLE SOFTWARE VERSION: NGP 5.74, DEP 2.21/2.042/2.17 DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT) : 11772.0 TOP LOG INTERVAL (FT) : 11649.0 BOTTOM LOG INTERVAL (FT): 11772.0 BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG MINIMUM ANGLE: 88.2 MAXIMUM ANGLE: 89.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL G~ PROBE $ BOREHOLE 7kND CASING DATA TOOL NUMBER NGP SPC 320 OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 4.500 4.5 FLO-PRO 9.50 .0 9.1 5.4 ,000 .000 .000 ,000 .3 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 GR MWD 22 AAPI 4 1 68 4 2 ROP MWD 22 FT/H 4 1 68 8 _ 3 70.3 First Name Min Max Mean Nsam Reading DEPT 11616.5 11770.5 11693.5 309 11616.5 GR 44.77 574.27 100.357 242 11616.5 ROP 37.82 868.85 93.7205 247 11647.5 Last Reading 11770.5 11737 11770.5 First Reading For Entire File .......... 11616.5 Last Reading For Entire File ........... 11770.5 File Trailer Service name ............. STSLIB.017 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/10/27 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.018 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/10/27 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/10/27 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
