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192-149
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. I C~,~.. t?q File Number of Well History File PAGES TO DELETE Complete RESCAN Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED · [] Logs 'of various kinds [] Other COMMENTS: Scanned by: Dianna Vincent Nathan Lowell [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: /si RECEIVED STATE OF ALASKA C�EiR .1 4 2�� ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETIO 11 RE••MPLETION REPORT AND LOG6t0GCC la. Well Status: 0 Oil 0 Gas 0 SPLUG 0 Oth,r V Abandoned ! uspended lb. Well Class LOAAC .1 q 5 .; OAAC 25.110 0 Exploratory 0 Stratigraphic 12 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other ► - '' o.of Completions Zero ' .®Development 0 Service 2. Operator Name: 5. Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 2/17/2014- • 192-149 • 313-338 • 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 1/24/1993 • 50-029-22325-00-00 ' 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 2/9/1993 . PBU 09-50 • 1728' FSL,6'FEL, Sec.02,T1ON, R15E, UM ' Top of Productive Horizon: 8. KB(ft above MSL): 55 . 15.Field/Pool(s) 264' FNL,4971'FWL, Sec. 12,T1ON, R15E, UM GL(ft above MSL): 19.7' , Prudhoe Bay/Prudhoe Bay - Total Depth: 9.Plug Back Depth(MD+TVD) 381'FNL,5193'FWL, Sec. 12,T1ON, R15E, UM • 6931' 5926'• 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 718364 " y- 5943195' Zone- ASP4 •11212' 9222' ' ADL028327 ' TPI: x- 723398 y- 5941351 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 723623 y- 5941241 Zone- ASP4 None 18. Directional Survey: ❑Yes ®No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MSFL/DLL/LDT/CNL/GR N/A 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 32' 110' 32' 110' 30" 281 cu ft Arcticset 13-3/8" 68# L-80 32' 3978' 32' 3723' 16" 2927 cu ft CS III/478 cu ft Class'G' 9-5/8" 47 L-80 28' 10738' 28' 8821' 12-1/4" 1462 cu ft Class'G' 7" 29# 13Cr80 10584' 11212' 8692' 9222' 8-1/2" 97 cu ft Class'G' 24. Open to production or injection? 0 Yes ®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): ) 5-1/2", 17#x 4-1/2", 12.6#, 8352'- 10593' 10525'/8644' 13Cr80 ��l/�� // 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. /LE s tc,.lilcr-a fINAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No - • '-"`"; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED SCANNED APR 2 5 2014rx `",,z See Attached Fb"Mr) t r 27. PRODUCTION TEST Date First Production -W, ., 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 ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. None RBDMS APR 17 206 29. GEOLOGIC MARKERS(List all formations ar kers encounter 30. FORMATION TESTS NAME MD ND Well Tested? I]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 10744' 8826' None . Zone 2 10778' 8855' Base of Sadlerochit 11070' 9102' • 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: John Rose,564-5271 Email: John.G.Rose@bp.com Printed Name: Title: Drilling Technologist Joe Lastufk J Signature: Phone 564-4091 Date:.3II4'/3/1441+- 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: 09-50 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used - 10746' 29 Bbls Class 'G' - 10650' 74 Bbls Class 'G' 10507' Tubing Cut 10080' Tubing Cut 8352' Tubing Cut & Pulled 9675' 65 Bbls Class 'G' 6952' EZSV 6931' Set Whipstock 09-50, Well History (Pre-Rig Sidetrack) Date Summary 12/03/13 T/I/O=SSV/1060/0+,Temp=Sl. PPPOT-T(PASS), PPPOT-IC (PASS). Pre RST. PPPOT-T: Stung into test void(100 psi), bled void to 0 psi. Functioned LDS all moved freely(1",450 lb/ft). Pumped through void, good returns. Pressured test void to 5000 psi for 30 min test, lost 0 psi in 15 min, lost 0 psi in second 15 min(PASS). Bled void to 0 psi. PPPOT-IC: Stung into test void (500 psi), bled void to 0 psi. Functioned LDS,all moved freely(1",450 lb/ft). 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. 12/08/13 T/1/O. SSV/1280/0.Temp.=SI. IA FL(Coil request).AL disconnected. IA FL @ surface. SV,WV,SSV=C. MV=O. IA&OA=OTG. NOVP.2130 hrs. 12/08/13 CTU#3 w/1.75"CT(CTV=30.7). Objective-Pre-RST P&A MIRU. 12/09/13 CTU#3 w/1.75"CT(CTV=30.7). Objective-Pre-RST P&A. Continued from 12/8/13. Complete RU. RIH to 5000'with 2.25"BDJSN cement nozzle while L&K. Drain hose froze/no returns to tank. Decision to POOH and fix frozen drain hose. RIH. L&K and underbalance w/diesel complete. Continue RIH.At 6860', reel swivel body started leaking. Close inner reel valve and POOH to change out reel swivel. RIH. 12/10/13 CTU#3 w/1.75"CT(CTV=30.7). Objective-Pre-RST P&A. RIH w/2.25" BDJSN cement nozzle.Tag PBTD. Correct to ELMD of 10,030'(obtained from Slickline tag). PUH 10'to 10,020'and paint while coil flag. PUH above perfs to 10,640'and establish baseline injectivity= 146 psi @ 1.0 bpm. Baseline static WHP= 115 psi. Cementers pump 8 bbl fresh water spacer,29 bbl 15.8 ppg cement:5 bbl neat,9 bbl w/ 5 ppb aggregate, 15 bbl neat, 33.7 fresh water displacement. Let 2 bbl exit nozzle,then begin PUH and laying in cement 1:1. Returns slowed considerably after 10 bbl returned,then dropped off to a trickle after 11 bbl returned. Park coil-100'above perfs. Close choke and attempt to build WHP; no success.After all cement exits nozzle, PUH to safety at 9600'. Unsuccessful at achieving bump/squeeze. Decision made to drop ball and jet/contaminate from top of perfs 10,746'up to 10,400.While POOH observed severe wear on coil. Checked WT w/accoustic meter. WT below minimums for 1.75"0.134 Coil. Decision to swap reels before proceeding. Blow down reel w/N2. RDMO.Will return to well following reel swap and maintenance. 12/15/13 CTU#3 1.75"(CTV=33.2 bbls, 15560')Obj: Drift&log w/GR/CCL, P&A. Travel to location and begin rigging up. 12/16/13 CTU#3 1.75"(CTV=33.2 bbls, 15560')Obj: Drift&log w/GR/CCL, P&A. Complete rig up. Drifted new coil w/1.25" ball.Weekly BOP test complete. RU PDS memory GR/CCL. 12/17/13 CTU#3 1.75"(CTV=33.2 bbls, 15560')Obj: Drift&log w/GR/CCL, P&A. RIH w/PDS memory GR/CCL. Tag TD @ 10857.5'down/10849'up. Confirmed tag three times. PUH 10'and paint flag @ 10839' (blue/green). Log OOH @ 45 fpm up to 10000'. POOH. Confirm good data w/PDS(+34'correction). MU cement toolstring w/2.25" BDJSN. RIH&tag @ 10862'uncor. PUH to flag and correct 10851 uncor/10862cor. Load well w/KCI and underbalance w/264 bbls diesel. Page 1 of 3 09-50, Well History (Pre-Rig Sidetrack) Date Summary 12/18/13 CTU#3 1.75"(CTV+33.2bbI, 15560')Obj Drift&log w/GR/CCL, P&A. RIH w/PDS memory GR/CCL.Tag TD @ 10857.5'down/10849'up. Confirmed tag three times. PUH 10'and paint flag @ 10839' (blue/green). Log OOH @ 45 fpm up to 10000'. POOH. Confirm good data w/PDS(+34'correction). MU cement toolstring w/2.25" BDJSN. RIH&tag @ 10862'uncor. PUH to flag and correct 10851 uncor/10862cor. Load well w/KCI and underbalance w/264 bbls diesel. Pump 10 bbl water spacer and and 74 bbls class G 15.8ppg cement. Lay in cement up to 10640'. Shut choke and pump until achieving a 500 psi bump over WHP. Cut cement,displace with water and lay in coil volume of cement. Est TOC @ 9300'. PUH and squeeze. Maintained 1500 psi squeeze pressure for 40 min.Total of 41 bbls behind pipe. Clean out cement to 10640'. Circulate and POOH at 80%. FP tubing to 2500'with 60/40. Trap 700 psi WHP. 12/21/13 TAGGED TOP OF CEMENT AT 10,632'SLM W/2.25"CENT, S.BAILER(bailer full of cement). 12/22/13 DRIFTED TO 5-1/2"x 4-1/2"XO @ 10,534'SLM (10,540'MD)W/4.43"CENTRALIZER(no issues). 12/23/13 T/I/0=940/1180/0. MITT**FAILED**to 3500 psi/MIT IA**FAILED**to 3500 psi. MIT OA**FAILED** (Post P&A) Pumped 12.72 bbls of crude into IA to reach test pressure on TBG and IA using jumper hose to equalize pressure. (See Log) 15 min T lost 38 psi/30 min T lost 32 psi.Total loss of 70 psi in 30 mins. 15 min IA lost 70 psi/30 min IA lost 58 psi.Total loss of 128 psi in 30 mins. Repressure T and IA with .42 bbls of crude. 15 min T lost 30 psi/30 min T lost 27 psi.Total loss of 57 psi in 30 mins.30 min IA lost 64 psi/30 min IA lost 52 psi.Total loss of 116 psi in 30 mins. Bled TxIA back to starting psi. Bled back—9 bbls. Pumped a total of 40 bbls crude down OA. Established LLR with 12 bbls for 7 mins. LLR=2 bpm @ 1900 psi. DSO notified of well status and tree valve positions as follows: SV,WV,SSV=closed. MV= open. IA and OA open to gauges. FWHP=930/1216/0. 12/26/13 T/I/O=894/1255/10.Temp=SI. MIT-T to 3500 psi**PASS**, MIT-IA to 3500 psi(Pre Sidetrack). No AL. Pumped 2.65 bbls diesel down Tbg to achieve test pressure(3511/1403/29).TP lost 30 psi in 1st 15 mins & 15 psi in 2nd 15 mins for a total of 45 psi in 30 min test. Bled Tbg from 3466 psi to 1000 psi (3.17 bbls) in 10 mins. Made(2)attempts at MIT-IA to 3500 psi, both failed. Established LLR of..36 gals/min @ 3500 psi on IA.Attempted CMIT-TxIA to 3500 psi.Tbg/IA lost 29/51 psi in 1st 15 mins& 19/39 psi in 2nd 15 mins for a total of 48/90 psi in 30 min test. Bled Tbg/IA from 3461/3424 psi to785/785 psi. Job complete. Final WHPs=785/785/22. 12/28/13 INITIAL T/I/O=0/600/0 PSI. STAND BY FOR WIND. RIH W/CCUTEMP/ARCHER NOISE TOOL. 12/29/13 RIH W/CCLlTEMP/ARCHER NOISE TOOL, BASELINE PASS TO LRS INCREASE IAP TO 3500 PSI/INCREASED TBG TO 1500 PSI W/TRIPLEX. FOUND LEAK AT 10333.7'. PERFORMED REPEAT AND STOP COUNT OVER LEAK. BLED PRESSURE OFF TBG AND LEAK SIGNAL ATTENUATES. PRESSURE UP TBG TO 3500 PSI/IA TO 1500 PSI, NO LEAK OBSERVED. BLED TBG TO 1500 PSI/INCREASE IAP TO 3500 PSI, CONTINUE LOG OUT AT 30 FPM. NO OTHER LEAKS FOUND. LRS PUMPED A TOTAL OF 14.1BBLS. LRS PERFORM PRESSURE FALL OFF TEST. WELL SHUT-IN UPON DEPARTURE, DSO NOTIFIED. FINAL T/I/0=1000/250/0 PSI. 12/29/13 T/I/0=300/625/0 Temp=Sl Assist E-Line(PRE SIDETRACK) Pumped 7 bbls of diesel down IA for LDL log. Bled back—4 bbls of diesel. Pumped an additional 7 bbls of diesel down IA to assist E-Line for LDL log. Performed a 1 hour Leak Off test on IA to 3600 psi, IA lost 134 psi in 1 hr test. Bled back-7 bbls. SV,WV,SSV=E-Line IA,OA=OTG FWHP=1000/492/0 E-Line on well upon departure. Page 2 of 3 09-50, Well History (Pre-Rig Sidetrack) Date Summary 01/03/14 INITAL T/I/O=0/350/0, SSV=CLOSED. RAN IN W/4.15"O.D. JET CUTTER&CUT 5-1/2"TBG @ 10,507' MD. TIED INTO TBG TALLY DATED 2/12/1993. GOOD INDICATION AT SURFACE OF CUT TBG PRESSURE FELL OFF&IA PRESSURE CAME UP CONFIRMING COMMUNICATION AFTER CUT. LEFT WELL SHUT-IN&SECURE ON DEPARTURE-NOTIFIED DSO OF OF WELL CONDITION. FINAL T/I/O=200/400/0. 01/11/14 T/I/O=241/769/0.Temp=S/I. (Sidetrack)Spear into OA w/5 bbls neat meth followed by 40 bbls diesel to prove injectivity. Pump 402 bbls 9.8 brine/KI3869 inhibitor down OA to load OA. Freeze protect OA w/6 bbls diesel. Spear into TBG w/5 bbls neat meth followed by 870 bbls of 9.8 NaCL. Pumped 12 bbls dsl down TBG—U-tube—w/IA. 01/12/13 Continued U-tube, FP all surface lines/choke skid. Final valve positions SV/WV=closed, MV, SSV=open, CV's=OTG. FWHP 423/427/0. 01/12/14 T/I/O=450/350NAC.Temp=SI. Bleed WHPs to 0 psi (RWO prep). No AL. Integral installed on IA.T& IA FLs @ surface. Bled IA to slop trailer from 350 psi to 0 psi in 10 minutes(-3 bbls)returned.TP tracked to 0 psi. Monitor for 30 minutes.TP&IAP remained at 0 psi. Job complete. Final WHPs=0/ONAC. SV, WV, SSV=C. MV=0. IA, OA=OTG. 11:59. 01/13/14 T/I/O=0/ONac.Temp=SI.WHPs(Pre Rig).AL disconnected.WHPs unchanged overnight. SV,WV, SSV=C. MV=0. IA, OA=OTG. 16:00 hrs. 01/13/14 T/I/O=0/ONac.Temp=SI.WHPs(Pre Rig).AL disconnected.WHPs unchanged since day shift. SV,WV, SSV=C. MV=0. IA, OA=OTG. 23:30. 01/13/14 T/1/O=S/INACNAC.Verified VR plugs on both companion side IA and OA flanges.Torqued flanges and Pt'd VR plugs. (See log). 01/24/14 T/I/O=0/0+/vac.Temp=SI.WHP's(Pre RWO). No wellhouse,AL,flowline or scaffolding. SV,WV, MV _?. SSV=C. IA,OA=OTG. NOVP. 1515 hrs. 01/28/14 T/1/O=S1/0/0 Piggybacked IA&OA valves with Temp.valves#3+ FWP's SI/0/0 see log for details. 01/29/14 T/I/O=0/0/0 Temp=Sl Pressure up TBG for Valve Crew(Pre-RWO) Pump.6 bbls meth to reach 300 psi on TBG/IA. FWHP=300/300/0 WV, SV, SSV, MV=CLOSED CV's=OTG. 01/30/14 T/I/0=300/300/0.Verified barriers LTI (PASSED). Set 6"J BPV#419.Verified LTI of plug and MV (PASSED). Removed upper tree and installed Dryhole tree temp valve#27.Torqued to API specs. PT'd dryhole tree(PASSED). RDMO. Final WHP's BPV/300/0. Page 3 of 3 i I 1 I North America-ALASKA-BP Page 1 of ✓ Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:1/24/1993 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To His 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 2/2/2014 00:00 - 04:00 4.00 1 RIGD P PRE SKID FLOOR -PJSM 1 -PREP TO SKID RIG FLOOR 04:00 - 06:00 2.00 RIGD P PRE LAY DERRICK OVER -SECURE PIPE CAT -PREP TO LAY DERRICK OVER -LOWER DERRICK,MAST WT 383K -RIG DOWN MUD MODULE WALK WAYS, 1 JACK UP MUD MODULE -CRAB AWAY FROM DRILLERS MODULE SET ' DOWN AND TURN TIRES -MOBILIZE RIG 06:00 - 18:00 12.00 MOB P PRE RIG MOVE -MOVE RIG FROM A-PAD THROUGH D-PAD .J — — -- TO SPINE ROAD 18:00 - 20:30 2.50 1 MOB P . PRE MOVE RIG -MOVE RIG FROM GAURD SHACK TO SAG RIVER ROAD IN FRONT OF CH2MHILL YARD 20:30 - 21:30 1.00 MOB N RREP PRE CODE-8 -REPLACE FAILED PRESSURE RELIEF VALVE __— ON REAR TIRE IN MUD MODULE 21:30 - 00:00 2.50 MOB P PRE MOVE RIG ' -MOVE RIG FROM SAG RIVER ROAD TO DS-17 2/3/2014 00:00 - 03:00 3.00 MOB P PRE RIG MOVE -MOVE RIG FROM DS-17 TO DS-09 103:00 - 06:00 I 3.00 MOB P PRE RIG MOVE -STAGE MUD MODULE ON PAD 06:00 - 09:00 3.00 MOB P PRE RIG MOVE -SPLIT DRILLERS MODULE AND UTILITY MODULE -PREPARE DRILLERS MODULE FOR RIG MOVE 09:00 - 12:00 3.00 MOB P PRE RIG MOVE -MOVE DRILLERS MODULE FROM A-PAD THROUGH D-PAD TO SPINE ROAD SIMOPS: -PICK DUMMY WELLHOUSE WITH CRANE -MOBILIZE TO DS-09 12.00 - 18:00 6.00 MOB P 1 PRE RIG MOVE -MOVE DRILLERS MODULE ALONG SPINE , ROAD TO INTERSECTION WITH OXBOW SIMOPS: -SET DUMMY WELLHOUSE ON 09-50A -LAY MATS FOR DRILL MODULE ON 09-50A 18:00 - 00:00 6.00 MOB P PRE RIG MOVE -MOVE DRILLERS MODULE ALONG SPINE 1 ROAD FROM OXBOW TO SAG RIVER ROAD 2/4/2014 00:00 - 12:00 12.00 i MOB P I PRE RIG MOVE I I -MOVE SUB FROM SAG RIVER ROAD TO DS-09 '-STAGE SUB ON PAD -LOAD DOCKS AND MOVE TO DS-09 Printed 3/3/2014 12:34:57PM r North America-ALASKA-BP Page 2 uta' Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:1/24/1993 12:00:00AM 'Rig Release: Rig Contractor:PARKER DRILLING CO. I UWI:500292232500 Active datum:09-50A Plan 13 ort66.80usft(above Mean Sea Level) Date From-To Hrs Task Code - NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 - 15:00 3.00 MOB P PRE 1 RIG MOVE -SPOT SUB OVER WELL -LOAD DOCKS AND MOVE TO DS-09 RIG UP SUB AND PITS -STOW CURTAIN IN PIPE SHED -INSTALL FLOOR PLATES AT SUB/PITS I ,INTERCONNECT -INSTALL ROOF PLATES AT SUB/PITS INTERCONNECT 15:00 - 21:00 6.00 MOB P PRE RIG MOVE -MOVE MOTORS F/A-PAD T/PUMP STATION 1#1 -LOAD DOCKS AND MOVE TO DS-09 CONTINUE RIG UP SUB AND PITS -CONNECT ELECTRIC UTILITIES I -M/U HIGH PRESSURE MUD LINES I -M/U LOW PRESSURE UTILITY LINES r 21:00 - 00:00 3.00 MOB P PRE RIG MOVE • •-MOVE MOTORS -FROM PUMP STATION#1 TO W.GUARD SHACK -ADJUST KOOMEY PRE-CHARGE TO 1050 PSI 2/5/2014 00:00 - 03:00 3.00 MOB P PRE RIG MOVE I -MOVE MOTORS -FROM GUARD SHACK TO ICE ROAD • —i- ENTRANCE 03:00 - 06:00 • 3.00 MOB P PRE RIG MOVE 1 -MOVE MOTORS TO DS-17 06:00 - 09:00 3.00 MOB P PRE RIG MOVE I -MOVE MOTORS F!DS-17 T/DS-09 09:00 - 12:00 3.00 MOB P PRE RIG MOVE I -ORIENT MOTORS PARALLEL TO SUB -SET DOWN,REMOVE TIE RODS,TURN • 'AXLES I CRAB MOTORS INTO SUB • -DROP SUPPORT COLUMNS -CONNECT UTILITY LINES • -CONNECT ELECTRICAL 12:00 - 14:30 2.50 RIGU P PRE RIG UP -CONNECT FLOW LINE -CONNECT GAS BUSTER LINE -- — -CONTINUE CONNECTING UTILITY LINES 14:30 - 16:00 1.50 RIGU P PRE RIG UP -PJSM FOR RAISING DERRICK -COMPLETE PRE-RASING CHECKLIST -RAISE DERRICK,PU WT 533K OFF 'HEADACHE • 16:00 - 18:00 2.00 RIGU P PRE RIG UP -PJSM FOR SKIDDING -SKID FLOOR • -SKID CATTLE CHUTE -INSTALL HANDRAILS AND WALKWAYS NOTE:E-MAIL FROM AOGCC(L.GRIMALDI) -RECEIVED @ 16:31 HRS,2/05/2014 -UPCOMING BOP TEST WITNESS WAIVED Printed 3/3/2014 12.34'57PM North America-ALASKA-BP Page 3 oge Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 ' End Date. X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date(Tme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 18:00 - 23:30 5.50 RIGU • P PRE RIG UP -PJSM FOR BRIDLING DOWN AND DRESSING OUT RIG FLOOR 1 -BRIDLE DOWN AND DRESS OUT DERRICK -TIGHTEN KELLY HOSE TO TOP DRIVE,TIE I I BACK LINES -RIG UP STABBING BOARD,RIG UP FORUM CRANE,IDM CALIBRATE BLOCKS AND CHECK C.O.M • -RU MUD LINES,CEMENT LINE,BLEED OFF LINE -CHECK 0-RINGS ON HAMMER UNIONS I j PRIOR TO M/U -CALIBRATE PVT SENSORS 23:30 - 00:00 I 0.50 RIGU P PRE RIG EVAC DRILL -HELD H2S/EVACUATION DRILL -MUSTER CREW AT SIGN IN TRAILER • -AAR • -ALL PARTIES ACCOUNTED FOR -GOOD CREW RESPONSE I ALL THIRD PARTY PERSONNEL MUSTERED 2/6/2014 00:00 - 03:30 3.50 • RIGU P PRE PULL BPV , -BRING DSM LUBRICATOR TO RIG FLOOR I -PULL TREE CAP AND RIG UP LUBRICATOR -PJSM -TEST LUBRICATOR 250 PSI/3500 PSI,5 MIN /5 MIN I -GOOD TEST -PULL BPV,RIG DOWN LUBRICATOR i NOTE: -RIG ACCEPT AT 00:01 HRS 03:30 - 05:30 2.00 VVHSUR P DECOMP RIG UP -RIG UP LINES TO CIRCULATE OUT FREEZE PROTECT -RESPOT CUTTINGS BOX -BUILD CONTAINMENT 05:30 - 11:00 5.50 WHSUR P DECOMP CIRCULATE OUT FREEZE PROTECT -PJSM -PRESSURE TEST LINES 250 PSI/3500 PSI,5 MIN/5MIN I I -REVERSE CIRCULATE DIESEL @ 1.5 BPM, 1500 PSI -PUMP DIESEL OUT OF BACK SIDE @ 2 BPM, 450 PSI • -TOTAL DIESEL CIRCULATED OUT:8 BBLS -CIRCULATE SURFACE TO SURFACE @ 4 BPM,430 PSI :SIMOPS: -INSTALL 7"RAMS IN BOP STACK Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 4.x.27 Operation Summary Report Common Wet Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 • End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud DateRme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. I UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 11:00 - 17:00 6.00 WHSUR P DECOMP SET TWC -MONITOR WELL FOR 10 MIN @ GAS BUSTER -R/U LUBRICATOR -TEST 250 PSI/2500 PSI HIGH 5MIN EACH -PJSM -SET TWC WITH LUBRICATOR -TEST TWC 250 PSI/3500 PSI,5 MINI/5MIN FROM ABOVE -GOOD TEST -TEST TWC 250 PSI/2000 PSI,5 MIN/3OMIN FROM BELOW h GOOD TEST I-4.2 BBLS BACK -L/D LUBRICATOR T 17:00 - 00:00 7.00 BOPSUR P DECOMP N/D TREE AND N/U BOP -PJSM -BLOW DOWN AND RIG DOWN ALL LINES -BLEED PRESSURE OFF CONTROL LINES AND VOID 1-N/D TREE -CLEAN AND CLEAR BOP DECK -N/U HIGH PRESSURE RISER -N/U BOP -INSTALL BELL NIPPLE -HOOK UP FLOW LINE AND FILL LINE ON DRIP PAN 2/7/2014 00:00 - 03:00 3.00 BOPSUR P DECOMP N/U BOP ' -FINISH N/U BOP STACK I-M/U 7"TEST JOINT OFFLINE 03:00 - 10:00 7.00 BOPSUR , P DECOMP BOPE TEST -TEST TO 250 PSI/3500 PSI HIGH FOR 5 MIN /5MIN -TEST WITH 7",5.5"&4"TEST JOINTS -ALL TESTS CHARTED -SEE ATTACHED BOP TEST CHARTS i-COMPLETE DRAWDOWN TEST NOTE:E-MAIL FROM AOGCC(L.GRIMALDI) -RECEIVED @ 16:31 HRS,2/05/2014 -TEST WITNESS WAIVED 10:00 - 10:30 0.50 BOPSUR P DECOMP SERVICE RIG 10:30 - 14:00 3.50 BOPSUR N RREP 11.80 DECOMP CODE-8 -SERVICE RIG -REMOVE SAVER SUB AND LOWER IBOP -REINSTALL LOWER IBOP I -INSTALL AND TQ.SAVER SUB -INSTALL FEDDER RINGS AND TQ 14:00 - 18:00 ' 4.00 i BOPSUR P DECOMP BOP TEST • -FINISH TESTING -DOCUMENT CLOSING TIMES,AND ACCUMULATOR TEST R/D -BLOW DOWN AND RIG DOWN TESTING EQUIPMENT -CLEAN AND CLEAR RIG FLOOR 18:00 - 18:30 0.50 1 WHSUR P DECOMP PULL TWC -PJSM 1 I -X/O FOR DUTCH RISER TO LUBRICATOR NOT ON RIG Printed 3/3/2014 12:34:57PM I North America-ALASKA-BP Page 5 oKd+ Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) • Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Tme:1/24/1993 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13©66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)• 1 18:30 - 21:00 2.50 1 WHSUR N WAIT DECOMP CODE-8 -FIND X/O FROM DUTCH RISER TO 1 LUBRICATOR -X/O FOUND ON PARKER RIG 273 21:00 - 23:00 2.00 WHSUR P 1 DECOMP PULL TWC -R/U DUTCH RISER/LUBRICATOR, -TEST 250 PSI/3500 PSI,5 MN/5 MIN I -GOOD TEST -PULLTWC WITH LUBRICATOR R/D LAY DOWN LUBRICATOR AND DUTCH RISER 23:00 - 00:00 1.00 WHSUR P DECOMP PULL TUBING HANGER -PJSM -M/U LANDING JTTO HANGER 2/8/2014 00:00 - 00:30 0.50 PULL P DECOMP PULL HANGER -UNSEAT HANGER I-P/U 213K ' -FILL STACK -MONITOR WELL FOR 10 MIN:STATIC '-PULL HANGER TO FLOOR 00:30 - 01:30 ' 1.00 I PULL P DECOMP CIRCULATE SURFACE TO SURFACE 1-CIRCULATE 6900 STKS -630 GPM,880 PSI 1 SIMOPS: -R/U DOYON CASING -R/U SCHLUMBERGER CONTROL LINE SPOOLER 01:30 - 06:00 4.50 • PULL I P DECOMP PULL 7"COMPLETION -PJSM 1 L/D 1 JT OF 7"TUBING 1 -PULLED TIGHT WITH 25K OVERPULL -NOTIFY DRILLING SUPERINTENDENT AND ODE -DECIDE TO R/U 250 TON ELEVATORS 06:00 - 10:00 4.00 PULL P DECOMP R/U,CIRCULATE&ATTEMPT PULL R/U TIWAND HEAD PIN ON STUMP -CIRCULATE EP MUD LUBE SWEEP(30 BBLS) -CIRCULATE HIGH VIS SWEEP 30 BBLS I I -15 BPM,830 PSI 1 -PULLED OVER 20K INTO TIGHT SPOT L -RETURNS BACK WITH 1 CUP OF PARRAFINS 10:00 - 12:00 2.00 PULL P DECOMP i WORK PIPE THROUGH TIGHT SPOTS -WORK UP TO 315K HOOKLOAD AT 10K I INCREMENTS I -PIPE DID NOT BREAK FREE WITH 53" STRETCH 12:00 - 13:00 1.00 PULL N DPRB 10,478.80 DECOMP WAIT -WAIT ON ORDERS FROM TOWN -MONITOR HOLE FILL 13:00 - 15:00 I 2.00 PULL N i DPRB 10,478.80 DECOMP RIG DOWN AND MOVE CONTROL LINE SPOOLER -CUT AND BAND 1/4"CONTROL LINE 1 _ -PIPE STRETCH TEST TUBING -13",25K Printed 3/3/2014 12:34:57PM I I i North America-ALASKA-BP Page 6 rg22.-7 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:1/24/1993 12:00:OOAM 'Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 t 66.80usft(above Mean Sea Level) Date ! From-To Hrs Task ' Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 18:30 3.50 PULL N DPRB 10,478.80 I DECOMP RIH I -RIH WITH 7"TUBING JT CHANGE OUT SIDE DOOR ELEVATORS TO BX -P/U LANDING JOINT -M/U HANGER,LAND HANGER -RUN 4 LOCK DOWNS -CLEAN AND CLEAR RIG FLOOR 18:30 - 19:30 1.00 7 PULL P DECOMP WAIT ON ORDERS -PLAN FOR RIGGING UP E-LINE AND DSM LUBRICATORS 19:30 - 20:00 0.50 PULL P DECOMP R/U CH2MHILLAND E-LINE LUBRICATORS I -PJSM 20:00 - 21:00 1.00 PULL 1 P DECOMP R/U DSM LUBRICATORS -R/U AND SET TWC -R/D LUBRICATOR AND STAGE OUT 21:00 - 23:00 2.00 PULL P DECOMP SPOT AND STAGE OUT SLB LUBRICATOR AND TRUCKS -PJSM 23:00 - 00:00 1.00 I PULL P DECOMP R/U SCHLUMBERGER LUBRICATOR,AND IEXTENSION 2/9/2014 00:00 - 02:00 2.00 I PULL P DECOMP R/U E-LINE i-R/U E-LINE WITH SLB LUBRICATOR __ -CONNECT LUBRICATOR TO DUTCH RISER 02:00 - 03:30 i 1.50 PULL P DECOMP PRESSURE TEST E-LINE LUBRICATOR -TEST TO 250 PSI/3000 PSI,5 MIN/5MIN -TWO LEAKS ON LDS,RETORQUED AND RE-TEST -TEST GOOD , 03:30 - 04:30 1.00 PULL P DECOMP •R/D -R/D SCHLUMBERGER PRESSURE CONTROL 1-R/U DSM LUBRICATOR AND PRESSURE !TEST 04:30 - 05:00 0.50 I PULL P DECOMP PRESSURE TEST DSM LUBRICATOR • -TEST TO 250 PSI/3000 PSI,5MIN/5MIN -TEST GOOD 05:00 - 06:00 1.00 i PULL P DECOMP R/D -R/D DSM LUBRICATOR -R/U SCHLUMBERGER PRESSURE CONTROL -RIH W/JET CUTTER TO 10080' i 1 NOTE: -1 HR TOSETTWC • '-0.5HRTOR/U DSM -0.5 HR TEST DSM LUBRICATOR •-0.5 HR FOR R/D DSM LUBRICATOR -TOTAL:2.5 HRS 06:00 - 12:00 6.00 PULL P DECOMP CUT TUBING -CUT 5-1/2"TUBING AT 10080' -POOH W/WIRELINE 12:00 - 12:30 0.50 PULL I P T DECOMP R/D -PJSM R/D SCHLUMBERGER PRESSURE CONTROL -L/D DUTCH RISER -P/U LANDING JT -PULL HANGER AND L/0 , I -PULL TUBING -L/D SINGLE OF 7"TUBING • i-PULLED TIGHT AT SAME SPOT Printed 3/3/2014 12:34:57PM • North America-ALASKA-BP Page 7 aP7 Operation Summary Report Common Well Name:09-50AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: IX3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay .Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Tme:1/24/1993 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13©66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations ' (hr) (usft) 12:30 - 13:00 0.50 PULL P DECOMP WAIT _ -WAIT ON ORDERS 13:00 - 18:00 5.00 I PULL P DECOMP R/D -R/0 SHORT BAILS I I -R/U LONG BAILS rt -R/D SLB LUBRICATOR AND RE-HEAD E-LINE 18:00 - 00:00 6.00 PULL P DECOMP R/U -R/U WIRELINE SHEAVES AND STRING WIRE ' LINE -PJSM ON RUNNING FREE POINT W/SLB -CHANGE WIRELINE SHEAVES 2/10/2014 00:00 - 01:00 1.00 PULL 1 P DECOMP R/U E-LINE -CHANGE WIRELINE HEAD TO 0.39"FOR FREEPOINT -INSTALL HEAD PIN ON TOP DRIVE 01:00 - 02:00 1.00 PULL N SFAL 11.80 DECOMP I TROUBLESHOOT SLB SAFETY SWITCH 02:00 - 03:00 1.00 PULL i P DECOMP R/U FREE POINT TOOL -PJSM • -BRING TOOL TO FLOOR AND R/U TO RIH 03:00 - 04:30 1.50 PULL N SFAL 11.80 DECOMP RELOCATE SHEAVE IN DERRICK 04:30 - 08:00 3.50 PULL P DECOMP RIH WITH FREE POINT TOOL 08:00 - 09:00 1.00 PULL N DFAL 11.80 DECOMP TROUBLE SHOOT FREE POINT TOOL 09:00 - 10:30 1.50 PULL N DEAL 3,511.80 DECOMP PULL FREE POINT TOOL 10:30 - 12:30 2.00 PULL N DEAL 3,511.80 DECOMP !RIH WITH FREE POINT TOOL 12:30 - 13:00 0.50 PULL N DEAL 3,511.80 DECOMP 'POH WITH FREE POINT TOOL TO SWAP OUT TOOLS RIH TO 3500'MD -TOOL BAD,POH 13:00 - 14:30 1.50 r PULL N DFAL ' 3,511.80 DECOMP CIRCULATE 1 - 250 GPM,250 PSI -CHANGE OUT FREE POINT TOOL 14:30 - 15:00 0.50 PULL N ' DFAL 3,511.80 DECOMP R/D R/D CIRCULATING HEAD -BLOW DOWN LINES -R/U AND RUN IN NEW FREE POINT TOOL 15:00 - 16:30 i 1.50 • PULL N DFAL 3,511.80 • DECOMP R/U -CALIBRATIE FREE POINT TOOL -RIH 1000',CONFIRM CALIBRATION 16:30 - 22:00 5.50 PULL P DECOMP LOG -PERFORM FREE POINT LOG W/SLB E-LINE I-FOUND STUCK POINT AT 8421'MD,F/ I PARKER 272 RKB -STUCK POINT AT GLM#6 -POH WITH E-LINE • R/D -R/D E-LINE EQUIPMENT 22:00 - 00:00 2.00 PULL P I DECOMP RIH -PJSM '-CHANGE OUT ELEVATORS -M/U LANDING JT -RIH WITH 7"JT AND TUBING HANGER -RILDS ON HANGER I R/U -R/U DUTCH RISER •-REHEAD E-LINE F/0.39"T/0.23"FOR RUNNING JET CUT Punted 3/3/2014 1234.57PM North America-ALASKA-BP Page 8 p1 7 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3 013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 I Spud Date/me:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft)_ 2/11/2014 00:00 - 03:30 3.50 PULL P DECOMP R/U LUBRICATOR •-PJSM -TEST 250 PSI/2600 PSI HIGH,5 MIN/ 5MIN -GOOD TEST -_BLOW DOWN LINES 03:30 - 09:00 5.50 PULL P DECOMP R/U JET CUTTER -M/U TOOL STRING -LOAD EXPLOSIVE M/U LUBRICATOR,TEST QUICK CONNECT RIH,CUT TUBING c 8353'MD SIMOPS 1-M/U STANDS OF 4"DP OFF LINE 09:00 - 09:30 0.50 PULL P 8,364.80 DECOMP R/D DUTCH RISER 09:30 - 10:00 0.50 PULL N DPRB 8,364.80 DECOMP INVESTIGATE DROPPED OBJECT NOTE: 6 OZ ELECTRICAL DUST COVER SUSPENDED BY AIRCRAFT SAFETY CABLE TO THE TOP DRIVE WAS KNOCKED FREE BY THE OFF DRILLERS SIDE TUGGER LINE AND FELL TO THE FLOOR. FOLLOWING A STOP TO OPERATIONS THE I TOP DRIVE WAS INSPECTED AND THE REMAINING 5 DUST COVERS WERE CUT FREE AND REMOVED FROM THE TOP DRIVE. 10:00 - 12:00 2.00 PULL P DECOMP POOH M/U LANDING JOINT TO HANGER -PULL 7"TUBING -F/ 8353'MD T/8163'MD -PULLED TIGHT I-WORKED PIPE TO MAX PULL PU 169K SO 159K 12:00 - 12:30 0.50 PULL P DECOMP WAIT ON ORDERS 12:30 - 15:00 2.50 PULL P DECOMP R/U DUTCH RISER -PJSM,LANDING HANGER M/U LANDING JT TO HANGER DRAIN STACK,LAND HANGER •-R/U DUTCH RISER 15:00 - 17:00 2.00 PULL P DECOMP R/U E-LINE PJSM -R/U SHEAVE ON ELEVATORS -SPOOL OUT E-LINE FOR RE-HEAD SLB REQUIRED TO CHANGE HEADS AFTER j FIRING CUTTER -RE-HEAD LINE -FILL STACK&DUTCH RISER -R/U LUBRICATOR ON DUTCH RISER 17.00 - 19:30 2.50 WHSUR P DECOMP PRESSURE TEST LUBRICATOR -250PSI/2600 PSI, 5 MIN/5 MIN -TESTED AGAINTS WELL BORE -BLOW DOWN TEST EQUIPMENT Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 9 gf.e Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 1 Spud Date/Time:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13©66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 23:00 3.50 PULL P i DECOMP CUT TUBING -PJSM ' -M/U TOOL STRING ' -LOAD EXPLOSIVE -RIH W/E-LINE -CUT TUBING @ 5305'ADJUSTED TO ORIGINAL TALLY -CUT IN FIRST FULL JOINT ABOVE GLM#2 _ 23:00 - 00:00 1.00 PULL P DECOMP POOH WITH E-LINE -R/D LUBRICATOR -STOW LUBRICATOR ON FORUM CRANE -R/D DUTCH RISER 2/12/2014 23:00 - 00:00 1.00 PULL P DECOMP I TEST VBR'S 1-TEST 5-1/2",250 PSI/3500 PSI FOR 5 MIN/ 5 MIN -TEST GOOD -REMOVE 5-1/2"AND INSTALL 4"TEST JOINT -TEST 4",250 PSI/3500 PSI FOR 5 MIN/ 5 i 1MIN TEST GOOD 00:00 - 01:30 - 1.50 PULL P DECOMP PULL HANGER I -PULL DUTCH RISER AND L/D ON SKATE 1-P/U LANDING JOINT AND RIH i M/U TO HANGER PULL HANGER,PU T 125K 01:30 - 05:30 4.00 PULL I P I DECOMP I W POOH -MONITOR WELL FOR 10 MINUTES,STATIC j-BRINE,9.8 PPG IN,9.8 PPG OUT (-POOH ON ELEVATORS F/5305'T/2982' -PU WT 100K,SO WT 100K.AT 3911'MD 05:30 - 08:00 2.50 PULL P DECOMP I CLEAR FLOOR i PJSM MOVE SLB CONTROL LINE SPOOLER OFF FLOOR -R/D E-LINE LUBRICATOR,GREASE HEAD, I BOPE -REMOVE E-LINE EQUIPMENT FROM FLOOR 08:00 - 13:30 5.50 PULL P 1 DECOMP POOH I -MONITOR WELL FOR 10 MINUTES,STATIC -BRINE,9.8 PPG IN,9.8 PPG OUT -POOH ON ELEVATORS F/2982'T/SURFACE -PU WT 35K,SO WT 35K,AT 400'MD i 1 I TOTAL JOINTS RECOVERED 78 JTS 7"TUBING 1 -50 JTS 5-1/2"TUBING -1 CUT JT 5-1/2"TUBING,4.11 FT LONG ITOTAL BANDS RECOVERED-55 EACH 13:30 - 16:00 2.50 PULL I P DECOMP R/D CASING EQUIPMENT -R/D 250 TON SIDE DOOR ELEVATORS -R/D LONG BALES i-REMOVE CSG EQUIPMENT FROM FLOOR 1 -INSTALL SHORT BALES -INSTALL BX ELEVATORS -CLEAN AND CLEAR FLOOR Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 10,AI. Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: 'X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 i Spud Date/me:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 18:00 2.00 PULL P DECOMP CHANGE BOP RAMS -CLOSE BLIND RAMS -REMOVE 7"CASING RAMS -INSTALL 2-7/8" X 5-1/2"VBR'S -M/U 4"TEST JOINT ON TEST PLUG -RIH WITH TEST PLUG -FILL STACK 18.00 - 20:00 2.00 PULL N RREP 11.80 DECOMP TEST VBR'S -TEST 4",250 PSI/3500 PSI FOR 5 MIN/5 'MIN -TEST GOOD -INSTALL 5-1/2"TEST JOINT -UNABLE TO FILL TEST JOINT,RAMS LEAKING BY -FUNCTION RAMS 3 TIMES AND ATTEMPT FILL ALL ATTEMPTS UN-SUCCESSFUL NOTE: CONTACT DRLG.SUPT AND INFORM OF PROBLEM AND PROCEED WITH RAM CHANGE 20:00 - 22:30 2.50 PULL N RREP 11.80 DECOMP 'CHANGE RAMS -VBR'S NOT TESTING ON 5-1/2"TEST JT -CLOSE BLIND RAMS -OPEN UPPER PIPE RAMS,INSPECT VBR'S -RUBBERS DAMAGED ON VBR'S -INSTALL NEW ELEMENTS 22:30 - 23:00 0.50 PULL P DECOMP SERVICE RIG 2/13/2014 00-00 00:30 0.50 PULL P DECOMP INSTALL WEAR RING -M/U WEAR RING RUNNING TOOL -P/U WEAR RING AND RIH -RILDS 4 EACH -L/D TEST JT AND RUNNING TOOL 00:30 - 04:00 3.50 PULL P DECOMP P/U FISHING BHA#1 -PJSM -F/SURFACE T/668' -CHANGE BX INSERTS TO 5" -P/U 4-1/16"SHOULDER TYPE SPEAR -P/U BUMPER SUB,JAR,9 EA.DC, ACCELERATOR -CHANGE BX INSERTS TO 4" -P/U 4"HWDP OFF SKATE 04.00 - 11:00 7.00 PULL P DECOMP RIH WITH FISHING BHA#1 • -P/U 4"DRILL PIPE OFF SKATE -FI 668'T/5,302'MD -FILL PIPE EVERY 2000'MD,125 GPM,130 PSI 11.00 - 11:30 0.50 PULL P DECOMP SPOT EP MUD LUBE PILL AT FISH -PUMP 35 BBL EP PILL -CHASE W/22 BBL 9.8 PPG BRINE,84 GPM, 125 PSI 11:30 - 12:30 1.00 PULL P ' DECOMP ENGAGE FISH -WASH DOWN TO FISH -TOP OF FISH(8j 5334'MD -CIRCULATE 9.8 PPG BRINIE,170 GPM,340 PSI Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 11 DPW Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Time:1/24/1993 12:00:00AM 'Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13©66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) (usft) _ 12:30 - 19:00 6.50 PULL P DECOMP POOH WITH FISH -F/8382'T/3716'MD PU WT 160K,SO WT 138K,WITH FISH ifp 18382'MD PULL TIGHT AT 5073'MD WORK PIPE FREE,STAGE UP OVERPULL -PIPE FREE AT PU Wr400K,240K OVER 19:00 - 21 00 2.00 PULL P DECOMP 'STAND BACK BHA -MONITOR WELL FOR 10 MINUTES,STATIC -L/D 2 JTS,4"HWDP -STAND BACK 3 STDS,4"HWDP -CHANGE BX INSERTS TO 5" -STAND BACK 3 STDS,6-1/2"COLLARS -L/D BUMPER AND JARS 21:00 - 00:00 3.00 PULL P DECOMP L/D TUBING -F/3048'T/1948' PJSM I-REMOVE BX ELEVATOR ROTATOR REMOVE BX ELEVATORS R/U 5-1/2"YT ELEVATORS -R/U POWER TONGS -L/D SPEAR WITH 1 CUT JT OF 5-1/2"TUBING -L/D 5-1/2"TUBING -PU WT 72K,DN WT 72K -25 JTS,1 CUT 35.48'LONG,2 GLM'S 2/14/2014 00:00 - 03:30 3.50 PULL P DECOMP L/D TUBING -F/1948'T/SURFACE -PJSM L/D 5-1/2"TUBING !TOTAL JOINTS L/D -73 JOINTS ,-1 CUT JOINT 35.48'LONG, -1 CUT JOINT 4.43'LONG TOTAL GLM'S L/D,4 03:30 - 04:00 0.50 PULL P DECOMP PRESSURE TEST 9-5/8"CASING -TEST 2500 PSI FOR 10 MINUTES -TEST GOOD 04:00 - 04:30 0.50 PULL P DECOMP CLEAR AND CLEAN FLOOR -PRESSURE WASH EP MUD LUBE OFF FLOOR 04:30 - 06.30 2.00 PULL P DECOMP P/U 8.5"CLEANOUT BHA -REMOVE 5.5"YT ELEVATORS -INSTALL BX ELEVATORS -P/U BULL NOSE,SMOOTH STRING MILL -P/U BUMPER SUB,JAR P/U 9 EACH DC,9 EACH HWDP 06:30 - 14:30 8.00 PULL P DECOMP RIH WITH 8.5"CLEANOUT BHA -F/594'T/5605'MD -P/U 42 EACH SINGLES FROM PIPE SHED -CONTINUE RIH WITH DP OUT OF DERRICK 1-CHECK TORQUE AT EVERY CONNECTION -INSTALL PS-21'S -FILL PIPE EVERY 2000',200 GPM,220 PSI ; + -PU WT112K,SOWT107Ket5605' Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 12 p937 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud DateMme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13©66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:30 - 15:00 0.50 r PULL P DECOMP TAG TIGHT SPOT CO 7373'MD 1-MILL THROUGH TIGHT SECTION 1-340 GPM, 700 PSI -80 RPM,4-9K TORQUE PU 141K,SO 127K,ROT 131K -SHUT DOWN PUMPS AND TD -WORK PIPE THROUGH TIGHT SPOT _ 15:00 - 16:00 1.00 PULL P DECOMP RIH WITH 8.5"CLEANOUT BHA -F/7373'T/7475'MD -CHECK TORQUE AT EVERY CONNECTION TAG UP ON TIGHT SPOT 7475'MD -MILL THROUGH TIGHT SECTION -340 GPM, 720 PSI -80 RPM,4-9K TORQUE -PU 145K,SO 129K,ROT 139K -SHUT DOWN PUMPS AND TD '-WORK PIPE THROUGH TIGHT SPOT 16:00 - 17:00 1.00 PULL P DECOMP RIH WITH 8.5"CLEANOUT BHA -F/7475'T/7851'MD -CHECKING TORQUE OF EVERY CONNECTION TAG UP ON TIGHT SPOT 7851'MD- -MILL THROUGH TIGHT SECTION -340 GPM, 720 PSI -80 RPM,4-9K TORQUE -PU 145K,SO 131K,ROT 139K -SHUT DOWN PUMPS AND TD -WORK PIPE THROUGH TIGHT SPOT 17:00 - 18:00 1.00 PULL P DECOMP RIH WITH 8.5"CLEANOUT BHA -F/7851'T/7955'MD -CHECKING TORQUE OF EVERY CONNECTION • TAG UP ON TIGHT SPOT 7955'MD .1-MILL THROUGH TIGHT SECTION I-340 GPM, 740 PSI -80 RPM,4-9K TORQUE -PU 148K,SO 132K,ROT 143K MILLING PARAMETERS CHANGED -TORQUE INCREASED TO 12-13K -ROP DECREASED TO ZERO NOTE:CONTACTED ODE,DRLG.SUPT AND INFORMED THAT RIG TEAM WOULD LIKE TO 'CEASE MILLING OPERATIONS TO PREVENT DAMAGING CASING,RECEIVED APPROVAL TO POOH TO TEST BOP'S 18:00 - 19:00 1.00 PULL P DECOMP CIRCULATE HIGH VIS SWEEP 1.5X BUS -625 GPM,2100 PSI -RECIPROCATED PIPE -MONITOR FOR GAIN/LOSS -SHUT DOWN MONITOR WELL 10 MIN NOTE:SMALL AMOUNT OF METAL FILINGS ON DITCH MAGNETS,NO SOLIDS AT SWEEP TO SURFACE Printed 3/3/2014 12:34:57PM • North America-ALASKA-BP Page 13aA. Operation Summary Report Common Well Name.09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) • Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Tme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13©66.8ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations _ (hr) _ (usft) _ 19:00 - 19:30 0.50 PULL P DECOMP I CLEAN AND CLEAR RIG FLOOR -PJSM -L/D CASING TOOLS -CLEAR FLOOR 19:30 - 20:00 0.50 PULL P DECOMP PRESSURE TEST CASING -2500 PSI FOR 5 MIN,GOOD TEST 20:00 - 21:00 1.00 PULL P DECOMP POOH ON ELEVATORS FROM 7955'MD TO 7499'MD -BLOW DOWN TOP DRIVE AND MUD LINES -PU 150K,SO 132K AT 7900'MD -MUD WEIGHT:9.8 PPG IN,9.8 PPG OUT 21:00 - 22:30 1.50 PULL P DECOMP RUN RTTS ON 1 STAND OUT OF DERRICK -PJSM -SET RTTS,100K HANG OFF WEIGHT BELOW -RACK BACK STAND IN DERRICK -PULL PS-21 SLIPS 22:30 - 23:00 0.50 PULL P DECOMP TEST RTTS j-250/2500 PSI,5 MIN/5MIN -TEST GOOD 23.00 - 00:00 1.00 PULL P DECOMP TEST BOPE -MU 4"TEST JT I-PULL WEAR RING SET TEST PLUG -MU OFF LINE MANIFOLD 1-FILL STACK AND CHOKE -TEST WITNESS WAIVED BY AOGCC REP JOHN CRISP 2/15/2014 00:00 - 06:00 6.00 PULL P DECOMP TEST ROPE -250 PSI/3500 PSI HIGH FOR 5 MINUTES EACH -TEST WITH 4.0"TEST JOINT -SEE ATTACHED BOP TEST CHART -TEST WITNESS WAIVED BY AOGCC REP JOHN CRISP -R/D TEST JT,TEST PLUG,,BLOW DOWN 06:00 - 09:30 3.50 PULL P DECOMP INSTALL 9 5/8"PACK OFF -PJSM W/FMC -MU PACK OFF RUNNING TOOL TO LANDING JT -RIH W/RUNNING TOOL AND STING INTO PACK OFF LAST TWO LDS EXTREMELY TIGHT NOTE:INFORM ODE OF DIFFICULTLY WITH LDS,POSSIBLE CASING GROWTH,MAKE DECISIOIN TO RILDS AND TEST EXISTING I PACK OFF -TEST PACK OFF TO 5000 PSI FOR 30 MIN, GOOD 09:30 - 10:00 0.50 PULL P DECOMP INSTALL WEAR RING 10:00 - 11:00 1.00 PULL ' P DECOMP RETRIEVE RTTS 11:00 - 12:00 1.00 PULL P DECOMP POOH ON ELEVATORS -MONITOR WELL FOR 10 MINUTES,STATIC -F/ 7614'MD T/ 6200'MD -PU 145K,SO 142KAT7550'MD - Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 14430.27 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud DateTme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) -12:00 - 15:30 3.50 PULL P DECOMP POOH ON ELEVATORS -MONITOR WELL FOR 10 MINUTES,STATIC -F/ 6200'MD T/ 594'MD -PU 132K,SO 128K AT 6200'MD -REMOVE PS-21 SLIPS 15:30 - 17:00 1.50 PULL P DECOMP LAY DOWN BHA -F/ 594'MD T/ SURFACE -MONITOR WELL FOR 10 MINUTES,STATIC -STAND BACK HWDP REMOVE 4"ELEVATOR INSERTS INSTALL 5"ELEVATOR INSERTS -STAND BACK COLLAR'S IN DERRICK -LD MILL ASSEMBLY 17:00 - 17:30 0.50 PULL P DECOMP CLEAN AND CLEAR RIG FLOOR 17:30 - 18:00 0.50 j. PULL P DECOMP SERVICE RIG 18:00 - 00:00 6.00 REMCMT P WEXIT RIH W/4"MULE SHOE -F/SURFACE T/6300'MD -UP WT 108K,DN WT 108K,©6300'MD -P/U 24 JTS FROM PIPE SHED TO 756'MD -RUN OUT OF DERRICK F/756'T/6300'MD 2/16/2014 00:00 - 01:30 1.50 REMCMT P WEXIT RIH W/4"MULE SHOE -F/6300'T/8378'MD -TAG FISH©8378'MD -UPWT131K,DNWr123K,©8378'MD -RUN IN OUT OF DERRICK -POH T/8356'TO SPACE OUT -M/U CEMENT HEAD NOTE:SLB ARRIVED ON LOCATION 1.25 HRS LATE DUE TO VEHICLE ISSUE 01:30 - 02:00 0.50 REMCMT P WEXIT R/U CEMENT HEAD 02:00 - 03:30 1.50 REMCMT P WEXIT CIRCULATE -CBU 1X,170 GPM,235 PSI 03:30 - 05:30 2.00 - REMCMT P WEXIT PRESSURE TEST -PJSM -250 PSI/2500 PSI, 5 MIN/5 MIN -NO LEAKS,PROCEED WITH JOB Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 15 oQd7 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) i Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay I Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/me:1/24/1993 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:30 - 06:30 1.00 REMCMT P WEXIT PUMP BALANCE PLUG PUMP 25 BBL 11.0 PPG MUD PUSH -ICP 373 PSI @ 5.1 BPM,100%RETURN FLOW -FCP 98 PSI @ 3.5 BPM,100%RETURN FLOW li !I PUMP 65 BBL 15.8 PPG CLASS G TAIL 10EMENT -YIELD 1.16 CU.FT/SK,314 SX -ICP 233 PSI @ 4.4 BPM,100%RETURN FLOW -FCP 120 PSI @ 3.2 BPM,100%RETURN FLOW PERFORM DISPLACEMENT -PUMP 6 BBL 11.0 PPG MUD PUSH -PUMP 68 BBL 9.8 PPG BRINE -ICP 60 PSI @ 5.1 BPM,100%RETURN FLOW -FCP 0 PSI @ 1.1 BPM,100%RETURN FLOW -SLOW RATE TO 2.1 BPM,15 PSI PRIOR TO END OF DISPL. CEMENT IN PLACE 06:30 HRS. RIG DOWN CEMENTERS -B/D CEMENT LINE -R/D CEMENT HEAD 06:30 - 07:00 0.50 REMCMT P WEXIT POOH TO GET ABOVE CEMENT PLUG -BRINE WEIGHT,9.8 PPG IN,9.8 PPG OUT -POOH F/ 8356'T/ 7200'MD -PU WT131K,SOWT123K@7200'MD 107:00 - 08:30 1.50 REMCMT P WEXIT CIRCULATE ABOVE CEMENT PLUG -LOAD DRILL PIPE WIPER BALL -CBU 2X,730 GPM,1920 PSI,20 RPM -RECIPROCATE PIPE 90' 08:30 - 11:30 3.00 REMCMT P WEXIT POOH -MONITOR WELL FOR 10 MINUTES,STATIC -BRINE WEIGHT,9.8 PPG IN,9.8 PPG OUT -P000 F/7200' T/SURFACE -PU 131K,SO 123K @ 7200'MD 11:30 - 12:00 0.50 STWHIP P WEXIT CLEAN AND CLEAR RIG FLOOR -CHANGE OUT PS-21'S 12:00 - 17:00 ' 5.00 STWHIP P WEXIT RIG UP E-LINE -PJSM W/E-LINE AND CREW -RIG UP SHEAVES AND RUN E-LINE -RIH W/JUNK BASKET AND 8.5"GAUGE RING ,-RIH T/7100'MD -PARAFFIN ON AND IN JUNK BASKET 17:00 - 20:30 3.50 STWHIP P WEXIT f PRESURE TEST 9-5/8"CASING -250 PSI/2500 PSI,5 MIN/30 MIN,GOOD -PRESSURE TEST EQUIPMENT FAILED -CHANGE OUT 5 EACH SENSATORS -R/D TEST EQUIPMENT ON MUD PUMP -R/U AND TEST WITH TEST PUMP -BLOW DOWN 20:30 - 00:00 3.50 STWHIP P WEXIT RIH W/EZSV -R/U E/LINE -M/U TOOL STRING -LOAD FIRING HEAD AND EXPLOSIVE -P/U TOOL STRING,MN EZSV RIH W/EZSV Printed 3/3/2014 12:34:57PM North America-ALASKA-BP Page 16.9833 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Datemme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 t 66.80usft(above Mean Sea Level) Date From-To ! Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) • 2/17/2014 00:00 - 02:00 2.00 STWHIP P WEXIT RIH W/EZSV -ZERO DEPTH AT 272 KB,PDC -LOG UNCLEAR FOR COLLAR LOCATE -MAKE MULTIPLE PASSES AT DIFFERENT ' SPEEDS ' -CCL CLEARED UP AT 6600'MD -COUNT COLLARS DN TO SETTING DEPTH I -CORRELATE GAMMA W/LOG FROM TOWN -SET PLUG AT 6938'MD,5980'ND ELM PLUG SET IN CASING IN UG-3 SAND I PACKAGE 02:00 - 03:00 1.00 STWHIP P DECOMP 'POOH W/E-LINE -BRINE WEIGHT 9.8 PPG IN,9.8 PPG OUT -POOH F/6938'T/SURFACE -R/D E-LINE 03:00 - 04:00 1.00 STWHIP P DECOMP PRESSURE TEST EZSV X 9-5/8 CASING -250 PSI/3500 PSI,5 MIN/30 MIN,GOOD NOTE:CONTACT INTL WITH TEST RESULTS, j I RECEIVE APPROVAL TO PROCEED WITH MILLING WINDOW 04:00 - 06:30 2.50 ' STWHIP P WEXIT !P/U WHIPSTOCK I-PJSM -P/U WHIPSTOCK ASSEMBLY 06:30 - 11:30 5.00 STWHIP P WEXIT 7RIH WITH WHIPSTOCK I -F/SURFACE T/6840'MD -RIH ON ELEVATORS PICKING UP 4°DP • FROM DERRICK -BREAK CIRCULATION EVERY 4000'MD,210 GPM,300 PSI i NOTE.100'MIN RUN TIME PER BAKER HAND. 11:30 - 12:30 • 1.00 ' STWHIP- P WEXIT ORIENT WHIPSTOCK !-45 DEG.RIGHT OF HIGH SIDE SET WHIPSTOCK©6952'MD • j • 1-PU 140K,SO 127K BEFORE SETTING WHIPSTOCK j I-PU 138K,SO 127K AFTER SETTING 'WHIPSTOCK 12:30 - 14:00 ' 1.50 STWHIP P WEXIT 1FLUID SWAP -FROM 9.8 PPG BRINE TO 9.6 PPG LSND -PJSM W/MUD ENGINEER AND TRUCK 1 DRIVERS -PUMP 40 BBLS FRESH WATER -PUMP 40 BBL HIGH VIS SPACER -CHASE SPACER W/9.6 PPG LSND MILLING FUILD -PUMP©580 GPM,2400 PSI Printed 3/3/2014 12:34 57PM • North America-ALASKA-BP Page 17 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date: IX3-013XC-C:DRILL(10,157,192.00) -i Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 I Spud Date/Tme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(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 STWHIP P WEXIT I MILL 8 1/2"WINDOW P1 1-6kA'L1 -TOW 6931'MD,5929'TVD -BOW 6948'MD,5941'ND 061 O/` -400 GPM, 1420 PSI ON,1340 PSI OFF JJ �7 -100 RPM,5-7K TORQUE ON,3-4K TORQUE OFF -PU 140K,SO 127K,ROT 133K -WOB 4-6K -MUD WEIGHT:9.6 PPG IN,9.6 PPG OUT -ROP DECREASED AT 6945' -PUMP HI-VIS SWEEP @ 6941',50% CUTTINGS INCREASE I-ROP RETURN TO NORMAL NOTE:SHAKERS BLINDING @ 6945'MD,PICK UP AND CBU 1X WHILE ADDING 0.25% DRIL-N-SLIDE 22:00 - 00:00 2.00 STWHIP P WEXIT DRILL FORMATION FROM 8 1/2"WINDOW -F/6948'T/6960',ESTIMATED 5949'ND -400 GPM, 1420 PSI ON,1340 PSI OFF -100 RPM,5-7K TORQUE ON,3-4K TORQUE OFF -PU 140K,SO 127K,ROT 133K -WOB 4-6K -MUD WEIGHT:9.6 PPG IN,9.6 PPG OUT -RETURNS 100%CEMENT @ 6954' -RETURNS 5%SAND @ 6958' -PUMP HI-VIS SWEEP @ 6960',30% CUTTINGS INCREASE SPR'S:6931'MD(5929'TVD)MW=9.6PPG #1 MP-20/30 SPM=325/420 PSI #2 MP-20/30 SPM=325/420 PSI 2/18/2014 00:00 - 03:00 3.00 STWHIP P WEXIT DRILL FORMATION FROM 8 1/2"WINDOW -F/6960'T/6969',ESTIMATED 5957'ND -325 GPM, 1150 PSI ON,1050 PSI OFF -100 RPM,7K TORQUE ON,4K TORQUE OFF -PU 140K,SO 127K,ROT 133K -WOB 4-6K -MUD WEIGHT:9.6 PPG IN,9.6 PPG OUT -RETURNS 70%SHALE @ 6960' -PULL THRU WINDOW AND RIH THRU WINDOW 3X'S -WITH PUMPS ON AND PUMPS OFF NO OBSTRUCTIONS 03:00 - 04:00 1.00 STWHIP P WEXIT CBU 2 X -420 GPM,1590 PSI -RECIPROCATE PIPE 75' • -RACK 1 STD FOR LOT 04:00 - 05:00 1.00 STWHIP P WEXIT PERFORM LOT(FIT) -MUD WEIGHT 9.6 PPG,6938'MD,5935'TVD -PUMP 2.7 BBLS TO 1300 PSI,BLED BACK 2.7 BBLS -LOT EMW=13.81 PPG PUMP DOWN DP AND KILL LINE NOTE:NOTIFY ODE OF TEST RESULTS, RECEIVE APPROVAL TO PROCEED Printed 3/3/2014 12:34.57PM North America-ALASKA-BP Page 18>Qt37 Operation Summary Report Common Well Name:09-50 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/2/2014 End Date. X3-013XC-C:DRILL(10,157,192.00) Project:Prudhoe Bay Site:PB DS 09 Rig Name/No.:PARKER 272 Spud Date/Tme:1/24/1993 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292232500 Active datum:09-50A Plan 13 @66.80usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 05:00 - 10:30 5.50 STWHIP P . WEXIT PULL OUT OF THE HOLE ON ELEVATORS FROM 6894'MD TO SURFACE. -MONITOR WELL FOR 10 MINUTES:STATIC -MUD WEIGHT:9.6 PPG IN,9.6 PPG OUT -PU 140K,SO 125K AT 6890'MD. -MONITOR WELL FOR 10 MINUTES:STATIC -L/D BHA,COLLAR'S,MWD. -LAY DOWN WINDOW MILLS: -STARTER MILL 8-1/4"OD.UPPER STRING MILLS IN-GUAGE. -PULL PS-21'S,CHANGE INSERTS 10:30 - 11:00 0.50 STWHIP P WEXIT CLEAN AND CLEAR RIG FLOOR 11:00 - 13:00 I 2.00 STWHIP P WEXIT FLUSH STACK AND LINES. -PICK UP PORTED SUB ASSEMBLY. -CLEAN AND WASH STACK INTERNALS. -BLOW DOWN LINES. -L/D PORTED SUB ASSEMBLY. 13:00 16:30 3.50 DRILL P WEXIT PICK UP AND MAKE UP 8-1/2"DRILLING ASSEMBLY. i-PJSM W/BAKER MWD/DD. -VERIFY BIT DETAILS -P/U AND ORIENT MWD TOOLS PER BAKER. -F/SURFACE T/634'MD. 16:30 - 17:00 0.50 DRILL P WEXIT SURFACE TEST MWD -TEST GOOD 450 GPM 940 PSI_ 17:00 - 20:00 3.00 DRILL PWEXIT 'RUN IN THE HOLE WITH 8.5"DRILLING ASSEMBLY. -FROM 634'MD TO 2528'MD -RIH ON ELEVATORS PICKING UP 60 JTS 4" DP SINGLES STOP AND FLOWCHECK WELL EVERY 5 STANDS DUE DISPLACEMENT BEING OFF. -LARGE AMOUNTS OF PARAFFIN. BARA-FIBER AND THICK MUD BLINDING OFF SHAKERS. 20:00 - 00:00 4.00 DRILL P WEXIT RUN IN THE HOLE WITH 8.5"DRILLING ASSEMBLY. -FROM 2528'MD TO 6300'MD -RIH ON ELEVATORS PICKING 4"DP STANDS •FROM DERRICK -BREAK CIRCULATION EVERY 2000'MD,170 GPM,500 PSI t 5300'MD STOP AND FLOWCHECK WELL EVERY 5 TO 10 STANDS DUE DISPLACEMENT BEING OFF. -LARGE AMOUNTS OF PARAFFIN. BARA-FIBER AND THICK MUD BLINDING OFF SHAKERS. 2/19/2014 00.00 - 00:30 0.50 DRILL P WEXIT CONTINUE TO RUN IN THE HOLE WITH 8.5" DRILLING ASSEMBLY. -FROM 6300'MD TO 6969'MD -RIH ON ELEVATORS PICKING 4"DP STANDS FROM DERRICK -PU 125K,SO 115K 00:30 - 01:30 1.00 DRILL P WEXIT CBU 1 X 1-410 GPM,1450 PSI I-CONDITION MUD PRIOR TO DRILLING OUT. y_--.__-- `LOWERED YP TO 20. Printed 3/3/2014 12:34:57PM TREE 7FMC F. r I,MZLi-EAD= CNV 09-50 I fEfY NOTES: ***CHROME TBG S:LNR*** ,,ACTUATOR= OTIS OKB.ELEV= 55 BF.B_EV 6931" H9-5/8'WHPSTOCK(02/17/14) KOP= _ 1996' Max Angle= 46°@ 932' 41 _1 Datum MD= _10781' 6952' �9-5/8'EZSV(02/17/14) Datum ND= 8800'SS GAS LFT MANDRELS 13-3/8"CSG,68#,L-80,J-55,D=12.415" — 3978' ST MD ND DEV TYPE VLV LATCH PORT DATE 1 3434 3296 36 LB-1 DMY T-2 0 08/02/12 Minimum ID =3.725" @ 10579' 2 5355 4760 41 LB-1 DMY RA 0 02/13/93 4-1/2" PARKER SWN NIPPLE 3 6373 5511 42 LB-1 DMY T-2 0 08/02/12 4 7037 6001 43 LB-1 DMY RA 0 08/28/94 5 7702 6483 42 LB-1 DMY RA 0 02/13/93 TBG CUT(02/11/14) H 8352' 6 8401 7003 48 LB-1 DMY T-2 0 08/02/12 7 9056 7513 43 LB-1 DMY RA 0 08/28/94 TOC(02/16/14) —I 9675' 8 9711 7991 43 LB-1 DMY RA 0 11/24/94 9 10058 8265 41 LB-1 DMY T-2 0 08/02/12 10 10484 8610 40 LB-1 DMY E-3 0 02/13/93 TBG CUT(02/09/14) 10080' ;.: k. 10504' —I5-112"PARKER SWS NP,D=4.562" TBG CUT(01/03/14) —I 10507' • . �� ►� -I 10525' —9-5/8"X 5-1/2"BAKER SB-3A HY DROSET PKR,ID=4.875" 5-1/2'TBG,17#,13-CR,.0232 bpf,113=4.892" 10540' 4/44 10540'I-15-1/2"X 4-1/2"X0,MILLOUT EXTENSION Ili 10561' —I4-1/2"PARKER SWS NP,13=3.813" 10579' H4-1/2"PARKER SWN NP,D=3125" TOP OF 7"LNR —I 10584' vto ti 1 10592' H4-1/2"TUBING TAS.WLEG,D=3.958" 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,ID=3.958" 10592' 10587' --I ELMD TT LOGGED 02/21/93 11111111111111 , —10640' —ITOC(12/18/13) 9-5/8"CSG,47#,L-80,D=8.681" — 10738' 11111111111111 PERFORATION SUMMARY 11111111111111 111111111111111, REF LOG:SAS LDT ON 02/09/93 1111111,4 ANGLE AT TOP PERF:32°@ 10746' 1111111111111 1111111111111 Note:Refer to Production DB for historical perf data 1111111111111 SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 1111111 3-3/8" 6 10746-10758 S 08/09/04 12/18/13 11111111111111 111111111111111 3-3/8" 4 10746-10770 S 11/01/93 07/24/99 1111111, 3-3/8" 6 10759-10775 S06/21/09 12/18/13 4..... 3-3/8" 4 10842-10852 S 05/15/00 12/18/13 1111111111111 3-3/8" 6 10852-10858 S 06/21/09 12/18/13 1111111111111 1111111111111 3-3/8" 4 10882-10884 S 07/24/99 11/02/99 1111111 3-3/8" 4 10884-10890 S 11/02/99 12/18/13 11111111111i1 3-3/8" 4 10918-10926 S 11/02/99 12/18/13 11111111111111 3-3/8" 6 10958-10964 S 09/17/99 12/18/13 111111111111111., 111111 3-3/8" 6 10970-10974 S 06/21/09 12/18/13 1111111111111111111 1 3-3/8" 6 10984-10990 S 09/17/99 12/18/13 11111111111i1 3-3/8" 6 10994-10998 S 09/17/99 12/18/13 11111111111i1• 3-3/8" 6 11002-11006 S 09/17/99 12/18/13 11111111111111 3-3/8" 6 11022 11028 509/17/99 12/18/13 11111111111111 11111111111i1 11*111*1**4,,. PBTD — 11132 OIT.T, 111111111111114 7"LNR,29#,13-CR,.0371 bpf,D=6.184" —I 11212' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 02/13/93 ORIGINAL COMPLETION 12/27/13 TQ/JMD CEMENTSQZ/P&A(12/18/13) WELL: 09-50 09/21/00 DAV/ PULL XXN TTP 01/06/14 JCM/JMD TBG CUT(01/03/14) PERMIT No: 1921490 01/02/02 RN/TP CORRECTIONS AR No: 50-029-22325-00 09/02/02 BHCITP PERF CORRECTIONS SEC 2,T1ON,R15E,1727'FSL&6'FEL 08/08/12 CDJ/JMD GLV C/O(08/02/12) 12/27/13 WEC/JMD PULLED DSSSV(11/28/13) BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 _._ — - Post Office Box 196612 Anchorage, Alaska 99519 -6612 0 December 30, adIN,NEDFEB Mr. Tom Maunder iq ( 9 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue �q Sr-0 Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of DS -09 Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from DS -09 that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659 -5102. Sincerely, Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) DS-09 10/20/11 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft gal 09 -01 1750760 50029201880000 Sealed conductor NA NA NA NA NA 09 -02 1760160 50029201980000 Sealed conductor NA NA NA NA NA 09 -03 1760350 50029202090000 Sealed conductor NA NA NA NA NA 09-04A 1930240 50029202120100 Sealed conductor NA NA NA NA NA 09-05A 1930260 50029202150100 Sealed conductor NA NA NA NA NA 09-06 1760480 50029202160000 Sealed conductor NA NA NA NA NA 09-07A 1990220 50029202230100 Sealed conductor NA NA NA NA NA 09 -08 1760700 50029202300000 Sealed conductor NA NA NA NA NA 09-09 1760760 50029202320000 Sealed conductor NA NA NA NA NA 09 -10 1760820 50029202350000 Sealed conductor NA NA NA NA NA 09-11 1760840 50029202360000 0.7 NA 0.7 NA 3.4 7/17/2010 09-12 1770070 50029202390000 Sealed conductor NA NA NA NA NA 09 -13 1770080 50029202400000 Sealed conductor NA NA NA NA NA 09 -14 1770250 50029202490000 Sealed conductor NA NA NA NA NA 09 -15A 2070220 50029202560100 Sealed conductor NA NA NA NA NA 09 -16 1770370 50029202570000 Sealed conductor NA NA NA NA NA 09 -17 1770380 50029202580000 Sealed conductor NA NA NA NA NA 09-18 1770390 50029202590000 Tanko conductor NA NA NA NA NA 09-19 1770400 50029202600000 Sealed conductor NA NA NA NA NA 09 -20 1770410 50029202610000 Sealed conductor NA NA NA NA NA 09 -21 1831600 50029210360000 2.5 NA 2.5 NA 25.5 7/17/2010 09 -22 1831730 50029210490000 6.7 NA 6.7 NA 42.5 7/8/2010 09 -23 1980440 50029210667100 2.2 NA 2.2 NA 15.3 7/8/2010 09 -24 1852020 50029214280000 Dust Cover NA NA NA 9.4 10/20/2011 09 -25 1840280 50029210830000 3.2 NA 3.2 NA 23.0 7/8/2010 09 -26 1840370 50029210910000 0.3 NA 0.3 NA 1.7 7/8/2010 09-27 1850280 50029212910000 Dust Cover NA NA NA 6.8 10/20/2011 09-28A 1930430 50029212920100 Dust Cover NA NA NA NA NA 09 -29 1850960 50029214220000 13.5 3.0 0.5 7/13/2011 11.9 10/20/2011 09 -30 1851840 50029214117000 Dust Cover NA NA NA 8.5 10/20/2011 09-31C 1960640 50029213960300 0.2 NA 02 NA 1.7 7/27/2010 09 -32 , 1851180 50029213710000 Sealed conductor NA NA NA N/A NA 09-33A 2081560 50029213650100 9.3 NA 9.3 NA 66.3 7/18/2010 09-34A 1932010 50029213290100 Sealed conductor NA NA NA N/A NA 09 -35A 1930310 50029213140100 2.0 NA 2 NA 17.0 7/27/2010 09-36C 1951140 50029214290300 Dust Cover NA NA NA 9.4 10/20/2011 09 -37 1940280 50029224510000 Open Flutes NA 0 NA 3.4 10/20/2011 09-38 1890210 50029219190000 0.1 NA 0.1 NA 6.8 10/20/2011 09-39 1910120 50029221330000 1.2 NA 12 NA 11.9 7/17/2010 09-40 1901690 50029221180000 1.3 NA 1.3 NA 10.2 7/17/2010 0941 1900740 50029220540000 Dust Cover NA NA NA N/A NA 09-42A 1990070 500292205901 SC Leak 09-43 1901070 50029220780000 11.3 6.0 1.0 7/13/2011 8.5 7/18/2011 09-44A 2091570 50029220870100 1.5 NA 1.5 NA 10.2 9/16/2010 09-45 1901150 50029220830000 0.2 NA 0.2 NA 3.4 10/20/2011 09-46 1901330 50029220920000 1.5 NA 1.5 NA 10.2 7/18/2010 09-47 1901460 50029220980000 1.3 NA 1.3 NA 6.8 7/18/2010 09-48 1910040 50029221280000 1.3 NA 1.3 NA 6.8 7/18/2010 09-49 1921340 50029223170000 0.7 NA 0.7 NA 2.6 10/20/2011 a- " - >• 09-50 1921490 50029223250000 Dust Cover NA NA NA 4.3 10/20/2011 09-51 1921410 50029223200000 Dust Cover NA NA NA 3.4 10/20/2011 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~ON REPORT OF SUNDRY WELL OPERATIONS ~,..~~~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ Other ~ PerFormed: Alter Casing ~ Puil Tubing ~ Pertorate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: Development ~ Exploratory ~~ 192-1490 3. Address: P.O. Box 196612 Stratigraphic ~ Service ~ 6. API Number: Anchorage, AK 99519-6612 50-029-22325-00-00 7. KB Elevation (ft): 9. Well Name and Number: 55 KB PBU 09-50 8. Property Designation: 10. Field/Pool(s): ADLO-028327 PRUDHOE BAY Field/ PRUDHOE OIL Pool ..... ...... ...... 11. Present Well Condition Summary: Total Depth measured 11212 feet Plugs (measured) None true vertical 9221.55 feet Junk (measured) None Effective De th measured 11132 feet p d, ~-~,~i~~~ Jt~~ ~; ~ 2!~0~ true vertical 9154 feet Casing Length Size MD ND Burst Collapse CONDUCTOR 80 20" 91.5# H-40 31 - 111 31 - 111 1490 470 LINER 628 7" 29# 13CR80 10584 - 11212 8692 - 9222 8160 7020 PRODUCTION 10713 9-5/8" 47# L-80 25 - 10738 25 - 8821 6870 4760 SURFACE 3879 13-3/8" 68# L-80 30 - 3909 30 - 3671 4930 2270 SURFACE 69 13-3/8" 68# J-55 3909 - 3978 3671 - 3724 3450 1950 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 7" 26# 13CR80 23 - 2178 7" 29# 13Cr80 2178 - 3302 4-1/2" 12.6# 13Cr80 10525 - 10593 5-1/2" 17# 13Cr80 3302 - 1 Packers and SSSV (type and measured depth) 4-1/2" Baker S63 Packer 1052 7" TIW Packer 10584 JuN 12. Stimulation or cement squeeze summary: Intervals treated (measured): euoSl(8 OII $~ G8# I;Qn~ ~g~j~ , ~l9li Anchor~ge Treatment descriptions including volumes used and final pressure: 13• Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 19 0 3419 302 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory ~ Developm ent ~ Senrice ~ Daiiy Report of Well Operations X 16. Well Status after proposed work: 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: N/A Contact Gary Prebie Printed Name Gary Preb~ Title Data Management Engineer Signature ;~ Phone 564-4944 Date 6/26/2009 r Form 10-404 Revised 04/2006 ,~i ~ll,. ,l.)~ ~~~~4~1 ~~~5~ Submit Original Only ~ ~.~ ~,~i~i 09-50 192-149 PFRF OTTOCHMFNT • • Sw Name Operation Date Perf Operation Code - - _ Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 09-50 2/21/93 PER 10,746. 10,770. 8,828.09 8,848.35 09-50 2/21/93 PER 10,842. 10,852. 8,909.15 8,917.59 09-50 2/21/93 PER 10,882. 10,888. 8,942.92 8,947.98 09-50 11/1/93 RPF 10,746. 10,766. 8,828.09 8,844.98 09-50 7/24/99 SQZ 10,690. 11,074. 8,780.81 9,105.03 09-50 9/17/99 APF 11,022. 11,028. 9,061.12 9,066.19 09-50 9/17/99 APF 10,994. 10,998. 9,037.48 9,040.86 09-50 9/17/99 APF 11,002. 11,006. 9,044.24 9,047.62 09-50 9/17/99 APF 10,958. 10,964. 9,007.09 9,012.15 09-50 9/17/99 APF 10,984. 10,990. 9,029.04 9,034.11 09-50 11/2/99 APF 10,884. 10,890. 8,944.61 8,949.67 09-50 11 /2/99 APF 10,918. 10,926. 8,973.31 8,980.07 09-50 5/15/00 APF 10,842. 10,852. 8,909.15 8,917.59 09-50 8/9/04 APF 10,746. 10,758. 8,828.09 8,838.22 09-50 6/21/09 APF 10,970. f 10,974. 9,017.22 9,020.6 09-50 6/21/09 APF 10,852. 10,858. 8,917.59 8,922.65 09-50 6/22/09 APF 10,759. , 10,775. 8,839.07 8,852.58 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE -~ J ~ 09-50 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY BBLS 4 METH 1 diesei 5 Total Alasr.ö UII "" ~-- - Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED REPORT OF SUNDRY WELL OPERATIONS 0 (} 1. Operations Performed: Abandon 0 Alter CasingD Change Approved Program D 55.00 8. Property Designation: ADL-OO28327 11. Present Well Condition Summary: 4. Current Well Class: Development Œ] Stratigraphic 0 9. Well Name and Number: 09-50 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool ExploratoryD ServiceD Stimulate 0 AI..rmJ & Gas Cons. Comm; WaiverD Time ExtensionO Anchorage Re-enter Suspended Well 0 5. Permit to Drill Number: 192-1490 6. API Number 50-029-22325-00-00 RepairWêllD PluQ PerforationsD Pull TubingO Perforate New Pool 0 Operation Shutdown 0 Perforate [K] 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): Total Depth measured 11212 feet true vertical 9221.6 feet Effective Depth measured 11132 feet true vertical 9154.0 feet Plugs (measured) Junk (measured) None None Casing Conductor Liner Production Surface Surface Length 80 628 10713 3879 69 Size 20" 91.5# H-40 7" 29# 13CR80 9-5/8" 47# L-80 13-3/8" 68# L-80 13-3/8" 68# J-55 MD TVD Burst Collapse 31 111 31.0 - 111.0 1490 470 10584 - 11212 8692.1 - 9221.6 8160 7020 25 - 10738 25.0 - 8821.3 6870 4760 30 - 3909 30.0 - 3670.6 4930 2270 3909 - 3978 3670.6 - 3723.5 3450 1950 Perforation depth: Measured depth: 10746 -10758,10842 -10852, 10884 -10888,10888 - 10890, 10918 -10926,10958 - 10964, 10984 -10990 ## True vertical depth: 8828.09 - 8838.22,8909.15 - 8917.59,8944.61 - 8947.98,8947.98 - 8949.67,8973.31 - 8980.07,9007.09 - 9012.15 9029.04 - 9034.11, 9037.48 - 9040.86, 9044.24 - 9047.62, 9061.12 - 9066.19 Tubing ( size, grade, and measured depth): 7" 26# 13CR80 @ 23 2178 7" 29# 13Cr80 @ 2178 3302 5-112" 17# 13Cr80 @ 3302 10525 4-112" 12.6# 13Cr80 @ 10525 10593 Packers & SSSV (type & measured depth): 4-112" Baker SB3 Packer @ 10525 7" TlW Packer @ 10584 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Representative Dailv Averaae Production or Iniection Data Prior to well operation: Subsequent to operation: Oil-Bbl Gas-Met Water-Bbl Casino Pressure Tubing Pressure 97 0.3 3912 2000 248 138 0.5 5739 2000 264 Copies of Logs and Surveys run - Daily Report of Well Operations. ! 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒJ GasD Development ŒI ServiceD 14. Attachments: Contact Printed Name Garry Catron Garry Catron WAG 0 GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Production Technical Assistant Signature c Phone 564-4657 Date 10/6/04 Form 10-404 Revised 4/2004 GINAL R8OMS BF L OCT ,] J ?om 09-50 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 08/09/04 Perforate 10746'-10758' 6 SPF FLUIDS PUMPED BBLS : TOTAL No Fluids Pumped 0 Page 1 TREE = FMC W 8.. LI"EA D = erN ACTUATOR = OTIS KB. ELEV - 55' BF. ELB' = KOP= 1996' Max Angle - 46 @ 9312' Dahlm MD = 10781' DahlmTVD- 8800' SS 7" TBG, 26#, 13-CR, .0383 bpf, ID = 6.276" 13-318" CSG, 68#, L-80, Jo55, ID = 12.415" Minimum ID = 3.725" @ 10579' 4-1f2" PARKER SWN NIPPLE 5-1IZ' TBG, 17#, 13-CR .0232 bpf, ID = 4.892" 10540' TOPOF7" LNR 10584' 4-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" 10592' 9-5I8"CSG, 47#, L-80, ID = 8.681" ÆRF ORA 110 N S l.t.11v1A RY REF LOG: SWS LDT ON 02/09/93 ANGLEATTOPPERF:32@ 10746' Note: Refer 10 A-oduction œ for historieal perf data SIZE SPF INTERII AL OpnlSqz ()t\ TE 3-318" 6 10746 - 10758 0 08l09,Q4 3-318" 4 10746 - 10770 S 07/24/99 3-318" 4 10842 - 10852 0 05l15,Q0 3-318" 4 10882 .. 10884 S 07/24/99 3-318" 4 10884 - 10890 0 11/02/99 3-318" 4 10918 -10926 0 11/02/99 3-318" 6 10958 - 10964 0 09/17/99 3-318" 6 10984 .. 10990 0 09/17/99 3-318" 6 10994 - 10998 0 09117/99 3-318" 6 11002-11006 0 09/17/99 3-318" 6 11022-11028 0 09/17/99 11132' 11212' 09-50 I SAFElY NOTES: CHROME UNER AND TUBING . ST MD lVD 1 3434 3296 2 5355 4760 3 6373 5511 4 7037 6001 5 7702 6483 6 8401 7003 7 9056 7513 8 9711 7991 9 10058 8265 10 10484 8610 10504' 10525' 10540' 10561' 10579' 7" X 5-1/2" XO, ID = 4.892" GAS LIFT MANDRELS ŒV TYPE VLV LATa-t 36 LB-1 DOME T-2 41 LB-1 rN RA 42 LB-1 DOME T-2 43 LB-1 rN RA 42 LB-1 rN RA 48 LB-1 DOME T-2 43 LB-1 rN RA 43 LB-1 rN RA 41 LB-1 510 T-2 40 LB-1 rN 6-3 5-1IZ' PARKERSWS I'IIP, ID = 4.562" 9-5/8" X 5-112" BAKERSB-3A HY[ROSETPKR, ID = 4.875" 4-1/Z' PARKERSWS I'IIP,ID=3.813" 4-1IZ' PARKERSWN I'IIP,ID=3.725" roRr DATE 16 09/16/99 02/13/93 16 09/16/99 08/28/94 02/13/93 16 09/16/99 08/28/94 11/24/94 24 09/16/99 02/13/93 10592' 4-1IZ' TLBING TAIL WLEG, ID = 3.958" I 10587' H ELMDTTLOGGIÐ 02/21/93 I ()t\ TE REV BY COMMENTS DATE REV BY COMMENTS 02113193 ORIGINAL COMPLETION 09121/00 ()t\ V/ PLLL XXN TIP 01/02102 RNITP CORRECl1ONS 09102102 BHCITP PERF CORRB::TIONS 08109104 MOCITLP A 00 ÆRFS PRUDI-DE BAY UNIT WELL: 09-50 PERMT No: 1921490 API No: 50-029-22325-00 SEC 2, T1 ON, R15E, 1286.01' FEL & 378.6' FNL BP Exploration (Alaska) ~ S BEEN ON OR BEFORE D cEMBER01 2000 E W C..LORihx~l~,lvt.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 5. Type of Well: 6. Datum elevation (DF or KB feet) Phillips Alaska, Inc. Development__X RKB 55 feet 3. Address Explorato~__ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3552' FNL, 4' FEL, Sec. 02, T10N, R15E, UM 09-50 At top of productive interval 9. Permit number / approval number 262' FNL, 304' FEL, Sec. 12, T10N, R15E, UM 192-149 At effective depth 10. APl number 334' FNL, 176' FEL, Sec. 12, T10N, R15E, UM 50-029-22325 At total depth 11. Field / Pool 379' FNL, 86' FEL, Sec. 12, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11212 feet Plugs (measured) Tagged PBTD @ 11016' MD (5/11/2000) true vertical 9222 feet Effective depth: measured 11016 feet Junk(measured) ORIGINAL true vertical 9056 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 1 10' 20" 281 cubic It AS 110' 1 10' Surface 3923' 13-3/8" 2927 cu It CS III & 478 cuft G 3978' 3978' Production 10683' 9-5/8" 1462 cubic It Class G 10738' 8821' Liner 628' 7" 97 cubic It Class G 10584' - 11212' 8692' - 9222' Perforation depth: measured 10842'-10852'; 10884'-10890'; 10918'-10926'; 10958'-10964'; 10984'-10990'; 10994'-10998'; 11002'- 11006'; 11022'- 11028'. true vertical 8909' - 8918'; 8945' - 8950'; 8973' - 8980'; 9007' - 9012'; 9029' - 9034'; 9037' - 9041'; 9044' - 9048'; 9061' -9066'. Tubing (size, grade, and measured depth) 7" 26#, 13CR mbg @ 3302' MD; 5-1/2"17#, 13CR Tbg @ 10540' MD; 4-1/2"12.6#, 1~C~!,~ ~,: Tb~.'@,~, ~.,.,,. , ,!,,~59~ .,M.,p~i~ ,~,-,~ . ~ ~, ~ Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SB-3A HYDROSET PACKER @ 10526' MD. ,.. o^,oo,^,-o sssv. MAY 2, 2. .000 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) ,.,~,,,;.,~r~ ~_~ Treatment description including volumes used and final pressure .... ,. ~...,~, , ,.~..'~. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 86 167 1007 - 287 Subsequent to operation 171 956 3669 - 282 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 PAl EngineeringS up er visor Date :~'-/~'- ,,~?'(~___~ Erin Oba ~ Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-50 DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 5/11/2000: 5/15/2000: RIH & tagged PBTD @ 11016' MD. MIRU ELU & PT'd equip to 3000 psi. RIH w/perf guns & shot 10' of Add Perforations @: 10842' - 10852' MD (Zone 2B) Reference Log: LDT/CNL 2/09/1993. Used 3-3/8" carriers & all shots @ 6 SPF, random orientation, underbalanced press, & 60° phasing. POOH w/guns. ASF. RD. Returned well to production & obtained a valid welltest. [AY 22 2000 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown_ Stimulate _ Plugging _ Perforate _X Puli tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 55 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic_ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3552' FNL, 4' FEL, Sec. 02, T10N, R15E, UM 09-50 At top of productive interval 9. Permit number / approval number 262' FNL, 304' FEL, Sec. 12, T10N, R15E, UM 92-149 At effective depth 10. APl number 334' FNL, 176' FEL, Sec. 12, T10N, R15E, UM 50-029-22325 At total depth 11. Field / Pool 379' FNL, 86' FEL, Sec. 12, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11212 feet Plugs (measured) Tagged PBTD @ 11007' MD (11/02/1999) true vertical 9222 feet Effective depth: measured 11007 feet Junk (measured) true vertical 9062feet ORI Gl NAL Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 281 cubic It AS 110' 110' Surface 3923' 13-3/8" 2927 cu It cs III & 478 cuft G 3978' 3978' Production 10683' 9-5/8" 1462 cubic ft Class G 10738' 8821' Liner 628' 7" 97 cubic ti Class G 1 0584' - 11212' 8692' - 9222' Perforation depth: measured 10884'- 10890'; 10918'- 10926'; 10958'- 10964'; 10984'- 10990'; 10994'- 10998'; 11002'- 11006'; 11022' - 11028'. true vertical 8945' - 8950'; 8973' - 8980'; 9007' - 9012'; 9029' - 9034'; 9037' - 9041" 9044' - 9048'; 9061' -9066'. Tubing (size, grade, and measured depth) 7" 26#, 13CR Tbg @ 3302' MD; 5-1/2"17#, 13CR Tbg @ 10540' MD; 4-1/2"12.6#, 13CR, Tbg @ 10592' MD. Packers & SSSV (type & measured depth) 7"9'5/8" X 5-1/2" BAKER SB-3A HYDROSET PACKER @ 10526' MD.cAMCO BAL-O SSSV @ 2158' MD. J~ ~ C ~ ~ '~ ~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached)'~'~I~U V Treatment description including volumes used and final pressure '?_~.!~;~/3~1 rD. ~,,,, 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Ca~'i'r~g 15r~s~ure Tubing Pressure Prior to well operation 59 483 377 - 297 Subsequent to operation 217 384 1881 - 321 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 ARCO EngineeringSupervisor Date Erin Oba Prepared by Pau/ Rauf 263-4990 ~_ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-50 DESCRIPTION OF WORK COMPLETED ACID WASH CEMENT PERFORATING OPERATIONS Date Event Summary 11/02/1999: RIH & tagged PBTD @ 11007' MD. Pumped 120 bbls Crude down tubing. Pumped 10 bbls Methanol. Pumped 20 bbls Crude down FL. MIRU ELU & PT'd equip to 3000 psi. RIH w/perf guns & shot 14' of Add Perforations @: 10884' - 10890' MD (Zone 2B) Reference Log: LDT/CNL 2/09/1993. 10918' - 10926' MD (Zone 2B) Used 3-3/8" carriers & all shots @ 6 SPF, random orientation, & 60° phasing. POOH w/ guns. ASF. RD. Returned well to production & obtained a valid welltest. RECEIVED tOV 12. 1999 Gas Cons. Comm~sk)n 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_X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development~X RKB 55 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 3552' FNL, 4' FEL, Sec. 02, T10N, R15E, UM 09-50 At top of productive interval 9. Permit number / approval number 262' FNL, 304' FEL, Sec. 12, T10N, R15E, UM 92-149 At effective depth 10. APl number 334' FNL, 176' FEL, Sec. 12, T10N, R15E, UM 50-029-22325 At total depth 11. Field / Pool 379' FNL, 86' FEL, Sec. 12, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured 11212 feet Plugs (measured) Tagged PBTD @ 11023' MD (9/30/1999) true vertical 9222 feet Effective depth: measured 11023 feet Junk (measured) true vertical 9062 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 110' 20" 281 cubic ft AS 110' 110' Surface 3923' 13-3/8" 2927 cuft cs III & 478 cuft G 3978' 3978' Production 10683' 9-5/8" 1462 cubic ft Class G 10738' 8821' Liner 628' 7" 97 cubic ft Class G 10584' - 11212' 8692' - 9222' RECEIVED · , , Perforation depth: measured 10958'-10964'; 10984'-10990'; 10994'-10998'; 11002'-11006'; 11022'-1102~CT 11 11~I~.9 true vertical 9007'- 9012'; 9029'- 9034'; 9037'- 9041'; 9044'- 9048'; 906~'-~066'. ~aBl~llOII & Gas ~ COllillltlSs~tl Anchorage Tubing (size, grade, and measured depth) 7" 26#, 13CR Tbg @ 3302' MD; 5-1/2"17#, 13CR Tbg @ 10540' MD; 4-1/2"12.6#, 13CR, Tbg @ 10592' MD. Packers & SSSV (type & measured depth) 9-5/8" X 5-1/2" BAKER SB-3A HYDROSET PACKER @ 10526' MD. 7" CAMCO BAL-O SSSV @ 2158' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation (shut in) - Subsequent to operation 702 19075 5832 331 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 ARCO Engineering Supervisor Date ~'O/~..~::; Erin Oba Prepare~ by Pa&l Radf 263-4990 ~ Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 09-50 DESCRIPTION OF WORK COMPLETED ACID WASH CEMENT SQUEEZE FOR WSO/GSO & PERFORATING OPERATIONS Date Event Summary 7/07/1999: 7/08/1999: 7/24/1999: 7/29/1999: 8/02/1999: 8/03/1999 - 9/9/1999: 9/11/1999: 9/15/1999: 9/17/1999: 9/15/1999: MITIA to 2500 psi - passed. RIH & tagged PBTD @ 11074' MD. A CTU Acid wash Cement Squeeze for GSO/WSO were performed as follows: MIRU CTU. PT'd equip to 4000 psi. Killed well w/100° F KCL Water. RIH & tagged PBTD @ 11074' MD. Pumped Crude. Reciprocated an acid wash across the open perforations @: 10746' - 10776' MD (Zone 3) Reference Log: SWS LDT 2/9/1993. 10842'- 10852' MD (Zone 2) 10882'- 10888' MD (Zone 2) Pumped: (a) 14.3 bbls of 80% Diesel - 20% Xylene, followed by (b) 32 bbls of 12% HCL - 10% Xylene - 3% Acetic Acid, followed by (c) 90 bbls of 1% KCL Water, followed by (d) shutdown. Pumped 20 bbls of 15.6 ppg Neat Class G Cement, followed by 50 bbls of 15.6 ppg Class G Cement w/fibers, followed by 30 bbls of 15.6 ppg Neat Class G Cement. Placed 63 bbls of Cement behind pipe w/a max sqz press of 2500 psi. Contaminated Cement w/Biozan & cleaned out contaminated cement to 10690' MD. POOH w/CT. Left 300 psi on wellhead. FP'd well. RD. RIH & tagged TOC @ 10709' MD. RIH & tagged TOC @ 10907' MD. UR'd to 10940'. POOH. BHA left in hole as fish. Fished UR, bow springs, 3/4" ball, & misc BHA junk f/wellbore. RIH & UR'd f/10958'- 11060' MD. MITto 500 psi- passed. RIH & tagged PBTD @ 11048' ELM. MIRU ELU & PT'd equip to 3000 psi. RIH w/perf guns & shot 26' of Add Perforations @: 10958' - 10964' MD (Zone 1) Reference Log: LDT/CNL 2/09/1993. 10984'- 10990' MD (Zone 1) 10994' - 10998' MD (Zone 1) 11002'- 11006' MD (Zone 1) 11022'- 11028' MD (Zone 1) Used 3-3/8" carriers & all shots @ 6 SPF, random orientation, 60° phasing, & balanced press. Tag PBTD @ 11045' MD. POOH w/guns. ASF. RD. RIH & tagged PBTD @ 11023' MD. Returned well to production & obtained a valid welltest. GeoQuest 500 w. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 9521 Company: 6/19/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia DIR MWD Disk D.S. 3-22 DUAL BURST TDT-P 950603 I 1 D.S. 3-29 PROD PROFILE 950530 I 1 D.S. 3-32A PERF RECORD 95 0609 I 1 D.S. 4-2A DUAL BURST TDT-P 950529 I 1 D.S. 4-35 PERF RECORD 950529 I 1 D.S. 6-19 DUAL BURST TDT-p 950530 I 1 D.S. 9-3 BRIDGE PLUG RECORD 950531 I 1 D.S. 9-39 PERF RECORD 950604 I 1 D.S. 9-50 PROD PROFILE 950602 I 1 D.S. 12-15 GAS LIFTSURVEY 950606 I 1 D.S. 12-17 GAS LIFTSURVEY 950607 I 1 D.S. 14-02B DUAL BURSTTDT-P 950531 I 1 D.S. 15-36 DUAL BURST TDT-P 950602 I 1 D.S. 16-11 MI INJECT PROFILE 950605 I 1 D.S. 15-15 951 82 .CNT-D 950509 1 D.S. 14-33 951 70 CNT-D 950427 I SIGNED: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. RECEIVED DATE: JUN 1 9 1995 Alaska 011 & Gas Cons. Commission Anchorage PERMIT DATA ~ AOGCC Individual Well Geological Materials Inventory T DATA_PLUS Page: 1 Date: 01/09/95 RUN DATE_RECVD 92-149 5559 92-149 SURVEY 92-149 SURVEY 92-149 DWOP 92-149 407 92-149 92-149 92-149 92-149 T 3909-11215 DLL/SDN/CNTHGR 1 R 0-10693 MWD E TELECO R 0-10693 MWD E TELECO R 01/23-02/14/93 R COMP DATE:02/21/93 PROD/SPIN/TEMP/P L 100-10795 PROD/SPIN/TEMP/P L 3000-11046 PROD/SPIN/TEMP/P L 10650-11000 PERF/GR/CCL/JEW L 10450-11040 L 10620-10940 L 10530-11200 RAW DATA L 10530-11200 POROSITY L 3950-11200 W/CH/GR 92-149 PERF 92-149 LD/GR/CNL 92-149 LD/GR/CNL 92-149 DLL/MSFL/GR Are dry ditch samples required? yes ~o~ And received? Was the well cored? yes ~ Analysis & description received? Are well tests required? yes ~ Received? yes ~~ Well is in compliance ~ COMMENTS 03/19/93 08/31/93 03/30/93 03/30/93 03/30/93 06/20/94 07/30/93 04/27/93 03/26/93 12/15/93 03/09/93 03/09/93 03/09/93 yes yes ~ GeoQuest $00 W. International Airport Road Anchorage, AK 99618-1199 ATTN: She~e NO. 9086 Company: Alaska Oil & Gas Cons Comm , Altn: Larry Grant I 3001 Porcupine Drive Anchorage, AK 99501 11/4/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 4-2A //~/~ { CBT(10-26-94) 1 1 D.S. 4-30 ST1 _ ~-~,~ PROD PROFILE (10-29~94) 1 1 D.S. 4-40 ~- J ~'~ PRoD PROFILE (10-28-94) 1 1 D.S. 9-31B PERF RECORD (10-27-94) 1 1 D.S. 9-50 ,, GAS LIFT SURVEY (10-26-94) ,, 1 1 D.S. 17-7 ~1 - [./. ' PERF REOORD (10-29-94) 1 1 ,,, .... Please sign and retum one copy of this transmittal to Sherrle at the above address. Thank you. ...---.,. STATE OF ALASKA ~ -,-. ALASKA ,_AND GAS CONSERVATION CO, ~IISSION REPORT OF SUNDRY WELL OPE,tATIONS "'i'.' (~perations performed: Operation shutdown Stimulate X Plugging Perforate Pull tubing Alter casing Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development Exploratory Stratigraphic Service 4. Location of well at surface 1727' NSL, 6' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 262' SNL, 304' WEL, Sec. 12, T10N, R15E, UM At effective depth At total depth 381' SNL, 74' WEL, Sec. 12, T10N, R15E, UM 12. Present well condition summary Total depth: 6. Datum of elevation(DF or KB) 55' RKB 7. Unit or Property Prudhoe Bay Unit feet measured 11212 feet true vertical 9214 feet 8. Well number 9-50 9. Permit number/approval number 92-149 10. APl number 50 - 029-22325 11. Field/Pool Prudhoe Bay Oil Pool Plugs(measured) PBTD Tagged @ 10799' MD (5/20/94) Effective depth: measured 10799 feet true vertical 8873 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 78' 20" 281 cu ft AS 110' 110' Surface 3946' 13-3/8" 2927 cu ft CS 111/478 cu ft CL G 3978' 3978' Production 10710' 9-5/8" 1462 cu ft CL G 10738' 8821' Liner 628' 7" 97 cu ft CIG 10584-11212' 8692-9222' Perforation depth: measured 10746-10770'; 10842-10852'; 10882-10888' true vertical 8828-8848'; 8909-8918'; 8943-8948' Tubing (size, grade, and measured depth) 7", 26#, 13 Cr-80 @ 3302' MD; 7" x 5-1/2" xover @ 3302'MD; 5-1/2", 17#, 13 CR-80 @ 10540' MD; 5-1/2" x 4-1/2" xover @ 10540' MD; 4-1/2", 12.6#, 13CR-80 w/tail @ 10592' MD Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker SB-3A Hydroset pkr @ 10525' MD, 7" Camco BaI-O SSSV @ 2157' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Representative Dally Average Production or Injection Data Prior to well operation Subsequent to operation OiI-Bbl Gas-Mcf Water-Bbl 415 494 2547 661 790 2573 Casing Pressure .- K I:LI:I V fL) AUG ~ 0 199~ uil & Gas Cons. Commissior ~ncnor.~.,j9 Tubing Pressure 274 284 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 1203/13 cc: KZ. JWP Date ~'/?~/~z:)... SUBMIT IN DUPLICATE~ 9-50 DESCRIPTION OF WORK COMPLETED VICTOR ROPE TREATMENT W/SHEAR PLUG 3/23/94: RIH & tagged PBTD at 11032' MD. 3/24/94: MIRU CTU & PT equipment. RIH w/CT to tag bottom, then pumped 34 bbls of gelled sand slurry containing a total of 7550 lbs of 20/40 mesh sand, to place an isolation sand plug across the lower perforation intervals located at: 10842 - 10852' MD (Tango) Ref. Log: SWS LDT 2/9/93. 10882 - 10888' MD (Tango) Made a final top of sand plug tag at 10790' MD. POOH w/CT. Rigged down. 3/25/94: RIH & tagged sand plug top at 10800' MD. 3/28/94: RIH & set a shear disk in preparation for a ROPE Treatment, in the 4.5" tubing at 10555' MD. 3/29~94: Performed a ROPE Breakdown Treatment to increase the production from the well as follows: MIRU & PT equipment to 8300 psi. ROPE treated the perforation interval above the sand plug, at: 10746 - 10770' MD (Victor) Ref. Log: SWS LDT 2/9/93. Pumped a total of 152 bbls of 60/40 Meth-Water w/0.5# Biozan, to pressure up & rupture the shear disk (above) at 6253 psi. Rigged down. 3/30/94: RIH & retrieved the ruptured shear disk assembly. Returned the well to production w/lift gas & obtained a valid welltest. RECEIVED ~,UG ~ 0 i99~ AtaSka O~i & Gas Cons. Corr~mission Anchon je ARCO Alaska, Inc. Date: r' June 14, 1994 P.O. Box 100360, ':chorage, AK Transmittal#: 94045 ~ ~' Subject: From/Location: Telephone: To/Location: fit.--- I1~ q~ -f"5- '7"~ ARCO Cased Hole Finals John E. DeGrey/ATO-1529 (907) 263-4310 Distribution JUN 2 o f994 0!! & (3as Cons. C0mrrlission , Numberi (M-D-Y) ;/q-'CO[ 1-10A I 06-02-94 i/ USIT i 1, 5" ! 2-33 [ 05-22-941f CNL [ 1,5" ! 3-18A i 05-19-94 l~ CCL [ 1,5" i 3-27 R u n, Contractor { Scale I. 05-24-94 !,"BAKER IBP REC [ 1, 5" 05-26-94 !/ PERF REC i 1, 5" 06-04-94 l/ INJ PROFILE i 1, 5" 05-25-94 lJ USIT i 1, 5" 06-04-94 ~Production Profile f 1, 1" 5" [ 4-07ST i 4-11A 4-19 4-46 5-3A i, 06-02-94 i/. CCL ! 1, 5" 6-3 i 06-03-94 i/' PERF REC i 1, 5" 6-10 i 05-22-94 [/P~atch Setting Rec I 1, 5" 6-16 , 06-05-94 ICTubl~ing Puncher I 6-22A i: 05-22-94 !./~ CNL ! 1,5" 7-4A [ 05-21-94 iv/ CNL [ 1, 5" 1, 5" SCH SCH 7-6 [ 05-21-94 ivProduction Profile I 1, 5" 7-7A [ 05-20-94 t / Pref Rec [ 1, 5" 7-18 ! 05-21-94 i" CNL i 1, 5" 7-23 [ 05-24-94 I/ CCL [ 1, 1" 5" 7-26 i 05-21-94 i,." Prod Profile I 1, 5" 7-28 i 05-26-94 tv 9-13 ! 05-25-94 ! ,- Bridge Plug 9-44 ! 05-20-94 FProduction Profile 1, 5" 9-50 [ 05-20-94 i 14-12 ~'-I~rO i 14-20 i ¢2.~.,[~ [ 14-34 i ¢\~ 2..~- [ 16-13 8q-I ~¥~ [ 17-12 11-291 i05-31-94 1-291 {05-30-94 1 11-291 05-31-94 11-291 i05-30-94 11-35 [05-31-94 11-35 05-31-94 11-36 !05123-94 14-3 i06-03-94 14-12 i05-28-94 05-28-94 1, 5" SCH 1, 5" SCH SCH ¢6-01-94 06-01-94 SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH i SCH i SCH SCH SCH SCH SCH SCH l/Production Profile [ t/' CNL i 1, 5" ] -- USIT ,-~ TDT--{ CBT /' USIT CBT CBT ~ PERF REC i'"' G RLOG "Production Profile ~/' PERF REC / PERF REC 1, 1" 5" SCH -' Pack Off Gas Lift l/Tubing Puncher 1 5" 1 5" I 5" 1 5" 1 5" I 5" 1 5" I 5" I 5" 1 5" 15" 1 5" 1, 1 2" 5" SCH SCH 1 511 SCH SCH SCH SCH SCH SCH SCH SCH SCH SCH 05-24-94 ~ Baker IBP Rec SCH 06-05-94 / Leak Detection SCH 05-26-94 ~ PERF REC 1, 5" SCH 18-1 i 06-04-94 1, 5" SCH O6-O4-94 SCH ARCO AlasKa, Inc. Is a Subsidiary of AtlantlcRIchfieldCompany ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 12-2-93 REFERENCE: ARCO CASED HOLE FINALS 7/?-I/~ . 1-3 10-31-93 ?v~ Z/~ 1-4 11-5-93 ~- 16 11-5-93 ~?_- ~?~__1-22 .11-7-93 -24A 10-14-93 -26 10-31-93 _~,~, ~ --1-28 11-6-93 ~4~~-30 10-31-93 10-17-93 -' 11-9-93 4-4 11-2-93 11-8-93 ~t~__!~] ~-2aa 11-2-93 ~' ~1~?-29 ~ 1-4-93 10-25-05 ~_1:34 9-49 11-1-93 1-12 11-9-93 10-20-93 11-8-93 2216A 11-8-93 *~3-2A 11-2-93 ~~i4-4 11-6-93 ,1.1o.,3 10-19-93 and return the attached copy. as RECEIVED B¥__~ ~ Have l Nice Day! Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA Perf Record ]Sq~ % -JID0~. Run 1, ~' Sch Perf Record ~-~-q~'~ Run 1, 5" Sch D~ Brat T~P ]t~00--1160~ R~ 1, ~' Sch Peri Record ~9~O~lO~Z~ R~ 1, ~' Sch Pe~ Record ~0-~Sl~ R~ 1, ~' Sch Completion Record ~0~a~ R~ 1, ~' Sch USIT ~C~l~tm~m~ Color R~ 1, ~' 590~0ta~ Sch Pe~ Record ~S~ ~Z~5 R~ 1, ~' Sch TBG Patch Record R~ 1, ~' '~0~5-7;~ Sch ~od ~offie~Ny~/ta~/~ R~ 1, 1"&5" 0-l~0~ Sch Collar (Packer Set) . R~ 1, ~' W~O~i0q~ Atlas D~ B~st TDTP i;~O~{~oaO R~ 1, ~' Sch Pe~ Record ~O~qg~O R~ 1, ~' Sch Pe~ Record I~~{~ R~ 1, ~' Sch ~od ~offie iSt~r~l~}i~aR~ 1, 1"~" ~l~.~a Sch IBP Set ~0~ R~ 1, ~' Sch Le~ Detect/5O~0}~}~ ~,~ 1, 1" ~~ Sch Pe~ Record ~[ o~ ~~ R~ 1, ~' Sch Pe~ Record t l~ ~ ~ i~ R~ 2, ~' Sch ~ak Detect ~O~l~O R~ 1, 1'&5' Sch Peal Record ~~ R~ 1, ~' Sch ~ Detect(~t]~li~ , ~ 1, ~'~" 0- ~o Sch TBG ~cher Z~-~5o R~ 1, ~' Sch Pe~ Record ~00~0~ R~ 1, ~' Sch D~ B~st~o~~TP5 ~ ~ R~ 1, ~' Sch receipt of data. ~ 93145 ~ "u/I8 ~ ~ 1~ ~ MOBIL The correct API# for 3-20A is 50-029-20980-01. This log was ran on 4-11 not the sidetrack and the correct API# is 50-029-20286-00. The correct API# for 9-7 is 50-029-20223-00. This log was ran on 12-16A and the correct API# is 50-029-20899-01. he correct API# for 18-29A is 50-029-22316-01. STATE OF ALASKA ALASKA ~ _ AND GAS CONSERVATION CO, .IISSION REPORT OF SUNDRY WELL OPERATIONS 1 Operations performed: Operation shutdown Stimulate Plugging Perforate X ,// I Pull tubing ~ Alter casing ~ Repair well --..-- Other ~'7~ "2.ARcOName of OperatorAlaska~ Inc. 5. Type of WellDevelopmentExploratory X I6. Datum °f elevati°n(DF °r~,f,~t1'-~¢;.,,.2 RKB' -" -' ' 3. Address Stratigraphic ' 7. Unit or Property P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1727' NSL, 6' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 262' SNL, 304' WEL, Sec. 12, T10N, R15E, UM At effective depth At total depth 381' SNL, 74' WEL, Sec. 12, T10N, R15E, UM Service Prudhoe Bay Unit 8. Well number 9-50 9. Permit number/approval number 92-149 10. APl number 50 - 029-22325 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: 11212 feet Plugs(measured) 9214 feet Casing Conductor Sudace Production Liner measured 11132 feet true vertical 9148 feet Junk(measured) Length Size Cemented Measured depth True vertical depth 78' 20" 281 CU ft AS 110' 110' 3946' 13-3/8" 2927 cuft CS 111/478 cuft CL 'G' 3978' 3978' 10710' 9-5/8" 1462 cu ft CL 'G' 10738' 8821' 628' 7" 97 cu ft CI 'G' 10584-11212' 8692-9222' Perforation depth: measured 10746-10770';10842-10852';10882-10888 true vertical 8828-8848';8909-8918';8943-8948' Tubing (size, grade, and measured depth) 7",26~,13CR-80 @ 3302' MD;7" x 5-1/2" xover @ 3302'MD;5-1/2",17#,13CR-80 @ 10540' MD;5-1/2" x 4-1/2" xover @ 10540' MD;4-1/2",12.6#,13CR-80 w/tail @ 10592' MD Packers and SSSV (type and measured depth) 9-5/8" x 5-1/2" Baker SB-3A Hydroset pkr @ 10525' MD,7" Camco BaI-O SSSV @ 2157' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) Treatment description including volumes used and final pressure 14. Representative Daily Averaae Production or In!ection D~ta Prior to well operation Subsequent to operation OiI-Bbl Gas-Md W~e>Bbl 420 ~.,~ 855 2353 520 ~ 1284 2485 Casing Pressure . ri r,/- r_ i %1 r' r~ t~ I;;~wL I V LI./ DEC 1 3 199;) u, & Gas Cons. c0mmlssi0r Anchr, mG; Tubing Pressure 262 298 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certifsthat the foregoing is true and correct to the best of my knowledge. Signed ~'~ ~'~ ~ Title FS-2 Senior Engineer Date Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ,k,,aILY REPORT OF WELL OPER?,~ ~ONS DS 9-50 Perforatin~ Ooerations: ARCO Alaska, Inc. perforated DS 9-50 at a selected interval in the Sadlerochit Sand of the Prudhoe Bay Unit on 11/1/93. The interval perforated was the following: 10746' - 10766' MD (Reference Log: $WS- DLL/MSFL dated 2/9/93). Completion fluid was in the wellbore during perforating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure. A short summary of the work is given below: Began perforating operations on 11/1/93. RU perforating unit, pressure tested BOP's and lubricator, okay. SI well, RIH, opened well to flow and perforated 10746'-10766' MD at 4 SPF, POOH, and confirmed all shots fired. (reft SWS-DLL/MSFL of 2/9/93). Rigged down and secured well. RECEIVED DEC 1 ,~ 199~x Alaska Uti & Gas Cons. Commission Anchorage RDC: 12/2/93 STATE OF ALASKA ALASKA' . AND GAS CONSERVATION CE '~,IISSION REPORT ,JF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Pull [ub~no.. ~ I)~velor. m~erll X ARCO Alaska, Inc. L:xp~or~,to~y ~ 55' RKB 3. Address Straligraphic 7. Uniter Property P.O. Box 100360, Anchorage, AK 99510-0360 se,'v,ce 4. Location of well at sur[ace 8. Well number 1727' NSL, 6' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 262' SNL, 304' WEL, Sec. 12, T10N, R15E, UM At effective depth At total depth 381' SNL, 74' WEL, Sec. 12, T10N, R15E, UM 9-50 9. Permit number/approval number 92-149 10. APl number 50 - 029-22325 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary 'Total depth' measured true vertical 11212 feet Plugs(measured) 9214 feet Effective depth: measured ! 1132 feet true vedical 9148 feet Junk(rneasured) Casing Length Size Cemented Measured deplh True vertical depth Conductor 78' 20" 281 cu li AS 110' 110' Sudace 3946' 13--3/8" 2927 ouft CS 111/478 cu It Cl.. 'G' 3978' 3978' Production 10710' 9-5/8" 1462 cu It CI_ 'G' 10738' 8821' Liner 628' 7" 97 cu fl Cl 'G' 10584-11212' 8692-9222' F'e~fforation depth: measured 10746-10770';10842-10852"10882-10888 true vedical 8828-8848';8909-8918' ;8943-8948' 7",26#,!3CR 80 @ 3302' MD:7" x 5-1/2" xovor (5) 330O'MD.5 1/2" 17#.13CR-80 @ 10540' 'tubing (size, grade, and measured depth) MD:5 1..'2" x 4 1/2" xovor (~ 10540' MD:4-1/2':.1~.(~'~ l~iR ~0 ,^,/t,~il ._Eh 10592' MO' F'ackers and SSSV (type and measured depth) 9-5"8" x 5 1,"2" Baker SB. 3A Hydroset pkr ~ 10525' MD.7" Camco Bal O SSSV ((~ 2157' MD 13. Stimulation or cement squeeze summary REC E i V~"~ Intervals treated(measured) Treatment description including volumes used and final pressure S E P - 9 199;~ Alaska Oil & Gas Cons. 14. Oit-Bbi (:~. ~, .... _, f".,,'~., W ate r- Bbl Oasin¢~ [:~r essl~re.. Tubing P~ essure Prior [o well operation 0 (.) 0 0 r~ t~ Subsequent to operation 2~ 00~ 3750 2500 15. Attachments ] 16. Slatus of well cl~ssification as' Copies of Logs and Surveys run ~ ! Daily Report of Well Operations ~ Oil X Gas Suspended Service 17. I h,~r,:_~by cedify that the foregoing is true and correct to the best of my knowledge. ~Signed, _ r,J-,~' 'Title FS-2 Senior Engineer Form 10-404 Re~06/15/88 - · ' 300 SUBMIT IN DUPLICATE i JLY REPORT OF WELL OPER. 'ONS DS 9-50 Perforatin~Operations: ARCO Alaska, Inc. perforated DS 9-50 at selected intervals in the Sadlerochit Sand of the Prudhoe Bay 'Unit on 2/211/93. The intervals perforated were the following: 10746' - 10770', 10842' - 10852' and 10882' - 10888' MD (Reference I~og: SWS-DIA./MSFL dated 2/9/93). Completion fluid was in the wellbore (]uring perf()rating operations. All wireline work was done through a 5000 psi WP BOP/Lubricator tested to 1.2 times the maximum expected surface pressure, A short summary of the work is ,aivcn below: Began perforating operations on 2/21/93. RU perforating unit, pressure tested BOP's and lubricator to 3500 psi, ()kay. RIH and perforated 10882'-10888' MD at 4 SPF, Lo,aged up and perforated 1.0842'--10852' MI) at 4 SPF, POOH, and confirmed all shots fired. RIH and perforated 10746'-10770' MD at 4 SI)F, POOl.t, and confirmed all shots fired, (ref: SWS-D1J./MSFI~ of ~/9/93). Rig,tled dm,mn and secured well. RECEIVED S E P - 9 199;S Alaska Oil & Gas Cons. ^nchorag~ RI)C: 8/30/93 ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 5-10-93 REFERENCE: ARCO DIRECTIONAL DATA 12-20-92 2-25-93 2-27-93 4-19-93 4-9-93 3-19-93 3-23-93 4-18-93 2-23-93 2-26-93 3-7-93 3-13-93 4-6-93 4-15-93 3-7-93 4-1-93 12/6-23/92 1/23-2/6/93 MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey Electronic Multi-Shot Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey MWD Directional Survey ~GI-8 ~.~-~ ~AGI-10 3-30-93 MWD Directional Please sign and return the attached copy as 12/30-1/15/93 MWD Directional Survey 12-9-91 MWD Directional Survey 1-15-92 MWD Directional Survey 1/92 MWD Directional Survey 2-9-93 MWD Directional Survey 1-16-93 MWD Directional Survey 12-27-92 MWD Directional Survey 1-18-93 MWD Directional Survey 1-17-93 MWD Directional Survey 2-16-93 MWD Directional Survey 2-24-93 MWD Directional Survey 4-28-93 MWD Directional 'Survey 3-7-93 MWD Directional Survey 3-17-93 MWD Directional Survey Survey Job#AKEI30010 Job#1209 Job#AKEI30016 Job#AKMW30020 Job# 1188 Job#AKEI30009 Job#1192 Job#AKEI30012 Job#1202 Job#1159 Job#1175 Job#1167 Job#AKMM911128 Job#AKMM911231 Job#AKMW30003 Job#AKMM921231 Job#1168 Job#1172 Job# 1185-450 Job # 1185 Job # 1190 Job# 1195-450 Job#1205 receipt of data. Sperry BHI Ana Ana Sperry Sperry Teleco Sperry Teleco Sperry BHI Ana Ana Ana Teleco Teleco Teleco Sperry Sperry Sperry Ana Sperry Sperry Teleco Teleco Teleco Teleco Teleco Teleco Teleco BHI Have A Nice Day? Sonya Wallace ATO- 1529 CHEVRON # CLINT CHAPMAN # EXXON MOBIL ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 7-20-93 REFERENCE: ARCO CASED HOLE * 1_1B~ I'~ °~6_20.93 1-16 7~'°~.~ 6-25-93 1-22 ~.~/l~. 6-29-93 1-30 ~;~' ~ ~o 6-29-93 3-25A ~'~ 6-27-93 3-30 ~--~ 6-23-93 3-31 ~ ~ ~ z~6-23-93 3-33 ~-I/o 6-29-93 3-36 ~-l~ 6-28-93 4-37 ~/~? 6-20-93 4-40 ~ N t3~6-20-93 5-3A q3~f 6-18-93 5-26 Tq~ ~ 6-25-93 6-4 7~- cz~6-26-93 6-13 ~ -30 6-25-93 9-49 ~} ~-- I'~ 6-22-93 9-50 ~'=-~ 6-26-93 12-26e~-~ 6-22-93 13-17 ~~ 6-27-93 13-14 ?=-~71 6-28-93 13-20 ~ -~? 6-19-93 16-12 ~l-~e 6-21-93 17-20 ~-~'6-26-93 ?~!AGI-6 ~ ~.o,e 4-25-93 AGI-8 ~-~6-19-93' *** AGI-10 El ~$~ 6_- 18-93 *** AGI- 10-'6-18-93 Prod Profile Perf Record Production Log Leak Detect Perf Record Leak Detect Bridge Plug Setting Completion Record Perf Record Dual Bur~t T~Yr~ (Borax) Completion Record SBT/~/C~ TDTP (Borax) Production Log Perf Record Production Log -Production Log CNL Le~l~ Detect Leak Detect Plug Depth Record Prod Profile Production Log a'~Acoustic CBT Perf RecOrd GR/CCL Perf Record Run 1, 5" Sch R._- 1, 5" Sch R._- 1, 5" Sch Run 1, 5" Sch R-n 1, 5" Sch Run 1, 2"&5" Sch R-- 1, 5" Sch Run 1, 5" Sch Rim 1, 5" Sch Run 1, 5" Sch R.n 1, 5" Sch Rim 1, 5" Atlas R.n 1, 5" Sch R.n 1, 5" Sch Run 1, 5" Sch R-n 1, 1"&5" Sch Run 1, 2"&5" Sch R'" 1, 5" Sch Run 1, 2" Sch R-- 1, 2" Sch Run 1, 5" Sch Run 1, 1"&5" Sch R-- 1, 5" Sch Run 1, 5" Arias Run 1, 5" Sch Run 1, 5" Sch Rlrn 1, 5" Sch Please sign and return the attached .c~p~ as receipt of data. RECEIVED B~/~~ Have A Nice Day//' ' / Sonya Wallace APPROVED ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA The correct -_-_me for this log is 1-LB. This is a revised log, please discard previous copy received. The correct APl# for AGI-10 is 50-02~2235~. - ECEIVED # mm,ui, s 'JUL 3 0 199~ # CLINT CHAPMAN ~ ~ONMos~ Na,ka 011 & ~as Cons. Commi**ion Anchorage STATE OF ALASKA ALASKA'!--''' AND GAS CONSERVATION C(~'""AISSION REPORT UF SUNDRY WELL OPERATIONS 1. Operations performed: operation shutdown Stimulate X Pull tubing Alter casing Plugging Perforate Repair well Other 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 1727' NSL, 6' WEL, Sec. 2, T10N, R15E, UM At top of productive interval 262' SNL, 304' WEL, Sec. 12, T10N, R15E, UM At effective depth At total depth 381' SNL, 74' WEL, Sec. 12, T10N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service 6. Datum of elevation(DF or KB) 55 RKB 7. Unit or Property Prudhoe Bay Unit 8. Well number 9-50 9. Permit number/approval number 92-149 10. APl number 50 - 029-22325 11. Field/Pool Prudhoe Bay Oil Pool feet 12. Present well condition summary Total depth: measured true vertical 11212 feet 9214 feet Plugs(measured) PBTD Tag @ 11049' M D (4/27/93) Effective depth: measured 11049 feet true vertical 9053 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 110' 20" 281 cu ft AS 110' 110' Surface 3923' 13-3/8" 2927 cu ft CS III & 478 cuft G 3978' Production 10683 9-5/8" 1462 cuft CIG 10738' 8766' Liner 628' 7" 97 cuft CIG 11212' 9214' Perforation depth: measured 10746-10770'; 10842-10852'; 10882-10888' true vertical 8773-8794'; 8855-8864'; 8889-8894' Tubing (size, grade, and measured depth) 7", 26~, 13 Cr, NSCC Tbg @ 3302' MD; 5-1/2", 17#, 13 Cr, NSCC Tbg @ 10540' MD; 4-1/2", 12.6~, 13 Cr, Tbg @ 10592' MD Packers and SSSV (type and measured depth) Baker SB-3A, Hyd Packer @ 10525'MD; 7", Camco BaI-O SSSV @ 2157' MD D ECl: I~/EI'~ 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation !\ L ~,., L I V JUN 3 0 199; Alaska 0il & Gas Cons. Commissio~ Representative Daily Average Production or In!ection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 830 696 1847 - 313 527 // 813 2611 307 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil x...~_ Gas__ Suspended..._ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor Form 10-404 Rev 06/15/88 1009/3 DAC cc: SW. JWP SUBMIT IN DUPLICATE 9-50 DESCRIPTION OF WORK COMPLETED ACID STIMULATION TREATMENT W/SST TOOL 4/27/93: RIH & tagged bottom fill at 11049' MD. 5/11/93: An Acid Stimulation Treatment using an SST Tool was performed as follows: MIRU CT & PT equipment to 4200 psi. Loaded the wellbore w/1% NH4CI Water & Crude, then RIH w/CT mounted SST Tool & made three sets to treat the two upper perforation intervals located at: 10746 - 10770' MD (Z3) 10842 - 10852' MD (Z2) Ref. Log: SWS LDT 2/9/93. Note: the lower perforation interval at 10882' - 10888' MD was not treated. Inflated SST elements to make first tool set at 10746 - 10756' MD, then proceeded pumping Stage #1 consisting of 15 bbls 50% Diesel/50% Xylene Preflush @ 1.0 bpm, followed by 15 bbls 15% HCL @ 1.0 bpm, followed by 25 bbls 9% HCL - 1% HF @ 1.8 bpm, followed by 110 bbls 1% NH4Cl Water Overflush @ 1.7 bpm. Deflated SST Tool elements to relocate tool. Inflated SST elements to make second tool set at 10760 - 10770' MD, then proceeded pumping Stage #2 consisting of 15 bbls 50% Diesel/50% Xylene Preflush @ 1.5 bpm, followed by 15 bbls 15% HCL @ 1.0 bpm, followed by 25 bbls 9% HCL - 1% HF @ 1.6 bpm, followed by 110 bbls 1% NH4Cl Water Overflush @ 1.5 bpm. Deflated SST Tool elements to relocate tool. Inflated SST elements to make third tool set at 10842 - 10852' MD, then proceeded pumping Stage #3 consisting of 15 bbls 50% Diesel/50% Xylene Preflush @ 1.6 bpm, followed by 18 bbls 15% HCL @ 1.5 bpm, followed by 27 bbls 9% HCL - 1% HF @ 2.0 bpm, followed by 110 bbls 1% NH4Cl Water @ 2.0 bpm. Deflated SST Tool elements. POOH w/CT & SST Tool. Rigged down. 5/17193: Pumped an ESL Scale Inhibition Treatment. Returned well to production w/gaslift & obtained a valid production test. RECEIVED JUN 3 0 199J Alaska Oil & Gas Cons. Anchorage ARCO ,~l~s~; Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 04--22-93 REFERENCE: --1-5ST 3-15-93 /~-14 3-14-93 03-15A 3-14-93 '~a-lm~ 3-~6-93 --3-18 3-14-93 ~1~ ~1~93 ~1 ~1~93 ~-SA-~-~ ~1~93 ~~ ~1~93 ~1~93 ~1~14 ~17-~ ~1~ 14 ~ 17-93 ~1~18 ~17-93 Production Log Production Log Spin/Temp/Gradio/Press CBT USIT (Cement & Corrosion) Peri Record PeriRecord Peri Record T~,h~ng Cllt ~ Production Log Ih~xluc~n I~g Inj Prof/Spin/Temp/Press Production Log PITS Production Log PeriRecard Press/Temp ~1, ~' Sch Run 1, ~' Sch Run 1, ~' Sch Color Run 1, [~' Sch Color Run 1, ~' Sch Run 1, [~' Sch Run 1,/~' Sch Run 1, ~' Sch Run 1, ~' Sch Run 1, [~' Sch ~o~ Run 1, 2'~' Sch Run 1, ~' Sch Run 1, ~' Sch Run 1, 2'&~' Sch Run 1, ~' Sch Run 1, ~' Sch l~_m 1, ~' Sch Run 1, ~' Sch Run 1, ~' Sch l~m 1, [~' Sch Run 1, ~' Sch Run 1, ~' Sch Please sign and return the attached copy as receipt of data. RECEIVED BY_~_~_~~ Have A Nice Day! APPROVED__ Trans# 93048 Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # LUCILLE JOHNSTON # EXXON # MOBIL # PHILLIPS PB WELL FILF~ # BPX # STATE OF ALASKA * The correct APl# for 1-5ST is 50-029-20076-00. m" STATE OF ALASKA "MIS ALASKA 0IL AND GAS CONSERVATION C~, I AND LU WELL COMPLETION OR RECOMP LETION REPORTG 1, Status of Well Classification of Service Well OIL [] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 92-149 3. Address 8. APl Number P. 0. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22325 4. Location of well at surface 9. Unit or Lease Name 172~ NSL, 6' WEL, SEC. 2, TION, R15E, UM ¢%,~i~:~.~ ............ LOCATIOI~ Prudhoe Bay Unit At Top Producing Interval ~ ..... ..~v ~ VE.~1/tED 10. Well Number 9-50 262' SNL, 304' WEL, SEC. 12, TION, R15E, UM j 'J~/~--:.-/-Z¢~ ] At Total Depth ~ ~/ERiFjE'ii .... ~ ~~ 11. Field and Pool L~.~..d.~ ~ Prudhoe Bay Field/Prudhoe Bay Pool 381'SNL, .74' WEL, SEC. 12, TION, R15E, UM 15. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. KBE = 55' I ADL 28327 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. 115. Water Depth, if offshore 116. No. ol Completions 1/24/93 2/9/93 2/21/93I N/A feet MSL I One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey ~20. Depth where SSSV set ~1. Thickness of Permafrost 11212' MD/9214' TVD 11132' MD/9148' TVD YES E] N~) []! 2157'feet MD ! 1900'(Approx.) 22. Type Electric or Other Logs Run MSFL/DLL/LD~T/CNL/GR 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP BO'I-I'OM HOLE SIZE CEMENTING RECORD AMOUNT PULI.ED 20" 91.5# H-40 32' 110' 30" 281 cu ft Arcticset 13-3/8" 68# L-80 32' 3978' 16" 2927 cu fl CS 111/478 cu ft "G' 9-5/8" 47# L-80 28' 10738' 12-1/4" 1462 cu fl Class "G" 7" 29# 13CR80 10601' 11211' 8-1/2" 97 cu fl Class "G" 24. Pedorations open to Production (MD+TVD of Top and Bottom and 25. TUBI'¢2 REC, ORD interval, size and number) SIZE DEPTH SET(MDI PACKER SET (MD) Gun Diameter 3-3/8" 4sp_f 7"x 5-1/2" 10593' 10525' MD 10746'-10770' 8773'-8794' 10842'-10852' 8855'-8864' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 10882'-10888' 8889'-8894' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL~ 27. PRODUCTION TEST Date First Production IMethod of Operation (Flowing, gas lift, etc.) 2/21/93 I Fiowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKESIZE IGAS-OIL RATIO TEST PERIOD I~ I Flow Tubing Casing Pressure 3ALCULATED OIL-BBL GAS-MCF iWATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE I~ 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. ECE1VED Aiask~ u,t & Gas G0nso Ar~ch0rage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate 29. 30. GEOLOGIC MARKER~ ,-ORMATION TESTS NAME ... Include inlerval tesled, pressure dala, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 10744' 8771' Zone 2 10778' 8800' Base Sadlerochit 11070' 9047' Aias~c.~ 0ii & ~a3 Cons. Com~nission Ar~chorago _ 31. LIST OF ATTACHMENTS Signed Title Drilling Engineer Suoervisor Date ~;~' INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 BP/AAI SHARED SERVICE DAILY OPERATIONS PAGE: 1 WELL: DS 9-50 BOROUGH: NORTH SLOPE UNIT: PRUDHOE BAY FIELD: PRUDHOE BAY LEASE: API: 50- PERMIT: APPROVAL: ACCEPT: 01/23/93 04:00 SPUD: 01/24/93 12:30 RELEASE: OPERATION: DRLG RIG: NABORS 18E WO/C RIG: NABORS 18E 01/23/93 ( 1) TD: 0'( 0) 01/24/93 ( 2) TD: 590' ( 590) 01/25/93 ( 3) TD: 1513'( 923) 01/26/93 ( 4) TD: 3240' (1727) NU DIVERTER MW: 0.0 VIS: 0 TURNKEY MOVE. NU DIVERTER & TAKE ON WATER. RIG ACCEPTED 1-23-93 @ 04:00. DRLG MW: 8.6 VIS:275 MIX SPUD & PU BHA. RU INJ LINE. DRLG TO 590. REPAIR SHAKER. DRLG W/BIT #1. DRLG W/MUD MOTOR MW: 8.6 VIS:160 DRLG TO 673, REPAIR SUN TRANS PUMP. DRLG TO 949. REPAIR SUN TRASH PUMP. SHORT TRIP, WASH & REAM. DRLG TO 1513. POH, PU MUD ASSY & RIH. DRLG. DRLG W/BIT #2 DRLG TO 3240 W/BIT #2 & MUD MTR. MW: 9.2 VlS:100 01/27/93 ( 5) TD: 4005'( 765) 01/28/93 ( 6) TD: 4005' ( 0) 01/29/93 ( 7) TD: 4300' ( 295) 01/30/93 (8) TD: 6250' (1950) 01/31/93 (9) TD: 7185' ( 935) 02/01/93 (10) TD: 8060' ( 875) RU TO RUN 13-3/8 CSG MW: 9.4 VIS:100 DRLG TO 4005. CBU, DROP SURV. POH TO RUN 13-3/8 CSG. CUT 13-3/8 CSG MW: 9.2 VIS: 72 RU & RUN CSG TO 3979. STUCK CSG. PU ANNULAR, CIRC. MIX & PUMP LEAD & TAIL SLURRY. BUMP PLUG. ND ANNULAR & CUT OFF FLANGE. TOP JOB CMT. INSTL EMERGENCY SLIPS & CUT CSG. DRLG 12-1/4" HOLE MW: 8.8 VIS: 36 PREPARE 13-3/8" CSG. NU SPEED HEAD & BOPS. TEST BOPS. PICK UP 12-1/4" BHA. RIH. TEST CSG. DRILL FLOAT EQUIP. CBU. DRLG. NEW HOLE. DRLG & SURVEYS MW: 9.2 VIS: 37 DRLG & SURV. WELD LEAK IN MUD LINE. DRLG, ROTATING & SLIDING. DRILLING MW: 9.4 VIS: 37 DRLG & SURV TO 6941. DROP SURV, PUMP DRY JOB & POH. CHG BIT & RIH. DRLG & SURV TO 7185. DRLG & SURV MW: 9.4 VIS: 42 DRLG & SURV TO 7856. TRIPPING, HOLE CLEAN. REPAIR WASHOUT ON MUD LINE. DRLG TO 8060. WELL : DS 9-50 OPERATION: RIG : NABORS 18E PAGE: 2 02/02/93 (11) TD: 9000'( 940) 02/03/93 (12) TD: 9400' ( 400) 02/04/93 (13) TD:10100' ( 700) 02/05/93 (14) TD:10380' ( 280) 02/06/93 (15) TD:10748' ( 368) 02/07/93 (16) TD: 10748' ( 0) 02/08/93 (17) TD:10748' ( 0) 02/09/93 (18) TD:lll60' ( 412) 02/10/93 (19) TD:l1212' ( 52) 02/11/93 (20) TD:11212 PB:11131 DRLG W/12.25 PDC BIT MW: 9.5 VIS: 40 DRLG & SURV, POH. SERV WEAR RING & CHG OUT MUD MTRS. RIH. DRLG TO 9000. DRLG MW: 9.7 VIS: 44 DRLD TO 9014, POH, CHG BHA, RIH. DRLD TO 9046, LEAKING MYD PUMP LINE, REPAIR. DRLD TO 9330, TRIPPED FOR BHA. POH, CHG BHA, DRLD TO 9400. DRLG MW: 9.9 VIS: 42 DRLD TO 9945. PUMP PILL, POH. LD MTR & PU MTR ASSY. RIH. DRLG TO 10100. RIH W/BIT MW: 9.8 VIS: 42 DRLG FORMATION TO 10380. MIX PUMP DRY JOB, POH. BUILD NEW BHA. RIH W/#8 BIT. POH TO RUN INT CSG MW: 9.9 VIS: 41 RIH, PU KELLY & REAM. WASHED & REAMED TO 10350. DRILLED TO 10748. SHORT TRIP. CBU, PUMP SWEEP & DRY JOB. RUN CSG ". MW:10.1 VIS: 52 POH, CHG OUT CASG RAMS. LD BHA, RU TO RUN 9-5/8 CSG. RIH. WASH DN CSG, CIRC HEAD. WASHED TO BTTM, LAND CASG. CBU. P/T LINES, PUMPED CMT. BUMP PLUG, CHECK FLOATS. CIP. RD & PUMP DN CSG ANNULUS. RAN 271 JTS OF 9-5/8 CSG. RIH W/BIT #9 MW: 9.1 VIS: 39 CLEAR FLOOR, INSTL PKOFF & TEST. INSTL BOP TEST PLUG, TEST. INSTL WEAR RING. MY BHA 99, INSTL NEW MUD LINE & TEST. RIH. CBU, RIH W/BHA 99. DRLG W/BIT #9 MW: 9.3 VIS: 41 RIH, TEST CSG. DRLG FIRM CMT & FLOAT EQUIP. DRLG NEW HOLE TO 10758. CHG OVER MUD, DRLG W/BIT #9. POH TO RUN 7" LINER MW: 9.4 VIS: 46 DRLG 8.5 HOLE. CIRC HI VIS SWEEP. DROP SURV. POH, RU & RUN LOGS. SERV WEAR RING. RIH, CIRC CLEAN HOLE. POH TO RUN LINER. POH W/SETTING TOOL MW: 0.0 INSTALL RAMS. POH, RU & RUN 7" CR & LINER HGR. CIRC. RIH W/LINER. CBU, RIH. CIRC, RECIP PIPE. TEST CMT LINES, PUMP PREFLUSH & CMT. BUMP PLUG, SET HGR & LINER. REV OUT CMT, POH W/LINER RUNNING TOOL. WELL : DS 9-50 OPERATION: RIG : NABORS 18E PAGE: 3 02/12/93 (21) TD:11212 PB:11132 02/13/93 (22) TD:l1212 PB:ll132 RUNNING 5.5" TBG MW: 8.5 Seawater FINISH POH, LD LINER RUNNING TOOL. PU & MU BHA 4-3/4 DC & DP & RIH. CBU, TEST LINER. RU & REV FILTERED SW, POH. CHG RAMS, RU CSG EQUIP & RUN TBG. LANDING TBG. MW: 8.5 Seawater PU & MU & RIH W/ TBG. PU TBG & CONTROL LINES &TEST. LAND TBG. 02/14/93 (23) TD:l1212 PB:ll132 TURN KEY MOVE MW: 8.5 Seawater RUN & LAND TBG, SET PKR. TEST TBG;. ND BOP & NU TREE, TEST. FREEZE PROT TBG. CLEAN MUD PIT & CELLAR. RELEASE RIG 2-13-93 @ 2100 HRS. MOVING RIG. SIGNATURE: (drilling superintendent) DATE: / /?I Ei STMI N ORISiNAL EASTMAN TELECO MWD SURVEY WELL #9-50 PRUDHOE BAY Eastman Teleco appreciates the oppo~unity to pruvide our services. Please find attached a copy of the directional surveys in each of the following formats: · No Interpolation · 100' MD Interpolated · 100' TVD Interpolated RECEIVED Alaska Oil & Gas Cons, Co~issio~ Anchorage, Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Well Name Location Date Surveyed Survey Performed By : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope : Jan 23-Feb 6, '93 : : Craig E. Tomayer This survey is correct to the best of my knowledge and is supported by actual field data. COMPANY REPRESENTATIVE MEASURED DEPTH NO INTERPOLATION Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-50 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation Date Jan 23-Feb 6, '93 Filename : 1175 Plane of Vertical Section : 111.7° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) Eastman Teleco Client : Prudhoe Bay Nell Name ' DS 9-50 Location : Drill Site 9 : Prudhoe Bay : North Slope No Interpolation Drilling Page 1 of 3 Date Jan 23-Feb Filename : 1175 '93 MD CkL INC DIR ft ft deg deg 0 0 0.0 0.0 164 164 0.4 237.3 256 92 0.4 202.2 348 92 0.3 234.5 440 92 0.4 189.8 TVD ft 0 164 256 348 440 VS ft 0 -0 -1 -1 -1 LAT ft 0 -0 -1 -1 -2 DEP D'LEG BUILD ft °/100 °/100 0 0.0 0.0 -0 0.2 0.2 -1 0.3 0.0 -1 0.2 -0.1 -1 0.3 0.1 TURN o/loo 0.0 -74.8 -38.2 35.1 -48.6 534 94 0'.4 240.8 626 92 0.5 219.7 718 92 0.2 237.7 809 91 0.4 248.6 902 93 0.8 224.0 534 -1 -2 -2 0.4 0.0 626 -1 -3 -2 0.2 0.1 718 -1 -3 -3 0 · 3 -0.3 809 -2 -3 -3 0 · 2 0.2 902 -2 -4 -4 0 · 5 0.4 54.3 -22.9 19.6 12.0 -26.5 996 94 0.6 221.8 1089 93 0.5 249.6 1183 94 1.6 228.2 1277 94 1.8 230.6 1372 95 1.9 232.7 996 1089 1183 1277 1372 -3 -3 -4 -5 -7 -5 -5 -6 -8 -10 -5 0.2 -0.2 -5 0.3 -0.1 -7 1.2 1.2 -9 0.2 0.2 -11 0.1 0.1 -2.3 29.9 -22.8 2.6 2.2 1466 94 2.0 219.4 1527 61 1.8 213.4 1622 95 1.8 92.1 1715 93 4.9 87.2 1808 93 7.1 89.7 1466 -8 -12 -14 0. 5 0.1 1527 -9 -14 -15 0.5 -0.3 1622 -8 -15 -14 3.3 0.0 1715 -3 -15 -9 3 . 3 3.3 1807 6 -15 1 2.4 2.4 -14. 1 -9.8 -99.0 -5.3 2.7 1903 95 8.9 94.6 1996 93 10.5 91.4 2088 92 11.8 93.5 2181 93 12.0 93.9 2274 93 12.7 98.4 1901 1993 2083 2174 2265 19 34 50 69 88 -15 14 2 . 0 !. 9 5.2 -16 30 i. 8 1.7 -3.4 -17 48 !. 5 1.4 2 · 3 -18 67 0.2 0.2 0.4 -20 87 1.3 0.8 4 · 8 2369 95 14.9 106.2 2462 93 17.2 111.8 2558 96 19.8 114.6 2651 93 21.9 !15.3 2745 94 24.4 113.6 2357 2447 2538 2624 2711 110 136 166 199 236 -25 109 3.0 2.3 8.2 -34 133 3.0 2.5 6.0 -46 161 2.9 2.7 2.9 -60 191 2.3 2.3 0.8 -75 225 2.8 2.7 -1.8 2840 95 26.7 114.3 2933 93 28.3 112.9 3027 94 30.7 111.1 3120 93 32.9 111.1 3215 95 34.9 110.7 2797 2879 2961 3040 3119 277 320 366 415 468 -91 262 2.4 2.4 -109 301 i. 9 1.7 -126 344 2.7 2.6 -144 390 2.4 2.4 -162 439 2. 1 2.1 0.7 -1.5 -1.9 0.0 -0.4 3306 91 36.5 111.5 3403 97 36.4 111.8 3496 93 36.4 113.2 3588 92 37.1 114.3 3680 92 37.9 114.3 3193 3271 3346 3419 3492 521 579 634 689 745 -182 489 1.8 1.8 0.9 -203 543 0.2 -0.1 0.3 -224 594 0.9 0.0 1.5 -246 644 1.0 0.8 1.2 -269 695 0.9 0.9 0.0 Eastman Teleco ~lient : Prudhoe Bay ~ell Name : DS 9-50 Location : Drill Site 9 : Prudhoe Bay : North Slope lo Interpolation Drilling MD C~L INC DIR ft ft deg deg 3772 92 38.7 114.6 3866 94 39.5 115.0 3951 85 40.1 116.4 4052 101 39.4 115.0 4144 92 39.0 115.0 TVD ft 3564 3637 3703 3780 3852 VS ft 802 861 916 980 1038 LAT ft -293 -318 -341 -369 -394 Page 2 of 3 Date Jan 23~-Feb 6, Filename : 1175 '93 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 747 0.9 0.9 0.3 801 0.9 0.9 0.4 850 1.3 0.7 1.6 908 1.1 -0.7 -1.4 961 0.4 -0.4 0.0 4238 94 38.1 115.0 4331 93 39.1 113.6 4424 93 41.7 111.8 4517 93 42.7 111.8 4611 94 42.6 111.1 3925 1097 -419 1014 1.0 -1.0 0.0 3998 1155 -442 1067 1.4 1.1 -1.5 4069 1215 -466 1122 3.1 2.8 -1.9 4138 1277 -489 1180 1.1 1.1 0.0 4207 1341 -512 1239 0.5 -0.1 -0.7 4705 94 41.8 112.5 4800 95 40.9 113.9 4894 94 40.0 113.6 4988 94 42.2 112.5 5083 95 42.5 111.8 4276 1404 -536 1298 1.3 -0.9 1.5 4348 1467 -560 1356 1.4 -0.9 1.5 4419 1528 -585 1412 1.0 -1.0 -0.3 4490 1590 -609 1468 2.5 2.3 -1.2 4560 1654 -633 1528 0.6 0.3 -0.7 5174 91 42.9 111.1 5267 93 42.9 110.7 5362 95 42.5 111.1 5457 95 42.3 111.1 5552 95 41.8 111.1 4627 1715 -656 1585 0.7 0.4 -0.8 4695 1779 -678 1644 0.3 0.0 -0.4 4765 1843 -701 1704 0.5 -0.4 0.4 4835 1907 -7'24 1764 0.2 -0.2 0.0 4906 1971 -747 1824 0.5 -0.5 0.0 5646 94 42.2 111.5 5738 92 43.2 110.7 5830 92 42.8 110.7 5924 94 43.1 111.5 6016 92 42.7 110.7 4976 2034 -770 1882 0.5 0.4 0.4 5043 2096 -793 1940 1.2 1.1 -0.9 5111 2159 -815 1999 0.4 -0.4 0.0 5179 2223 -838 2059 0.7 0.3 0.9 5247 2285 -860 2117 0.7 -0.4 -0.9 6111 95 42.8 110.4 6205 94 42.5 110.0 6299 94 41.9 111.1 6390 91 ~[~5 110.0 6483 93 41.6 111.1 5316 2350 -883 2178 0.2 0.1 -0.3 5386 2413 -905 2237 0.4 -0.3 -0.4 5455 2477 -927 2297 1.0 -0.6 1.2 5523 2537 -948 2353 0.9 -0.4 -1.2 5593 2599 -970 2411 0.8 0.1 1.2 6578 95 41.5 110.4 6672 94 40.8 110.7 6766 94 41.5 110.7 6861 95 43.6 110.7 6955 94 44.9 111.5 5664 5735 58O5 5875 5943 2662 2724 2786 2850 2915 -992 -1014 -1036 -1059 -1082 2470 0.5 -0.1 -0.7 2528 0.8 -0.7 0.3 2586 0.7 0.7 0.0 2646 2.2 2 2 0.0 2707 1.5 1.4 0.9 7049 94 44.3 111.5 7143 94 44.2 110.4 7238 95 43.9 110.4 7333 95 43.7 110.0 7427 94 43.2 108.6 6010 6077 6145 6214 6282 2981 3047 3113 3179 3243 -1107 2768 0.6 -0.6 0.0 -11'30 2830 0.8 -0.1 -1.2 -1153 2892 0.3 -0.3 0.0 -1176 2953 0.4 -0.2 -0.4 -1197 3014 1.2 -0.5 -1.5 Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-50 Location : Drill Site 9 : Prudhoe Bay ' North Slope No Interpolation MD C~L INC DIR TVD ft ft deg deg ft 7522 95 43.2 110.0 6351 7616 94 43.1 109.7 6420 7709 93 42.9 110.0 6488 7805 96 42.9 110.7 6558 7897 92 42.0 110.0 6626 Page 3 of 3 Date Jan 23-Feb 6, Filename : 1175 7990 93 42.7 109.3 6695 8085 95 41.9 110.4 6765 8180 95 41.1 111.8 6836 8273 93 41.2 112.2 6906 8367 94 41.3 113.2 6977 '93 VS LAT DEP D ' LEG BUILD TURN ft ft ft °/100 °/100 °/100 3308 -1219 3076 1.0 0.0 1.5 3372 -1240 3136 0.2 -0.1 -0.3 3436 -1262 3196 0.3 -0.2 0.3 3501 -1285 3257 0.5 0.0 0.7 3563 -1306 3315 1. 1 -1.0 -0.8 8461 94 40.6 112.5 7048 8555 94 40.2 113.9 7120 8650 95 29.4 112.2 7193 8744 94 38.7 112.5 7266 8839 95 37.9 113.2 7340 3626 3690 3753 3814 3876 -1327 3374 0.9 0.8 -0.8 -1349 3434 1.1 -0.8 1.2 · -1372 3~93 1.3 -0.8 1.5 -1395 3550 0.3 0.1 0.4 -1419 3607 0.7 0.1 1.1 8934 95 37.2 111.8 7415 9028 94 37.0 111.8 7490 9123 95 40.0 111.5 7565 9217 94 43.0 1!1.1 7635 9312 95 45.9 111.5 7703 3937 3998 4059 4118 4177 -14.42 3664 0.9 -0.7 -0.7 -1466 3720 1.1 -0.4 1.5 -1490 3776 1.4 -0.8 -1.8 -1513 3830 0.8 -0.7 0.3 -1536 3885 1.0 -0.8 0.7 9407 95 45.5 111.5 7769 9503 96 44.1 110.7 7837 9598 95 42.6 111.1 7907 9692 94 40.9 111.5 7977 9786 94 39.3 111.1 8049 4235 42~2 4351 4413 4480 -1558 3938 1.2 -0.7 -1.5 -1579 3991 0.2 -0.2 0.0 -1601 4046 3.2 3.2 -0.3 -1623 4104 3.2 3.2 -0.4 -1647 4166 3.1 3.1 0.4 9881 95 37.5 111.1 8123 9976 95 36.2 110.7 8'199 0070 94 35.7 110.4 8275 0165 95 35.6 111.8 8352 0259 94 35.9 113.6 842~ 4548 4615 4681 4743 4804 -1672 4229 0.4 -0.4 0.0 -1697 4292 1.6 -1.5 -0.8 -1720 4353 1.6 -1.6 0.4 -1743 4411 1.8 -1.8 0.4 -1765 4468 1.7 -1.7 -0.4 10352 93 36.7 114.6 8504 10446 94 36.1 115.7 8579 10541 95 34.8 116.7 8657 10634 93 33.2 118.1 8734 10693 59 32.4 117.8 8783 4863 4920 4975 5030 5085 -1786 4523 1.9 -1.9 0.0 -1806 4576 1.4 -1.4 -0.4 -1826 4628 0.6 -0.5 -0.3 -1846 4679 0.9 -0.1 1.5 -1867 4730 1.2 0.3 1.9 5140 5196 5251 5303 5334 -1889 4780 1.1 0.9 1.1 -1913 4831 0.9 -0.6 1.2 -1937 4880 1.5 -1.4 1.1 -1961 4926 1.9 -1.7 1.5 -1976 4955 1.4 -1.4 -0.5 Drigin of Bottom Hole Closure SLOT Bottom Hole Closure 5334 ft 111.7° MEASURED DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Well Name Location Date Surveyed Survey Performed By : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope : Jan 23-Feb 6, '93 : : Craig E. Tomayer This survey is correct to the best of my knowledge and is supported by actual field~ Eastman Teleco Client : Prudhoe Bay Drilling Well Name : DS 9-50 Location : Drill Site 9 : Prudhoe Bay : North Slope Date Jan 23-Feb 6, '93 Filename ' 1175 Interpolated 100 ft of MD Plane of Vertical Section : 111.7° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° O' O' ' (T) ~!ient ,~el 1 Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope Page 1 of 3 Date Jan 23-Feb 6, '93 Filename : 1175 Interpolated 100 ft of MD MD ft 0 100 200 3OO 4OO 5OO 600 700 8OO 90O 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 2900 3OOO 3100 3200 3300 3400 35OO 3600 3700 3800 3900 CkL INC DIR ft deg deg 0 0.0 0.0 100 0.2 144.7 100 0.4 223.6 100 0.4 217.6 100 0.4 209.2 100 0.4 222.4 100 0.5 225.7 100 0.3 234.2 100 0.4 247.5 100 0.8 224.5 100 0.6 223.0 100 0.6 247.1 100 1.6 228.6 100 1.8 231.1 100 1.9 228.7 100 1.9 216.1 100 1.8 120.2 100 4.4 88.0 100 6.9 89.5 100 8.8 94.4 100 10.6 91.5 100 11.8 93.6 100 12.1 94.8 100 13.3 100.5 100 15.7 108.1 100 18.2 112.9 100 20.7 114.9 100 23.2 114.4 !00 25.7 114.0 160 27.7 113.4 100 30.0 111.6 100 32.4 111.1 100 34.6 110.8 100 36.4 111.4 100 36.4 111.8 100 36.4 113.2 lC0 37.2 114.3 100 38.1 114.4 100 38.9 114.7 100 39.7 115.6 TVD ft 0 100 200 3OO 4OO 5OO 600 700 8O0 900 1000 1100 1200 1300 1400 1500 1600 1700 1799 1898 1997 2095 2193 2290 2387 2483 2577 2670 2761 2850 2937 3023 3106 3188 3268 3349 3429 3508 3586 3664 VS ft 0 -0 -0 -1 -1 -1 -1 -1 -2 -2 -3 -3 -4 -6 -7 -8 -8 -3 6 18 34 53 73 94 119 148 181 219 26,~ 305 353 405 460 518 577 637 697 758 820 883 LAT ft 0 -0 -0 -1 -1 -2 -2 -3 -3 -4 -5 -5 -6 -8 -11 -13 -15 -15 -15 -15 -16 -17 -18 -22 -28 -38 -52 -68 -84 -103 -121 -140 -160 -180 -202 DEP D ' LEG BUILD TURN ft °/100 °/100 °/100 0 0.0 0.0 0.0 -0 0.2 0.2 99.0 -1 0.4 0.2 78.9 -1 0.1 -0.0 -5.9 -1 0.1 0 . 0 -8 . 4 -2 0.1 0.0 13.1 -2 0.1 0.1 3.3 -3 0.2 -0.2 8.5 -3 0.1 0.1 13 . 3 -4 0.5 0.4 -23.0 -5 0.2 -0.2 -1.5 -6 0.3 0.0 24.1 -7 1.1 1.0 -18.5 -9 0.2 0.2 2.5 -12 0.1 0 . 1 -2 . 4 -14 0.4 -0.0 -12.7 -14 2 . ?' -0 . 1 -95.9 -10 3.0 2.6 -32.2 0 2.5 2.5 1.5 14 2.0 1.9 5.0 31 1.8 1.7 -3.0 50 1.3 1.3 2.1 71 0.4 0.3 1.3 93 1.7 1.2 5.7 117 3.0 2.4 7.5 144 2.9 2.6 4.8 174 2.6 2.5 2.0 208 2.5 2.5 -0.5 246 2.5 2.5 -0.4 287 2.0 2.0 -0.6 .332 2.4 z.3 -1.8 380 2.4 2.4 -0.5 432 2.2 2.2 -0.3 486 1.9 1.8 0.7 541 0.2 0.0 0.3 -225 596 0.9 0.0 1.5 -249 651 1.0 0.8 1.1 -274 706 0.9 0.9 0.1 -300 763 0.9 0.9 0.4 -327 820 1.0 0.8 0.8 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope Page 2 of 3 Date Jan 23-Feb Fiiename : 1175 Interpolated 100 6, '93 ft of MD MD ft 4000 4100 4200 4300 4400 4500 4600 4700 4800 4900 5OOO 5100 5200 5300 5400 55OO 560O 5700 5800 5900 6000 6100 6200 6300 6400 650,0 6600 6700 6800 6900 7000 7100 7200 7300 7400 7500 7600 7700 7800 7900 CkL INC DIR TVD VS ft deg deg ft ft 100 39.8 115.7 3740 947 100 39.2 115.0 3818 1010 100 38.5 115.0 3895 1073 100 38.8 114.1 3974 1135 100 41.0 112.3 4050 1199 100 42.5 111.8 4125 1266 100 42.6 111.2 4199 1334 100 41.8 112.4 4273 1401 100 40.9 113.9 4348 1467 100 40.1 113.5 4424 1532 100 42.2 112.4 4499 1598 100 42.6 111.7 4573 1665 100 42.9 111.0 4646 1733 100 42.8 110.8 4720 1801 100 42.4 111.1 4793 1869 100 42.1 ii1.1 4867 1936 100 42.0 111.3 4941 2003 100 42.8 111.0 5015 2070 100 42.9 110.7 5089 2138 100 43.0 111.3 5162 2206 100 42.8 110.8 5235 2274 100 42.8 110.4 5308 2342 100 42.5 110.0 5382 2410 100 41.9 111.1 5456 2477 100 41.5 110.1 5531 2544 100 41.6 ti1.0 5606 2610 100 ~41.3 110.5 5680 2676 100 41.0 110.7 5756 2742 I00 42.3 110.7 5831 2805 100 44.i ill.0 5903 2877 100 44.6 111.5 5975 2947 100 44.2 110.9 6046 3017 100 44.0 110.4 6118 3087 100 43.8 110.1 6190 3156 100 43.3 109.0 6263 3225 100 43.2 109.7 6335 3293 10O 43.1 109.8 6408 3362 100 42.9 110.0 6481 3430 100 42.9 110.7 6555 3498 100 42.0 110.0 6628 3565 LAT ft -355 -382 -409 -435 -460 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 878 0.1 0.0 0.2 935 0.7 -0.6 -0.7 992 0.7 -0.7 0.0 1049 0.7 0.3 -0.9 1108 2.5 2.3 -1.8 -612 1476 2.2 2.1 -1.1 -637 1538 0.6 0.3 -0.7 -662 1602 0.6 0.3 -0.7 -686 1665 0.2 -0.1 -0.1 -711 1728 0.4 -0.3 0.3 -735 1791 0.3 -0.3 0.0 -759 1854 0.2 -0.1 0.2 -783 1916 0.$ 0.8 -0.3 -808 1980 0.3 0.1 -0.3 -832 2044 0.4 0.1 0.6 -856 2107 0.4 -0.3 -0.5 -880 2171 0.3 0.0 -0.4 -904 2234 0.4 -0.3 -0.4 -927 2297 0.9 -0.6 1.1 -951 2359 0.8 -0.4 -1.0 -974 2422 0.6 0.1 0.9 -998 2483 0.4 -0.2 -0.5 -1021 2545 0.4 -0.3 0.2 · -1044 2607 1.2 1.2 0.0 -1069 2671 1.9 1.9 0.3 -1094 2736 0.6 0.5 0.5 -1119 2802 0.6 -0.4 -0.6 -1144 2867 0.4 -0.2 -0.5 -1168 2932 0.3 -0.3 -0.3 -1191 2997 0.9 -0.4 -1.1 -1214 3061 0.5 -0. 1 0.7 -i237 3126 0. 1 -0.1 0.1 -1260 3190 0.2 -0.2 0.2 -1283 3254 0.5 -0.0 0.7 -1307 3317 1. 0 -0.9 -0.7 -485 1170 1.5 1.5 -0.5 -509 1232 0.4 0.1 -0.6 -534 1295 1.1 '-0.8 1.2 -560 1356 1.4 -0.9 1.5 -5.86 1415 0.8 -0.8 -0.4 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-50 : Drill Site 9 : Prudhoe Bay ' North Slope Page 3 of 3 Date Jan 23-Feb Filename : 1175 Interpolated 100 6, '93 ft of MD MD CkL INC DIR TVD ft ft deg deg ft 8000 100 42.6 109.4 6702 8100 100 41.8 110.6 6776 8200 100 41.1 111.9 6851 8300 100 41.2 112.5 6927 8400 100 41.1 113 . 0 7002 VS ft 3633 3700 3766 3832 3898 8500 100 40.4 113.1 7078 8600 100 39.8 113.1 7154 8700 100 39.0 112.4 7231 8800 100 38.2 112.9 7310 8900 100 37.5 112.3 7389 3963 4027 4091 4153 4214 9000 100 37.1 111.8 7468 9100 100 39.3 111.6 7547 9200 100 42.5 111.2 7622 9300 100 45.5 111.4 7694 9400 100 45.5 111.5 7764 4275 4'337 4402 4471 4543 9500 100 44.1 110.7 7835 9600 100 42.6 111.1 7908 9700 100 40.8 111.5 7983 9800 100 39.0 111.1 8060 9900 100 37.2 11!.0 8138 4613 4682 4748 4812 4874 10000 100 36.1 110.6 8218 10100 100 35.7 110.8 8300 10200 100 35.7 112.5 8381 10300 100 36.3 114.0 8462 10400 100 36.4 115.2 8542 4934 4992 5051 5109 5169 ]0500 !00 35.4 116.3 8623 10600 100 33.8 117.6 8706 10693 '93 32.4 117.8 8783 ~r±g±n Bottom Hole Closure SLOT 3ottom Hole Closure 523? 5284 5334 5334 ft 111.7° LAT ft -1330 -1353 -13.77 -1401 -1427 DEP D'LEG BUILD ft °/100 °/100 3381 0.7 0.6 3444 1.2 -0.8 3505 1.1 -0.7 3566 0.4 0.1 3627 0.4 -0.2 TURN */100 -0.6 1.2 1.3 0.6 0.5 -1452 3687 0.6 -0.6 0.1 -1478 3746 0.6 -0.6 0.0 -1502 3805 0.9 -0.8 -0.7 -1526 3862 0.9 -0.8 0.6 -1550 3919 0.9 -0.8 -0.6 -1573 3975 0.5 -0.4 -0.5 -1595 4033 2.2 2.2 -0.2 -1619 4093 3.2 3.2 -0.4 -1644 4158 3.1 3.1 0.3 -1671 4224 0.0 -0.0 0.1 -1696 4290 1.5 -1.4 -1720 4354 1.6 -1.6 -1745 4416 1.8 -1.8 -1768 4476 1.7 -1.7 -1790 4534 1.8 -1.8 -0.8 0.4 0.4 -0.4 -0.! -18!1 4589 1.2 -1.2 -0.4 -1832 4644 0.4 -0.4 0.2 -1853 4698 1.0 0.0 1.6 -1877 4752 1.1 0.5 1.6 -1901 4806 0.7 0.1 1.1 4859 4910 4955 1.2 -1.0 1.7 -1.6 3.1 -3.0 -1927 -1952 -1976 1.1 1.3 1~5 TRUE VERTICAL DEPTH 100' INTERPOLATED Eastman Teleco Anchorage, Alaska Prudhoe Bay Drilling Well Name Location Date Surveyed Survey Performed By : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope : Jan 23-Feb 6, '93 : : Craig E. Tomayer ?his survey is correct to the best of my knowledge and is supported by actual field data. : ....... COMPA~.q'Y REPRESENTATIVE Eastman Teleco Slient : Prudhoe Bay Drilling Nell Name : DS 9-50 Location : Drill Site 9 : Prudhoe Bay : North Slope Date Jan 23-Feb 6, '93 Filename : 1175 Interpolated 100 ft of TVD Plane of Vertical Section : 111.7° Latitude & Departure relate to : SLOT CENTER Vertical Section Originates at : SLOT CENTER Slot Coordinates : Lat 0.000ft : Dep 0.000ft Directions Referenced To : TRUE NORTH Depth at Drill Floor : 0.00 ft Calculation Method : MINIMUM CURVATURE Magnetic Declination :+30.24°WELLSITE North Grid convergence : +0.0000° +0° 0' 0'' (T) Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-50 : Drill Site 9 : Prudhoe Bay ' North Slope Page 1 of 3 Date Jan 23-Feb 6, '93 Filename : 1175 Interpolated 100 ft of TVD MD ft 0 100 200 3OO 4OO 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1801 1902 2003 2105 2208 2310 2414 2518 2625 2733 2744 2957 3073 3192 3315 3439 3564 3690 3818 3947 ~4077 4206 CkL INC DIR ft deg deg 0 0,0 0.0 100 0.2 144.7 100 0.4 223.6 100 0.4 217.6 100 0.4 209.2 100 0.4 222.4 100 0.5 225.7 100 0.3 234,2 100 0.4 247.5 100 0.8 224.5 100 0.6 223.0 100 0.6 247.1 100 1.6 228.6 100 1.8 231.1 100 1.9 228.7 100 1.9 216.0 100 1.8 119.9 100 4.4 88.0 101 6.9 89.5 101 8.9 94.5 101 10.6 91.6 102 11.8 93.6 102 12.2 95.2 103 13.5 101.4 103 16.0 108.9 105 18.7 113.4 106 21.3 1!5.1 108 24.1 i13.8 111 26~ 114.2 11~ 28,~ 112.4 116 31.8 1t1.1 119 34.4 110.8 123 36.5 111.5 124 36.4 112.3 125 36.9 114,0 126 38.0 114.3 128 39.1 114.8 130 40.1 116.3 130 39 . 3 115,0 128 38.4 115.0 TVD ft 0 100 200 3OO 400 5OO 6OO 700 80O 9OO 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 2000 2100 2200 2300 2400 2500 2600 2700 2800 290{J 3000 3100 3200 3300 3400 3500 3600 3700 3800 3900 VS ft 0 -0 -0 -1 -1 -1 -1 -1 -2 -2 -3 -3 -4 -6 -7 -8 -8 -3 6 19 35 54 74 96 122 154 190 232 279 332 391 456 527 601 675 751 831 913 996 1077 LAT ft 0 '--0 -0 -1 -1 -2 -2 -3 -3 -4 -5 -5 -6 -8 -11 -13 -15 -15 -15 -15 -16 -17 -19 -22 -29 -41 -56 -73 ' -92 -113 -135 -158 -184 -211 -240 DEP D'LEG BUILD TURN ft °/100 /100 /100 0 0.0 0.0 0.0 -0 0.2 0.2 99.0 -1 0.4 0.2 78.9 -1 0.1 -0.0 -5.9 -1 0.1 0.0 -8.4 -2 0.1 0.0 13.1 -2 0.1 0.1 3.3 -3 0.2 -0.2 8.5 -3 0.1 0.1 13.3 -4 0.5 0.4 -23.0 -5 0.2 -0.2 -1.5 -6 0.3 0.0 24.1 -7 1.1 1.0 -18.4 -9 0,2 0 2 2.5 -12 0.1 0.1 -2.4 -14 0 . 4 -0.0 -12 . 7 -14 2.7 -0.1 -96.1 -10 3.0 2.6 -31.9 0 2.5 2.5 1,5 14 2.0 1.9 5.0 31 1.8 1.7 -2.9 51 1.3 1.2 2.0 72 0.5 0.4 1.6 95 1.9 1.3 6.0 120 3.0 2.4 7.3 149 2.9 2,6 4.4 182 2.5 2.4 1.6 220 2.6 2.6 -1.2 264 2.4 2.4 0.4 312 2 . 0 1 . 9 -1.6 367 2.5 2.5 -1.2 428 2.2 2.2 -0.3 494 ~ .7 1.7 0.6 562 C. 4 -0.1 0.7 631 0.9 0.4 1.3 -272 700 0.9 0.8 0.3 -305 773 0.9 0.9 0.4 -340 848 1.1 0.8 1.2 -376 922 0.9 -0.6 -1.0 -410 995 0.7 -0.7 0.0 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope Page 2 of 3 Date Jan 23-Feb 6, Filename : 1175 '93 Interpolated 100 ft of TVD MD ft 4334 4466 4602 4736 4869 5001 5137 5273 5409 5544 5679 5816 5952 6089 6224 6359 6493 6626 6759 6895 7035 7175 7314 7452 7589 7725 7862 7997' 8265 8397 8529 8660 8788 8914 9040 9170 9308 9450 9589 CkL INC DIR TVD ft deg deg ft 128 39.2 113.5 4000 132 42.2 111.8 4100 136 42.6 111.2 4200 135 41.5 113.0 4300 132 40.2 113.7 4400 133 42.2 112.4 4500 136 42.7 111.4 4600 136 42.9 110.7 4700 136 42.4 111.1 4800 135 41.8 111.1 4900 135 42.6 111.2 5000 136 42.9 110.7 5100 137 43.0 111.3 5200 136 42.8 110.5 5300 136 42.4 110.2 5400 135 41.6 110.4 5500 134 41.6 111.0 5600 133 41.1 110.6 5700 133 41.4 110.7 5800 137 44.1 111.0 5900 140 44.4 111.5 6000 140 44.1 110.4 6100 139 43.7 110.1 6200 138 43.2 109.0 6300 137 43.1 109.8 6400 137 42.9 110.1 6500 136 42.3 110.3 6600 135 42.6 109.4 6700 1~5~' 41. 5 111. 1 6800 133 41.2 112.2 6900 133 41.1 113 · 0 7000 132 40.3 113.5 7100 130 39.3 112.2 7200 128 38.3 112.8 7300 127 37 · 3 112 · 1 7400 126 37.4 111.8 7500 130 41.5 111.3 7600 138 45.8 111.5 7700 142 44.9 111.1 7800 139 42.7 111.1 7900 VS ft 1156 1243 1335 1425 1511 1599 1690 1783 1875 1965 2056 2149 2242 2335 2427 2516 2605 2693 2781 2874 2972 3069 3165 3260 3354 3447 3539 3630 3721 3808 3896 3982 4065 4146 4223 4299 4382 4477 4578 4674 LAT ft -443 -476 -510 -544 -578 -613 -647 -680 -713 -745 -778 -811 -845 -8,78 -910 -941 -972 -1004 -1034 -1067 -1103 -1138 -1171 -1203 -1234 -1266 -1298 -1329 -1360 -1393 -1426 -14.60 -1493 -1523 -1553 -1582 -1612 -1646 -1683 -1718 DEP D'LEG BUILD TURN ft °/100 °/100 °/100 1068 o.9 o.6 -1.1 1148 2.4 2.2 -1.3 1234 0.5 0.3 -0.5 1317 1.2 -0.8 1.3 1397 1.0 -1.0 0.5 1477 1.6 1.5 -1.0 1562 0.6 0.4 -0.7 1648 0.3 0.1 -0.5 1734 0.4 -0.3 0.3 1819 0.4 -0.4 0.0 1903 0.5 0.5 0.1 1990 0.3 0.2 -0.4 2077 0.3 0.1 0.4 2163 0.4 -0.1 -0.6 2250 0.3 -0.3 -0.2 2334 0.6 -0.5 0.! 2417 0.3 -0.0 0.5 2499 0.4 -0.3 -0.~ 2581 0.2 0.2 0.i 2668 1.9 1.9 0.2 2759 0.3 0.2 0.4 2850 0.6 -r~.2 -0.2~ 2941 0.3 -0.3 -0.2 3030 0.7 -0.4 -0.8 3118 0.4 -0.1 0.6 3206 0.2 -0.2 0.2 3293 0.4 -0.4 0.1 3379 0.5 0,2 -0.7 3463 2..2 -0.8 1.3 3545 0.6 -0.2 0.8 3625 0.4 -0.1 0.6 3704 0.6 -0.6 0.4 3781 1.0 -0.8 -1.0 3856 0.8 -0.8 0.5 3927 0.9 -0.8 -0.6 3998 0.2 0.0 -0.3 4075 3.2 3.2 -0.4 4163 3.1 3.1 0.1 4258 0.7 -0.6 -0.2 4347 1.5 -1.5 -0.1 Client Well Name Location Eastman Teleco : Prudhoe Bay Drilling : DS 9-50 : Drill Site 9 : Prudhoe Bay : North Slope Page 3 Date Jan Filename Interpolated of 3 23-Feb 6, : 1175 '93 100 ft of TVD MD CkL INC DIR TVD ft ft deg deg ft 9723 134 40.4 111.4 8000 9852 129 38.1 111.1 8100 9977 126 36.2 110.7 8200 10101 123 35.7 110.9 8300 1022'4 123 35.8 112.9 8400 10348 124 36.7 114.6 8500 10471 124 35.8 116.0 8600 10593 122 33.9 117.5 8700 10693 100 32.4 117.8 8783 VS LAT DEP D'LEG BUILD TURN ft ft ft °/100 °/100 °/100 4763 -1750 4430 1.8 -1.8 0.2 4844 -1779 4506 1.8 -1.8 -0.2 4920 -1807 4577 1.5 -1.5 -0.3 4993 -1832 4644 0.4 -0.4 0.1 5065 -1859 4711 1.0 0.1 1.7 5138 5211 5280 5334 -1888 4778 1.0 0.7 1.3 -1919 4844 1.0 -0.7 1.1 -1951 4906 1.7 -1.5 1.2 -1976 4955 2.9 -2.8 1.5 Origin of Bottom Hole Closure SLOT Bottom Hole Closure 5334 ft 111.7° ARCO Alaska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-22-93 REFERENCE: ARCO CASED HO~- FINALS 2-7-93 Dual Burst TlYrP Run 1, 226-93 Dual Burst TDTP O~orax) l~_m 1, if' 2,23-93 CNL l~_m 1, 2-8-93 Dual Burst TDTP 2-16-93 Perf Record 1~_~ 1, 28-93 Production Log Run 1, 1-31-93 CNL 2,1-93 CNL Run 2, 2-22-93 Tub~g Punch/~ Setth~ ~un 2-14-93 CNL Run 2, 2-21-93 Peff/GR/CCL/Jewelry Run 1, 2-17-93 CBT Color Run 2, 2-1793 USIT{Cement 2-6-93 PFC/GR/CCL (Correlation) Run 1, 2-6-93 Vertllog Run 1, Pleue sign and return.the attached copy a? receipt of data. Have A Nice Day! _~___~ Sonya Wallace APPROVED ....... ATO- 1529 Trans# 93038 Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Atlas # CENTRAL FILES # CHEVRON D&M # LUCILLE JOHNSTON # EXXON MARATHON # MOBIL # PIHLLIPS PB WELL FILES R&D # BPX # STATE OF AIASKA TEXACO The correct APl# for 2-12 is 50.029-20277-00. The correct APl# for 6-14A is 50-029-20458-01. P.O.Box 100360 ' Anchorage, Alaska 99510 DATE: 3-17-93 REFERENCE: ARCO MAGNETIC TAPE(S) WITH LISTINGS 3- 5A 2-27-e3 LL/MU./AC/GI ........ _9-4A 2-25-93 BCS/DLL/CNTH/GR c)~.L/._<~g9-50 2-9-93 DLL/SDN/CNTH/GR ~_~.~--/~J~.16-4A 2-19-93 MLL/DLL/AC/GR ~] L~.,..17.20 11.14-92 DPR/Den Poro/GR Please sign and return the~ attached copy a~ receipt of data. l~__m I Job~5903 Run1 Job~930/~ Run I Job~93057 Run I Job#5898 Run6 Job#1149 Have A Nice Day! Sonya Wallace ATO-1529 APPROVED__~ Trans# 9303.~~- .... Atlas 8ch Sch Atlas Teleco CENTRAL FILES (CH) CHEVRON D&M # BOB OCANAS (OH/GCT) # EXXON MARATHON MOBIL # PHILLIPS PB WELL FILES R&D # BPX # STATE OF A/2~KA TEXACO R'ECEIVED Alad(a 0ii & Ihs Cons. Commission Anchorage ARCO .~l~ska, Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: 3-2-93 REFERENCE: ARCO OPEN HOLE FINALS .-- 9- 2-25-93 ~~ 2-25-93 2-25-93 .... 2-9-93 ~~=~~ = 2-9-93 ~'~'-] 2-9-93 9-- ~- 1-18-93 ~.~-,[ ~ ~._.~J~ 1-18-93 1-18-93 ¢~- 2-19-93 2-19-93 ' ~ 1126-2112193 ~.._ ~ ~~ -~.l.~c~k6~ 1/26-2/12/93 1/26-2/12/93 DLL. (Simultaneous) BHC~t..- CNL DLL/MSFL/GR LD/GR/CNL (Raw) LD/GR/CNL (Poro) DLL/MSFL/GR LD/Neutron (Raw) LD/Neutron (Poro) DLL/MLL/GR BHCAIGR DGR/EWR/FXE DGR/CNP/DSFD/CAL DGR/Near-Far Ave 4~' Color Color Color Color Color Color Run 1, 2"&$" Run 1, 2"&$" Run 1, 2"&5" Run 1, 2"&$" Run 1, 2"&$" Run 1, 2"&$" Run 1, Run 1, 2n&5" Run 1, 2"&$ Run 1, Run 1, 2"&5" Runs 4-16, 2"&$"MD Runs 4-16, 2"&$"MD Runs 4-16, 2"&$"MD ,,......8.2~'' 18,2: 1/26-2/12/93 DGR/EWR/FXE Runs 4-16, 2'&$"TVD ~ 1/26-2/12/93 DGR/CNP/DSFD/CAL Runs 4-16, 2"&$'TVD ~g ~ 1/26-2/12/93 DGR/Near-Far Ave.~ Runs 4-16, 2"&S'TVD Please s~ ~d ret~~t~~ copy. receip~of ~. RECEIVED ~~~ ~A rove ANice ~ ~ / ' --- J ~D&M ~'~ R&D ~ C~T C~~ ~. ~ BPX ~ ~ON ~ ~ STA~ OF ~~ ~~ON ~ TEMCO ~ ~ MOB~ Sch Sch Sch Sch Sch Sch Sch Sch Sch Atlas Atlas Sperry Sperry Sperry Sperry Sperry Sperry WALTER J. HICKEL, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 TELECOPY: (907) 276-7542 Janua~ 12,1993 Mike Zanghi, Area Drlg Engr ARCO Alaska Inc P O Box 196612 Anchorage, AK 99519-6612 Re: Well # Company Permit # Surf Loc Btmhole Loc Prudhoe Bay Unit DS 9-50 ARCO Alaska Inc 92-149 1727'FSL, 6°FEL, Sec 2, T10N, R15E, UM 4913'FSL, 38'FEL, Sec 12, T10N, R15E, UM. Dear Mr Zanghi: Enclosed is the approved appliCation for permit to drill the above referenced well. The permit to drill does not exemPt you from obtaining additional permits required by law frOm other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be lested in accordance with 20 AAC 25.035. Sufficient nolice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of Ihe Commission may witness the test. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Yours truly, Russell A Douglass Commissioner BY ORDER OF THE COMMISSION jo/encl c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKa, JIL AND GAS CONSERVATION C~,.,,MISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrilll-Illb. Type of well. Exploratoryl-] Strut/graphic Test [] Development Oil E] Re-Entry [] DeepenI-11 Service [] Development Gas [] Single Zone [] Multiple Zone[] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO...A/a.ska, /,nc. KBE = 55feet Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612. Anchorage. Alaska 99519-~612 ADL 28327 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 ^^c 25.025) 1727' FSL, 6'FEL, Section 2, TION, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well number Number 5030' FSL, 330' FEL, Section 12, TION, R15E, UM DS 9-50 U-630610 At total depth 9. Approximate spud date Amount 4913'FSL, 38'FEL, Section 12, TION, R15E, UM January20, 1993 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth(UDandmVD) property line 6 feet DS 9-24@ 675'MD = 14 feet 2560 11212'MD/9198' TVD'eet 1"6." To be completed for deviated wells 17. Anticipated pressure (see 2o ,,,Ac 25.035 (e)(2)) Kickoff depth ~6oofeet Maximum hole angle ,~o.9 o Maximum surface 2800pslg At total depth (TVD) 8800'/3610Pslg 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement ' Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include Stage data) 30" 20" 91.5 H-40 Weld 80' 32' 32' 110' 110' 11 yds AS 16" 13-3/8" 68# L-80 BTC 3976' 31' 31' 4007' 3750' 2~ cu~cs///. 46ocu~c/~.~24ocu~cs// [. 12-1/4" 9-5/8" 47# L-80 NSCC 10702' 30' 30' 10732' 8835' 1462 cu ft Cl 'G' 8-1/2" 7" 26# 13cr-8o NSCC 630' 10582' 8722' 11212' 9198' 207cu ft Cl 'G' 19. To be completed for Redrill, Re-entry, and Deepen operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor RECEIVED Intermediate Production Liner DEC ~ 2 lJ99~ Perforation depth: measured Alaska 0il & Gas Cons. commisSiO~ true vertical ~_nnhnr~na . 20. Attachments Filin~ fee [] Property plat [] BOP Sketch [] Diverter Sketch []'-I~ilii-n.~ program [] Drilling fluid program [] Time vs depth pict [] Refraction analysis[] Seabed reportl-i 20 AAC 25.050 requirementsl'-I 21. I hereby certify~ that th~ foregoing is true and correct to tl)e_i;)est of my knowledge Signed~1~ -'~ Title'~r4~r'Dr#/ing Engineer Supervisor Date /-~''- ~.~x'.... ~ Commission Use Only Permit Numl~er JAPI number IApproval date JSee cover letter ?2. -/',~' ? 15 0, ~ ~_ ? - ~ ~ ~' ..7_._5' I /~/,~, _.~ ~ Ifor other requirements Conditions of approval Samples required [] Yes .JE~'No Mud Icg requireo Yes ]~]'No Hydrogen sulfide measures !-i Yes ~ No Directional survey requ~rea '~ Yes [] No Required working pressure for BOPE []2M; 1-13M; /J~5M; l'-110M; 1'315M; Other: ORIGINAL SIGNED ElY by order of Approved by RUSSELL A. DOUG~ Commissioner Eno commission Date/./.,~ .~/2. Form 10-401 Rev. 12-1-85 Submit in triplicate WELL PLAN WELL: 9-50 Producer LOCATION: Surface: Target: T.D.: 1727 FSL, 6' FEL, Sec. 02, T10N, R15E 5030' FSL, 330' FEL, Sec. 12, T10N, R15E 4913' FSL, 38' FEL, Sec. 12, T10N, R15E ESTIMATED START: Jan 20, 1993 OPR. DAYS TO COMPLETE: 23 (19 days drilling, 4 days completion) ~R/~TOR: Nabors 18E MAX ANGLE/SECT COURSE/KOP/BUILD/MAX DEP: 40.9 deg/S68.3E/1600'/2.0/5651' Estimated Ground level elevation is 25.5' AMSL. KB to ground level elevation is 29.5'. Item TVD(BKB) MD(BKB) Mud Wt. 20" CONDUCTOR 8 0 8 0 8.5 13-3/8" SHOE 3750 4007 9.0-9.5 TOP UGNU SANDS 5 992 6972 9.0- 9.5 K12 7020 8331 9.5-10.0 K10 7554 9038 9.5-10.0 K5 8135 9807 9.5-10.0 9-5/8" SHOE 8835 10732 9.5-10.0 SAG/PUT/SHUB Absent TOP SADLEROCHIT 8835 10732 9.2- 9.5 TARGET 8835 10732 9.2-9.5 TOTAL DEPTH 91 98 11 21 2 9.2-9.5 CASING PROGRAM: Hole Csq. Wt Grade Conn Lenoth Too 30" 20" 91.5# H-40 WELD 80 32 16" 13-3/8" 68# L-80 BTC 3976 31 12-1/4" 9-5/8" 47# L-80 NSCC 10702 30 8- 1/2" 7" 2 6# 13Cr NSCC 630 10582 Btm 110 4007 10732 11212 COMPLETION: Tubing: GLMs: Packer: LOGGING PROGRAM: ...Open Hole- Cased Hole 7x5-1/2 26#/1 7# 13Cr Fox 3300/7402 29 10732 10-5-1/2" x 1-1/2" with 8 dummies and 1 RP shear(2800 psi) in top station and 1 equalizing dummy rn deepest station. 9-5/8" x 5-1/2" perm latched set at +/- 50' above TOL with 4-1/2" tail pipe. RECE]VED 12-1/4" Hole: None 8-1/2" Hole: DLL/CNL/LDT/GR +/- MSFL No gyro or Cement Bond logs are planned. DEC Alaska Oil & ~as Cons. Anchorage DS 9-50 Conventional 15:01 December 18, 1992 Page 5 PROPOSED DRILLING AND COMPLETION PROGRAM DS 9-50 Procedure 1. MIRU drilling rig. N/U diverter and function test same. . Drill 16" hole to surface casing point. Run and cement surface casing. Nipple up BOPE and function test same to 5000 psi. , PU 12-1/4" BHA and RIH. Test casing to 3500 psi for 30 minutes. Drill 10' of new hole and perform leak off test. 4. Drill intermediate hole to intermediate casing point. . MU and run 9-5/8 casing string and cement as per well plan. Bump cementing plug with mud. 6. RIH and drill 8-1/2" hole through reservoir to TD. 7. RU and run e-line logs. MU 7" liner on 5" DP. RIH to TD. Cement same. Set liner hanger and packer. Circulate excess cement from wellbore. POOH. 9. MU casing scraper & clean out 7" liner. 10. Run 7" x 5-1/2", 13Cr tubing and packer assembly with SSSV. Freeze protect with diesel. Test tubing and casing to 3500 psi. 1 1. NU tree and test to 5000 psi. Release drilling rig. ° Anticipated BHP: ° Maximum Anticipated Surface Pressure: o Planned Completion Fluid: 3610 psi @ 8800' TVD SS 2800 psi 8.6 ppg filtered sea water Notes: a. The drilling fluid program and surface system will conform to the regulations set forth in 20AAC25.003. b. Maximum surface pressure is based on BHP and a full column of gas to TD (0.10 psi/ft). c. Based on previous logs on DS 9, no potential productive zones are anticipated above the Sadlerochit target d. No potential hazardous levels of H2S are anticipated in this well. RECEIVED DEC 2 2 !992 Alaska ,0il & was Cons. o. missi0n ~ch0rage k[CEIVED 9-50 Conventional Drillin¢~ Problems & Concerns: -- Producer ~laska bl~ & uas Cons. Co. mm~|ssio~' Anchorage DS 9-50 is a slant conventional well ( 80 acre infill producer ) with a 13-3/8" x 9-7/8" x 7" casing program. A copy of the DS 9 data sheet has been delivered to 18E. The Ugnu/Cretaceous is likely overpressured by 125 to 150 psi. A mud weight of 9.0 ppg or greater should be used through this interval to prevent salt water incursions. The top of the Cretaceous/Ugnu is at 6972' md. No significant drilling problems are anticipated. No Kingak, Sag River, or Put River will be exposed. The 9-50 well target is prognosed for the top of Sadlerochit ( ZULU flowunit ). There is no expected gas cap in the well. Faulting in the near target area is not a concern and a 200' target radius will be used. The completion will include 7" x 5-1/2" 13Cr Fox tubing with 8 dummied GLMs, one equalizing dummy, and one RP shear valve WASTE FLUIDS The 9-42, 49, and 51 surface annulus is available for pumping at present. Fluids can also be transported to the central CC-2 injection facility. The AOGCC has informed PB Drilling that only associated fluids from drilling operations can be pumped down the surface x intermediate annulus-ie: completion fluids cannot be pumped. C. ,UTTINGS DISPOSAL Plan to wash and store surface gravel in bermed pit on pad. Grind and inject all non-gravel surface, intermediate, and production interval material using the Sun Unit. FREEZE PROTECT!~N,., The tubing along with the tubing x casing annulus can be freeze protected using dieselor gas. Check with Porduction Dept regarding availability of gas. The 13-3/8" x 9-5/8" annulus must be fully displaced with dry crude after the well is completed. Ensure that annulus valves are secured with plugs after pumping crude. CLOSE APPROACHS & SHUT-INS Note near well proximity (less than 100') of other DS-9 wells. Production has been requested to perform the following:. 9-09 (injector) 30' to 100' down to 2678' md. Close SSSV until drilling well surface casing is set. 9-24 (producer) 30' to 100' down to 1548' md. Close SSSV until drilling well surface casing is set. DS 9-50 Conventional 15:01 December 18, 1992 Page ~RrR.-~-' LAND DIRECTIONAL DRILLING, INC. CorDorate Office 1111 East 80th Avenue Anchorage, AK 99518 (90?) 349-4511 Fax 349-2487 Alaska 01~ & 6as Cons. G0mm|$sig.~ DIRECTIONAL WELL PLAN ~ON PRUDHO~ BAY DRILLING Anchorage Well ......... : D~ 9-50 (P1) Field ........ : PRUDHOE BAY DRILL SIT~ 9 Computation..~ ~INIMUM CURVATUR~ Prepared ..... : 12/01/92 Seotion at...: 111.74 KB elevation,: 55.00 LEGAL DESCRIPTION Surface ...... ~ 1727 FSL 6 FEL $02 T10N R15~ UM Target ....... ~ 5030 FSL 330 F~L S12 T10N RI~E UM ~HL .......... : 4913 ~$L 38 FEL ~12 TAON R15~ UM X ASP ZONE 4 718363.99 5943195.01 723376.31 5941364.19 723671.68 ~941256.41 PROPOSED WELL STATION IDENTIFICATION K~ K0P BUILD 2.00/100 MEAS INCLN DEPT~ ANGLE VERT-DEPTHS S~CT BKB SUB-S DIST 0 0.00 0 -55 0 1600 0.00 1600 1545 0 1700 2,00 1700 t645 2 1800 4.00 1800 1745 7 1900 6.00 1899 1844 16 DIR~CTION REL-COORDINATES DL/ A~IMUT~ ~ROM-WELLMEAD 100 0.00 0 N 0 E 0.0 111,74 0 N 0 E 0.0 111,74 t ~ 2 E 2,0 111.74 3 S 6 E 2.0 111.74 6 S 15 E 2.0 2000 S.00 1999 1944 28 2100 10.00 2097 2042 44 2200 12.00 2196 2141 63 2300 14.00 2293 2238 85 2400 16.O0 2390 2335 111 111.74 10 S 26 E 2.0 111.74 16 S 40 E 2.0 111.74 23 S 58 E 2.0 111,74 32 $ 79E 2,0 111.74 41 $ 103 E 2.0 2500 l~.O0 24~5 2430 140 2600 20.00 2580 2525 173 2700 22.00 2673 2618 209 2800 24.OO 276~ 2710 248 2900 26.00 2856 2801 290 111.74 52 S ~30 E 2.0 111.74 64 S 160 E 2.0 111,74 77 $ 194 E 2.0 11~.74 92 S 230 E 2.0 111,74 107 S 269 E 2.0 3000 28.00 2945 2890 335 3100 30.00 3032 2977 384 3200 32.00 311~ 3063 436 3300 34.00 3202 3147 490 3400 36.00 3284 3229 547 111.74 124 S 311 E 2.0 111.74 142 ~ 356 E 2.0 111.74 161 $ 404 E 2.0 111.74 181 S 455 E 2.0 111.74 203 $ 508 ~ 2,0 ~ND OF 2.00 ~UILD TARGET TOP $ADLEROCHIT 3500 38.00 3364 3309 607 3600 40.00 3441 3386 670 3643 40.87 347~4 3419 698 10732 40.87 8835 8780 5336 10732 40.87 8835 8780 ~336 111.74 225 S 564 E 2.0 111.74 248 S 623 E 2.0 111.74 259 S 649 E 2,0 111.74 1977 S 4957 E 0.0 111.74 1977 S 49~7 E 0,0 MOT BOTTOM SADLEROCHIT TD 10988 40.87 9029 8974 5504 11062 40.87 9085 9030 5553 11212 40_R7 glga 9143 111.74 2039 $ 5113 E 0.0 111.74 2057 S 5158 E 0.0 ~11,74 2094 S 5249 E 0.0 (GLDD (c)92 D$950P 81.36 2:19 I~1 1) PRUDHOE BAY DRZLLIN6 A) KB O O 0 O, O0 ii] KOP 8ll~LO ~?.O0/:lOO :~600 1600 O 0.00 ~ C] END OF 2.00 BUILD 3643 347~1 698 40,87 D) TAROT 10732 8835 53~6 40.87 · · Lr. IV-~ E)TO ~_~2:t;~ g~glt565~ 40.87 Secf. JOfl at: :!;~:1.74~\ ~r TVD Scale.- 1 inch- 1200 feet Dap Scale' t inch - ~200 fel~d~O 2 2 1992 Drawn ' 12/0,I/9~ Alaska O, & uae Cons. Gore Sreat Land DYrectiona] OrYllj 0 600 ]~00 1800 tGLDD Ic)9~ 05950P 2:29 PN jl 2400 3000 3BO0 4200 4800 5400 §000 6600 7200 7000 Sect ion Departure Great k~nd OieectJona] £ri]]m9 I I lllll. I II I II I 111 JlJ J J II ! ~ II I II os 9-50 PLAN VIE~ I i iiii$i i i ! ]I i ii i i CLOSURE .....: 5651 ft at Azimuth 1ti.74 DECLINATION · 30.24 [ SCALE ' ! inch = BOO t~eet DRAWN. ' ~2/01/92 "P UDHOE BAY .. I II i illi I II II __II I __ Il Marker ldent i ~cat ion ND N/S E/I~ k) 1(8 0 0 N 0 E BJ KOP BUILD 2.0O/1Ol} l§OO 0 N 0 E C) Eh1] OF 2.00 BUILD 36~3 259 S 649 E D) l'ARGET 10,732 1977 S 4957 E E) TO 112t2 2094 S 5249 E · ~ rm [jRILLIN ' - i lm , , iii ii ii I I llm II 400 0 400 ~0 120~ mt 800 2000 24D0 2800 3DO0 3600 4000 4400 4801) 5200 <-- h'ESI ' EAST --> ((;LOD (cj92 [f~95OP [ll.m'~i~! PH-ll ............ 5600 6000 6400 6890 Great Land Directional Drilling, collision Avoidance Analymim Client.: Field..: Pad .... : Well...: PRUDHOE BAY DRILLING NSLOPE Drill Site 9 D$0950P Method..: Date .... : WellHd X: WellHd Y: Normal Plane 11/2S/92 718363.99 5943195.01 Comment: DS 9-50 1600 KOP Wells with minimum separation greater than 200 ft not reported. ~All depths are relative to the planned well. ~xisting Well DS0908G 86 1700 1700 DS0909G 29 1909 1910 DSO910G 138 2300 2307 DS0924G 14 675 675 DS0936G 149 1~75 1575 D$0944G 81 851 851 D$0945G 177 2476 2490 .... ~-= .... 100' .... -----25'~=~== Band Occurs at Warning-Band Serious-Band Closest D~pths Enter Leave Enter Leave Point BKD MD MD MD MD MD · i 2017 1 2417 0 1315 225 949 3 1118 RECEIVED DEC 2 2 1992 A~aska OJJ &[ias Co,'ls. Commission Anchorage TOTAL P. 01 MUD PROGRAM: Well 9-50 The mud program for this well shall follow the new Mud Policy. The following are the recommended mud parameters. MUD SPECIFICATIONS- SURFACE HOLE Surface: Casing point: Mud Weight: ppg 8.5 - 9.5 8.5 - 9.5 Funnel Viscosity sec/qt ~300 <100 YP Ibs/100ft2 40 - 60 20 - 40 10 sec Gel Ibs/100ft2 30 - 60 15 - 20 10 min Gel Ibs/100ft2 60 - 80 20 - 30 pH - 8.5- 10 8.5- 10 APl Fluid loss mi/30 min 1 5- 2 5 1 5- 2 5 Hardness mg/I < 200 <200 .MUD SPECIFICATIONS- INTERMEDIATE HOLE Surface casing shoe to Top 'K' shale (~6000 - 7000'): Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid Loss mi/30 min pH -- Hardness mg/I 9.5 - 10.0 10 - 15 5-10 10 - 20 <15 9.5 - 10.0 < 200 Top 'K' shale to Section TD. Mud Weight ppg 9.5 - 10.5 Yield Point Ibs/100ft2 10 - 20 10 sec Gel Ibs/100ft2 5 - 10 10 min Gel Ibs/100ft2 15 - 25 APl Fluid loss mi/30 min 6.0 - 8.0 pH -- 9.5 - 10.0 Hardness rog/liter <200 DEC 2_ 2 !99~ Alaska 0il & Gas Cons. bul~missior~ Anchorage DS 9-50 Conventional 15:01 December 18, 1992 Page 8 MUD SPECIFICATIONS-PRODUCTION INTERVAL; Swap out mud after drilling out intermediate cement. Follow recommended Baroid displacement procedure as attached. Baroid to mix 2-3% KCL blend (same as used for sidetracks)at plant and transport to rig. Return mud to Baroid upon completion of well for credit. Mud Weight ppg Yield Point lbs/1 00ft2 10 sec Gel lbs/1 00ft2 10 min Gel Ibs/100ft2 APl Fluid loss mi/30 min pH 9.0-9.5 10- 15 5-10 7- 15 6.0 - 8.0 (fluid loss lowered to below 6 cc prior to entering K-shales 8.0 - 9.0 RECEIVFD DEC 2 2 ~992 Alaska 0il & ~as Gons, uummjssion DS 9-50 Conventional 15:20 December 18, 1992 Page 9 13-3/8" SURFACE CASING CEMENT PROGRAM - BJ Services CASING SIZE: 13-3/8", 68# CIRC. TEMP 40°F LEAD CEMENT TYPE: Cold Set III ADDITIVES: retarder WEIGHT: 12.2 ppg YIELD:1.92 ft3/sx MIX WATER: 10.5 gps APPROX #SACKS: 1532 THICKENING TIME: 4:30 hrs TAIL CEMENT TYPE: Class G + 2% A-7, CaCl + I gphs FP-6L ADDITIVES: as required WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx MIX WATER: 4.95 gps. APPROX #SACKS: 400 THICKENING TIME: 3 hrs TOP JOB CEMENT TYPE: Cold Set II ADDITIVES: retarder WEIGHT: 14.9 ppg APPROX #SACKS: 250 YIELD:0.96 ft3/sx MIX WATER: 3.89 gps SPACER: 75 bbls fresh water ahead of lead slurry. CENTRALIZER PLACEMENT: 1. Run one(l) bow type centralizer per joint for the first 20 joints. 2. Place the centralizers in the middle of each joint with a stop collar. 3. Run two bow type centralizers spaced 10" and 20' above conductor shoe 4. Do not run cement baskets. CEMENT VOLUME: 1. Lead slurry to surface w/100% excess. 2. Tail slurry volume 400 sx 3. Top job volume 250 sx. DS 9-50 Conventional 15:01 December 18, 1992 Page 13 9-5/8" INTERMEDIATE CASING CEMENT PROGRAM- BJ Services CIRC. TEMP: 130° F SPACER: 50 bbls Arco Spacer, weighted 1 ppg above mud current mud weight. LEAD CEMENT TYPE: CLASS G ADDITIVES: 2.0% A-2 + 0.5% Gel + 0.7% R-18 + 1 GPHS FP-6L WEIGHT: 12.0 ppg YIELD: 2.40ft3/sx MIX WATER: 14.2 gps APPROX #SACKS: 400 THICKENING TIME: 5hrs TAIL CEMENT TYPE: CLASS G ADDITIVES: .3% FL-52 + 0.5% CD-32 + 0.1% A-2 + 1 GHS FP-6L for 3-4 hrs thickening time. WEIGHT: 15.8ppg YIELD: 1.14ft3/sx MIX WATER: 4.84 gps APPROX #SACKS: 440 THICKENING TIME: 4 hrs CENTRALIZER PLACEMENT: 1. 1 turbulator centralizer per joint on shoe joints (2 required) 2. 1 turbolator per joint on every third joint to 500' above shoe(4 required) 3. 1 straight blade rigid centralizer every third joint from 300' below to 300' above Ugnu/Cretaceous (6972' md to 8331'md + 600' = 16 required) 4.2 turbolators spaced out 100' and 200' above surface shoe (2 required) OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 10-12 bpm. CEMENT VOLUME: 1. Tail G slurry to 1000' md above casing point with 50% excess. 2. Lead slurry from 1000' above shoe to 300' md above Ugnu/Cretaceous (6972'md). 2. 80' md 9-5/8", 47# capacity for float joints, t~ Er E IV E D 9-50 Conventional 15:02 December 18, 1992 DEC 2 2 '~992 Alaska Oil & Gas Cons. 6ommission Anchorage Page 17 7" PRODUCTION LINER CEMENT PROGRAM - BJ Services CIRC. TEMP 1400 F PREFLUSH: 75 bbls Arco preflush + 1% S-400 . CEMENT TYPE: CLASS G ADDITIVES: 0.8% BA-10 + 0.6% FL-32 + 0.2% CD-30 + 0.3% A-2 + 0.35% R-1 + 0.35% R-1 + 1 ghs FP-6L WEIGHT: 15.7 ppg YIELD:1.18 ft3/sx MIX WATER: 5.03 gps APPROX #SACKS: 175 THICKENING TIME: 4:15 hrs total Note: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencys ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: Run 2 turbolators per joint in open hole, 1 per joint in lap, and none opposite intermediate casing shoe (31 needed). OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 40cc or less. Displace @ 8-10 bpm. LINER CEMENT VOLUME: , . 3. 4. 5. Open hole + 30% excess + excess for surface volume lost (adjust if a caliper log is run and it indicates severe washouts). 7", 26# casing capacity below landing collar. 150' liner lap 200' of cement on top of the liner in the 9-5/8" casing. Modify volume if caliper shows washout in 8-1/2" hole, RECEIVED DEC 2 2 1992 ~[aska Oil & Gas Cons. ¢(~mmissi0.a ~ch0.raga DS 9-50 Conventional 15:17 December 18, 1992 Page 22 DS 9-50 Casing Design SURFACE CASING 13-3/8" 68#/FT K-55 & L-80 BTC CASING BURST COLLAPSE K-55 3450 1950 L-80 5020 2260 PBYS (#) TJYS (#) 1069000 1300000 1556000 1585000 Burst Pressure Calculation Burst rating based on Shutting in the well on a gas kick equivalent to the LOT (14.0 ppg) at the surface casing shoe. Worst case will be in the K-55 casing, which has no back up gradient. LOT (ppg) TVD (FT) SIPRESSURE 14 3750 2730 Burst S.F. 1.26 Collapse Calculation Collapse rating based on losing returns until the fluid level is below the surface casing shoe Mud weight behind the surface casing is 9.5 ppg Mud Wt. (ppg) TVD (FT) Collapse press 9.5 3750 1853 Collapse S.F. 1.22 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 68 4007 PBYS Tension S.F. 4.59 Mud Wt. 9.5 ppg TJYS 5.58 String Wt. (#) 232912 RECEIVED Alaska Oil & Gas Coi'~s, burn,mission Anchorage DS 9-50 Casing Design Production Casing 9-5/8", 47#,L-80,NSCC Casing GRADE BURST L-80 6870 COLLAPSE PBYS (#) TJYS (#) 4750 1086000 1161000 Burst Pressure Calculation Burst rating based on have a tubing leak on top of full column of fluid Worst case will be at the surface, which has no back up gradient. SrTP 3420 Burst S.F. 2.01 Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Gas Grad. Mud Wt. (ppg) TVD (FT) (psi/ft) Collapse press 10.2 8835 0.1 3803 Collapse S.F. 1.25 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 47 10732 PBYS Tension S.F. 2.55 Mud Wt. 10.2 TJYS 2.73 String Wt. (#) 425767 RECEIVED DEC 2 2 1992 Alaska Oil & Gas Cons. Cor[~missior~ Anchorage DS 9-50 Casing Design PRODUCTION LINER 7", 26#, 13Cr, NSCC Casing GRADE BURST 13Cr 7240 COLLAPSE PBYS (#) TJYS (#) 5410 604000 667000 Burst Pressure Calculation Burst rating based on formation pressure on top of 9.7 ppg fluid Fluid wt (ppg) back up (ppg) Burst Pressure SITP 9.7 9.5 3512 3420 2.06 Burst S.F. Collapse Calculation Collapse rating based on annulus being evacuated due to gas lift Mud weight behind the casing is 10.2 ppg Mud Wt. (ppg) 10.2 Collapse S.F. Gas Grad. TVD (FT) (psi/ft) Collapse Press 9198 0.1 3959 1.37 Tension Calculation Based on full string weight in mud Casg Wt. (#/ft) MD (FT) 26 630 Mud Wt. String Wt. (#) 10.0 13826 Tension S.F. PBYS TJYS 43.68 48.24 RECEIVE : DEC 2 2 1~92 Alaska Oil & Gas Cons, Anchorage ~.ABORS 18 E 13 5/8" 5,000 psi Stack 1.50 4.75 4.73 ? 3.98 I 3.66 I 1.49 2.37 ,,~, 2.21 0.£5 , .,? GROUND LEVEL RKB 1 ,,! HYDRIL PIPE RAM BLIND RAM , KR TQ RF RIG FI ©©R 11.41 ,! 15.66 17.93 I f 22.96 MUD CROSS PIPE RAM .,J CROSS ] TBG ~ SPOOL I ~x~A: F: FLG/ 26.45 28.25 Anchorage 30.25 f SUF..,' CE 'LE DIVEFITEFi SYSTEM ...... Two lines venting go deg. apart in directions that ensure sale down wind venting, and ex- tending to a point at least 100' lrom any potential'"" source o! lgnilion. e ,. 10' Full Opening Valves 35' or as required Dresser Sleeve o .. · 10' Diverter Line 1. Ail pipe connections 150¢ ANSI Flanges or welded connections and secured lo prevent movemenL 2. Manual 10' full opening valves mechanically c~nnected to ensure that one valve is fail-sate open at all limes. 3. All lures ~re gO deg. and targeted. 1 O' Full opening ball valve w/Hydraulic Actuator Cellar RECEIVED DE0 2 2 7992 20' Diverter Spool w/lO'.Side Outlet Alaska Oil & Gas Cons. Commission Anchorage i MEM 1/'J~O MUD ~lt.L 7AMK, wATER TO pit ~.TRIP TANK 'rAN K I'IUD SYSr£H SURFACE F~ TOTAl. SURFAC,~ CAPACITy' V~2uu~ TYF~ ~ FER DISTRIE, OTION - Choke Manifold - Poor Boy Degasser . - Brandt VacuumvType Degasser - Brandt Dual Tandem Shale Shaker - Pioneer Mud Cleaners - Pioneer MKI Centrifuge 1 - Recording drilling fluid, pit 'level indicator with both visual and audio warning devices at driller's console ' 1 - Trip Tank (75 BBL.) 1 - Drilling fluid flow sensor with readout at driller's console 11 - 5 Hp Agitators 9-50CMT.XLS State: Well: Field: State Permit PRL IDHL?£ 14,9 Work S beet: Date: C~t Vo~x~e Calcula#ons 1/G/93 Casing T~e Casing Size Casing Length Hole Diameter Cement-Sacks Cement- Yield Cement-Cubic tt Cement- Cubic It Cement- Sacks Cement- Yield Cement- Cubic tt -Inches - Feet -Inch~ 111 111 111 111 112 112 112 Cement- Cubic tt 112 Cement- Sacks 113 Cement- Yield 113 Cement- Cubic It 113 Cement- Cubic tt Cement- Cubic tt /Vol Cement - Fill Factor Casing T~ Casing Size -Inches Ca~ing Depth - Feet Hole Diameter-Inches Cement- Sacks111 Cement- Yieldti1 Cement- Cubic It 111 Cement-Cubic It 111 Cement- Sacks~I2 Cement- Yield112 Cement- Cubic tt 112 Cement- Cubic it 112 Cement- Sacks113 Cement- Yield113 Cement- Cubic tt 113 Cement- Cubic tt 113 Cement- Cubic It / Vol Cement- inte~¥al fl Top of Cement- Feet Conductor 20.000 80.000 30.000 0.000 0.000 0.000 297.000 0.000 0.000 0.000 0.000 297.000 1.361 Intermediate 111 0.068 0.000 0.000 0.00 0.00 0.00 0.00 O00 0.68 0.00 0.00 0.00 0.00 0.00 0.00 0.00 IIDIV/O! I~DIV/O! 13.375 3,976.000 16.000 0.009 0.000 0.000 2,941.000 0.000 0.000 0.000 460.000 0.000 0.000 0.000 0.000 3,401.000 2.034 Inte~mediale 112 0.000 0.000 0.000 0.09 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 11DIV/O!. t~DIV/O! Printed 1/6/93 Liner 7.000 630.000 8.500 0.000 0.000 0.000 207.000 0.000 0.000 0.000 0.000 207.000 2.591 P~oduc6on 9.625 10,732.000 12. 250 0.00 0.00 0.00 1,462.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 1,462.00 4,668.22 6,063.8 ~,~r~ D~p~h State: Alaska Borough: Well: DS9-50 Field: Prudhoe 19ay St. Perm ~ 92-149 Date Engr: 9.5~SG.XLS 116/93 M. Minder Casing Interval Interval Size Bottom Descriptionescriptionescription Tension Top Length lA 13.375 151 31 120 2A 13.375 $750 120 3856 3A 9.625 8835 30 10702 4A 7 9198 8722 630 5A 0 0 0 0 6A 0 0 0 0 7A 0 0 0 0 8A 0 0 0 0 9A 0 0 0 0 10A 0 0 0 0 Lbs Grade Thread Lbs 68 K-55 BTC 0 68 L-80 BTC 0 47 L-80 NSCC 0 26 13CR80 NSCC 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 lB 2B 3B 4B 5B 6B 7B 8B 9B 1(319 Mud Hydraulic Collapse Wieght Gradient Gradient ppg psi/ft psi/ft 9.5 0.494 0.394 9.5 0.494 0.394 10.5 0.546 0.446 10.2 0.530 0.430 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 0.0 0.000 -0.100 Maximum Minimum Pressure Yield psi psi BDF 2800 3450 1.2 2800 5020 1.8 2800 6870 2.5 2800 7240 2.6 0 0 #DIV/OI. 0 0 #DIV/O! 0 0 #DIVIO! 0 0 #DIV/0! 0 0 #DIV/0! 0 0 #DIVIO! Tension Strength K/Lbs 1C 8.16 2C 262.208 3C 502.994 4C 16.38 5C 0 6C 0 7C 0 8C 0 9C 0 10C 0 K/Lbs TDF 1069 131.00 1556 5.93 1086 2.16 604 36.87 0 #DiV/O! 0 #DIV/01 0 #DIV/O! 0 #DIV/0! 0 #DIV/0! 0 #DIV/O! Collapse Collapse Pr-Bot-Psi Resist. CDF 59 1950 32.776 1478 2260 1.530 3940 4750 1 205 3959 5410 1.367 0 0 #DIV/O! 0 0 #DIV/0! 0 0 #DIVi0! 0 0 #DIV/O! .0 0 #DIVI0! 0 0 #DIV/O! Page 1 CHECK L I ST FOR NEW WELL PEPd4ITS .... ITEM APPROVE DATE Fee ~,~_ E2 thru 8] (3) Adrni n [.9 thru 13] [10 & 13] [14 thru 22] [23 thru 28] Company Lease & Well YES NO 1. Is permit fee attached ............................................... ~_ 2. Is well to be located in a defined pool .............................. /~ .... 3. Is well located proper distance from property line ................... ~ .. ~ 4. Is well located proper distance from other wells ..................... ~4~' . ..... 5. Is sufficient undedicated acreage available in this pool ............. L ... 6. Is well to be deviated & is wellbore plat included ................... ~__ ~ 7. Is operator the only affected party .................................. 8. Can permit be approved before 15-day wait ............................ ~ .. REMARKS e 10. 11. 12. 13. 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. 26. 27. 28. Does operator have a bond in force ................................... ./~ Is a conservation order needed ....................................... ,., I s admi n i st rat i ve approval needed .................................... Is lease nLrnber appropriate .......................................... ~ Does well have a unique name & ncrnber ................................ Is conductor string provided ......................................... ~ Will surface casing protect all zones reasonably expected to serve as an underground source of drinking water .................. ~ Is enough cement used to circulate on conductor & surface ............ /.4'.¢ Will cement tie in surface g intermediate or production strings ...... Wi 11 cement cover al 1 known product ire horizons ..................... ~ Will all casing give adequate safety in collapse, tension, and burst. .~. Is well to be kicked off from an existing wellbore ................... Is old wellbore abandonment procedure included on 10-403 ............. Is adequate wellbore separation proposed ............................. /~ Is a diverter System required ........................................ Is drilling fluid program schematic & list of equipment adequate ..... ~ Are necessary diagrams g descriptions of diverter & BOPE attached .... ~ Does BOPE have sufficient pressure rating -- test to ~¢¢o psig ..... ~ Does choke manifold comply w/API RP-53 (May 84) ...................... Is presence of H2S gas probable ...................................... ( 6 ) Ot h e r /¢/~_~ ./~ ;z//~¢ ?_~ 29. [29 thru 31] 30. 31. c7) ~2. (8) Addl /-¢- ¢~ ~. rev 12/92 jo/6.011 eng i n~e r ing' MTM/~ RAD ~ to'~ BEW JDH_L~ LG~T ~ FOR EXPLORATORY $ STRATIGRAPHIC WELLS: Are data presented on potential overpressure zones ................... Are seismic analysis data presented on shallow gas zones ............. If offshore loc, are survey results of seabed conditions presented... Name and phone nLrnber of contact to supply weekly progress data ...... Additional requirements ............................................. INITIAL G'EOL UNIT ON/OFF POOL CLASS STATUS AREA ~ SHORE Exp/Dev/~ Inj UM ~/ WELL TYPE: Redri 11 Rev _MERIDIAI',J' SM - ~ ' -- 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. REC'E VED M~R 1 9 199 Alaska Oil & Gas Cons. Anchorage RECEIVED MAR 1 9 19~: Alaska Oil & Gas Cons. Anchorage ALASKA COMPUTING CgNTER *------- ~CHLU~OERGER ****************************** FIELD NAME : PR[)DHOE ~AY BO~OUGN ~ ~ORTH S'~Tg : APt NUMBER : 50-029-22.325-00 LIS Ta~e Verification bi, sti. no Sch!u~berc~er Alaska Co~puti. no Center 9-~a~-1993 13:2~. **** REEL !,{EA. DER DATE : 9.]!03/ 9 O~!CIN : FblC ~EL NAa~ ~ 93057 PR ~7;V IOI3S REEL CO~ENT : ~RC(.~ ALASKA, INC,,PRU[:~'{OE B~Y,9-50,50-O29-22325-O0 D~TK : 93/0]/ 9 ('3~ IGI ~! : wLIC T~PK MA~E : 93057 COST:I~UATIOM ~ : !. COP~'E~T : ARCO a. LASK.5., INC..P~UDH!}E B:~.Y,9-50 LOGGING JOB S~tR~ACE LOCATION SECT!O~: KELLY B:ISH!MG: ~ ST ST~I.~¢G ?ND STRI ~:G 9-50 500292232500 ARCO A.[,,ASKA iNC. SCNLUaBERGE~ ~:E['L SERVICES 9-aA~-93 2 .1.727 6 55.00 54. O0 25.5(~ OPEN ~t ~:) I, ~; CASING DR I[,.LERS 8!T SIZE (IN) SIZE (IN) DEPTH ~.500 1073~.0 bis Tape Vertf. ication blstln(~ Schlumberger ,~lasKa Com~)utloc! Center O- -MAR-I., 993 1):21 PRODUCTION STR REMA~,S,, ~'!ELO EN(;!NE~E~'S REd'AP'KS: Tf)[~LST~ I ~,~G: ~4SF[,-D6L-[,~DT'CNL-GR-TCC-A,~S'B~ IDLE-SP-HEAD R~.N 1,3" rEFbOM STANOOFFS ON T~E DhL, AMS, ..~D RIGID ~RIDbE~, RAN ~ ~bb(~VER S[.,,E,,,,V~S TO H~LP T~Rq THE LDT AND MSFL PADS, ORI[,LING r'~UD ~A0 24,'(~00 pp'~'i CHLORIDES. ~,AI. RIX= SANDSTO{!E, DHC : NONE, .~'{DEN : 2,65 G/CC. HC : L[)T CAGiPER, FQ : ~,0 G/CC, bOGGED G~ ONLY 'JN CASING FRO~ 9 5/8" CASI~(~,*~ :BOTTOM T0 THE SU~FACE CASI~,~G. **** FILM HEAD~;R **** F~I,,,~ NA'"~E : EDIT ,001 SFRVICE : FL!C VERSION : 00lA07 DATE : 93/0~/ 9 ~45X REC SIZE : ~.0~4 FT[,,~ TYPE : LO L~ST F![,E FILM HE~DER F!b~ NUMBER: 1 EDITED CURVES All tool strings; De~th shifted and clipped curves; all runs meroed; no cased hole data. [)~PTH I NCRE~ENT 0. 5000 # ~'SFL CNTH $ ~$~LIN~ CU~V~ PO~ SHIFTS: GR C!;RVE SHI~T [)aTA (?~KASURED DEPTH) ..... 7 ........ 1~7,0 !!,128o0 1!~25.5 ~105o.0 !1036.0 11027.0 11027.o START [)~PTN STOP DEPTH .t144.0 ~07~2,0 11187.0 10732.0 11203.0 30732.0 1.~17~.0 1073~.0 !13.53.0 1073~o0 .......... FOUIVAt.:~_:?.~T JNSHIFTF[; DEPTH .......... {P L L, S f'; N C N T H 11125.5 1,1049.5 11O27.0 1112!.0 11092.0 1~.036.0 LIS 5~aoe verJ, f. ication ~,,istinO Scblum~erc~er AlasKa Computin<~ Center 9-~A~-1993 1~:2! !tO!q'O 10989.5 10980.5 ~ 0979 5 1.09§~i5 ! 0929 ~ 10925.5 10909 5 ~0889,0 10874°5 108~6 5 10836:0 ~0805,~ ~0743'0 0742 0 ~0649.0 10645.0 !0630.5 10610.5 ~058~.0 100.0 TOOL CODE !097~.5 1090~.5 10835.5 10741.5 11015.0 10989.5 10979.5 1.0930,0 ~0904.0 10~8~.5 10836.0 1o805.5 ~o728.0 1064:~.5 1.101,5,o lOq~3.0 10064.5 I0925.0 10~08,5 !0874.0 1(3742.0 1.0680.5 10644.0 10630.5 10609.5 1.0587.0 10586.5 99.5 99.0 '99.5 ~.!N N~:). PASS NO, MERGE TOP PAGE: PATA F~R~AT SPECIFICATIO~ RECORD ** ** SET wYPM - 64EB ** TYPE i 66 0 2 66 3 73 4 66 1 LIS Tape Verification !,istin~ $ChlUmberc]er A!as.~o Computing Center TYPE ~EP~ CODE VALUE 73 7 65 9 65 FT !~ 66 12 12 6~ 1] 66 0 !4 65 FT 15 66 68 16 66 ! 0 66 0 NaMF SERV UNIT SERVICE AP ID ORDER # bO DE~T FT 599363 00 I.~l~ DL!, ()H~ 599363 O0 L!~D DLL ONMM 599363 O0 S? DLL MY 599363 00 g~ DLL GA.P! 599,363 O0 T~NS DL!,, b~ 599363 00 MTE~ DLL DEGF 599363 00 ~ES QLL OHM~ 599363 00 TEND DLL LB 599363 ~$F!, OLh ONM~ 599363 00 RHOB SDN G/C3 599363 00 D~HO SDN G/C3 59~363 00 P~F SDN BN/E 599363 00 C~L~ SUN iN 59~363 00 NDH! CNT}4 pi.I-S 599363 O0 C~AT C~?~ 599363 NPAT CNTH 599363 O0 NCN? CNTh CPS 599363 FCNT CNTH CPS 599363 00 CNTC CNTH API APl AP1 FIL~ NUMB NUmB TYPE CLh$$ MOD NU~B S~MP 000 O0 0 I 1 1 4 000 O0 0 1 1 1 4 000 O0 0 t ! t 4 000 O0 0 1 1 1 4 hoe O0 0 1 I I 4 000 00 0 1 1 ! 4 000 O0 0 I ! 1 4 000 O0 0 I 1 1 4 000 O0 0 I 1 ! 4 000 O0 0 1 1 I 4 000 O0 0 I ~ 1 4 000 O0 0 1 I I 4 oo0 0o o i 1 ! 4 000 O0 0 ! 1 I 4 000 OO 0 1 1 1 4 000 O0 0 1 1 1 4 000 00 0 ! I 1 4 000 O0 0 I 1 I 4 000 O0 0 I 1 1 4 0 I 1 I 4 REPR CODE (HEX) 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 68 0000000000 68 O000000000 68 0000000000 68 0000000000 0000000000 68 0000000000 68 0000000000 oooo .ooooo mmmmmmmm mmmmmm ** DaTa ** bFP?. 1121 5.500 LL;4. D[,L -990.250 I~LD. DLI, -999. 250 SP. mt, I, Gn. DLL -999.250 TENS.DLL -999.~50 MTEM DLI, -099.250 M~ES, DL!,, TEND.DLL -999.250 ~SwL.DI, L '990.250 ~HO~'S[)~ -9q9 250 DREO SDN I ' ' .- m - . ~ DEW,SDN -9~9.250 CALl ,SDN 7,057 NPMI,C>~TH -999. ~50 CRAT.CNTM CWTrN~aT' ,CNTHCNTM -9~9'99m- 'n25~' ~CNT., . ,r~,~TM. -m99.~5(~.. FCNT~ ,CNT~ -999 ~5o.. C~-~I~C CNTH -999.250 -999.250 -999.250 -999,250 -999.250 LIS ~aDe verification Li$tlno Schlumber,.g~.r Alaska Commuting CeDter ~,,n DL!.,, 99J9. '' 5 . Y. .2,0 TEN8 DLL TEaD.DLL ~-461.296 ~Sw,b. D!~L mEF'SDN -999.250 CALl .SDN N~AT.CMTH -999 250 cFTC. CNT}.{ -999:250 DEPT. ! ~ 100. 000 bL GR.DLL' !!!.522 T~%~$. DLL TKND.DL~ !305,946 PE~'.SDN 5.9!5 CALl N~AT.CNTH 3.187 ~C~T.CN'T~ CFTC. CNTH 666. DFPT. ! ! 000. O00 LL.N GP'DL[, 44..996 TEN$.DLL TKND. DI.,[, !.263.3!5 MSFL.. DI,L PEF.SDN 4.793 CALl NRAT.CMTH 2.587 NCNT.CNTH CFTC.CMTH t073.453 DKP?. 10900.000 bLa.Dbb G~.DL[, 33. 166 TE[~I5. DI.,L TE~r~. DLL !205.354 ~ISFL. OLL PE~':. SDN 4. 243 CALl .SDN N~AT.CNTH 3.050 NCMT.CNTH CFTC.CNTH 808.512 OFPT. 10800. 000 L!,~q. DLL GR.DLL 29.279 TE~&.DLL TEND.DLb !297.805 ~SFb. D!..,L PE~.SDN 3.605 CALl NPAT.CNT.H 2.878 MCNT.CNT~! CFTC.CaT~ 8~1.719 DFPT. ! 060(',. 0o0 LL~,! G~. D[,5 -999.250 TEN$,DLL T~D.DLI, -999.250 '~SFb. DLL DEF. S9~'~ -999.250 CALl NPAT.CNT~ -999.250 ~/CNT. C~TH CFI'C.CNTH -999.2K0 9-gA~-1993 !~:2! 5.279 bLD.DL!, 5925.000 4.863 8.157 MP~I.CNT~ 2087.563 FCNT.CNTH 4 129 2.474 ~4 629.094 ~.9~5 LLO.OL, 5 9 080 5695.O00 ~TEM.Obb 1631114 4.488 ~HOB.SDN 2.358 8.109 NPH!.CNT~ 24.591 2668.250 FC~T.CNTH 1006.0o3 3.306 LLD.DLI,, 5625.000 ~TE~.DLL 2.815 RHOB.SDN 8.075 NPHI.CNTH 2315.500 FC~T.C~IT~: 2.504 ,11.62.~03 2.201 30.978 745.063 3 628 2 203 28!619 78O 56.'] -999 250 [,L[).O!,L -g99.250 -999:250 ~TEM.DLL 999 250 990 250 R~OB SD,q : :250 ' .-. . 990 8.707 ~PH!.CHTH -999.250 -990.250 FCNT.C~TH -999.~50 -999.250 I,LD.DLL -999.250 -999.250 aTEa. DLL -999.250 -999.~50 ~HOB.SDN -999.250 4.840 ~PHI.C~T~ -999.250 -999.750 ~CNT.CNT~ -999.~50 -999.250 I, LD.O!,L -999.250 -999.250 ~TE~.DLL -999.250 -O99.250 PHOg. SDN -999.750 4.g29 NPHI.CM?H -999.250 -999.250 FCNT.C~!TH -999.250 SP:.DLb aaES.DLI, DRHO.SDN CRAT.CNTH C~TC.CNT~ SP.DLL ~RES.DbL ORHO.SDM CRAT.CNTH CNTC,CNTH SP.DLL aRES..DLL DRMO.SDN C~AT,.CNT~ CNTC.CMTM SP.DLL MRES.DLL DRMO.SDN CRAT.CNTH CNTC.CNTH SP DLL DR~O.SDN CRAT.CN~'H CNTC.CMTH SP.DbL ~RES.DLL DRHO.SDN CRAT.CNTH CMTC.CNTH ~RES.DLL ORHO.SDN C~T.CNTH CNTC.CNTH SP.DI,L MRES.DLL CRAT.CNTa CMTC.CNTH PAGE: -999.250 0,065 :999.250 999.250 '999.250 '9.625 0,066 0.248 3.016 19~6.563 -28.938 0.066 0.051 2.394 2489.375 -19.606 0.066 0.100 2.803 2171.656 -37.250 0.066 0.029 2.653 2175.063 '999.250 -999 250 -999:250 .-999.250 999.250 -999.250 -999.25O -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 LIS Tape Verification ListiDq Sc~lumberoer Alaska Co~Duti. n~ Center CF'~fC . C~t,~ TH -999,250 **** FILE T~A!LEP **** SF~VICE : FbIC VERSIOM : DATE : ~3t03/ 9 ~X REC SIZ~ : t024 FIbM TYPE : LO **** FILM HEADEN **** FILM NA~E : EDIT .002 SERVICE : FLIC VERSION ~ 00{A07 DAT~ : 93/C]/ 9 ~X REC SIZE : 10~4 FILE TYPE : LO FILF HEADER FILE NUMBER: 2 EDITED CASED MOLE ~AIN PASS De~th shifted and clluued curves ~or open hole lo~S run into casin~, DEuT}{ !NCRE~EMT 0,5000 FILW SUmmArY PBU TOOL COD~ START D~PT~ STOP DEPTH [~ ......... ' ~064~.0 ' .... $95g,0 B~$~!,TME C!~RVE FOR S~IFTS: ---- ...... EQUIVALENT IINS~IFTEO DEPTH ....... DASEI, INE DEPTH GRCH 10617,5 10617,0 1058~,5 105~7,5 ]0560,0 10570.~ 10546,5 1.0546,0 ~0530.5 I0530,5 !00.0 Ioo.n Schlumberqer AlasKa Computin~ Center 9-.UAP-!993 !3:~1. PAGEI TO OPEN $ bls FORMAT DATA ** DATA FOR~qAT 8PECI'FICATION" ....... REC{RD' t ** ** SET TYPE - 64ED ** 1. 66 0 2 66 0 ~ 73 4 66 5 65 6 73 7 8 68 0,.~ 9 65 It. 66 42 12 68 13 66 0 1~ 65 FT 15 66 68 16 66 0 66 1 ** SET TYPE - CHAM ** ID ORDER # LOG TYPE CLASS ~OD ~[JMB SAMP ELE~ CODE (HEX) OFP? FT 599)63 00 000 O0 0 2 ! 1 4 68 0000000000 GnC~,~ DLL ~API 599363 O0 000 OO 0 2 1 I 4 68 000000o000 TF~B Db!, LB 599363 ~0 OOO 00 0 2 1 1 4 68 O0000OO000 T~NS DLL LB 599363 O0 000 O0 0 2 1 1 4 68 0000000000 ~!PE$ DUL GHu~' 599363 O0 ~00 00 0 ? ! ~ 4 68 0000000000 ~TE~ DLI, OEGF 599363 O0 000 O0 0 2 1 1 4 68 0000000000 D~PT. 10642.0n0 GRCH,DLI, 70.132 .... ~'TE".[,I,!, 151,735 ~PE~.D[,L 0.070 --~ .. ~ TEMD.Dbb 1216.408 TEMS.Dbb 5575.000 5!S Tape verification 5isti, nq Schlumberger Alaska Computinq CeDter DEPT. 10600.000 GPC~. DLI, DEPT. !0500.000 GRC~.DLL ~ES. DLL, 0.07! MTE~4. DLL D~TPT. 10400.000 GRCM.DLL DFPT. 10300 OOn D ~ P ·, 10 ~ O 0,000 G ~ C a ' D L L ~DES,DLh 0,072 ~TE~, DLb EPT lOlOO.O00 GRCH DLL ~. R E $: D L, b O. 072 ~.~' T ~ ~: D L L D~PT. 10000.000 G~CH. [)LL [')EPT. g900.O00 ~'~ E ~. ~ b 1, 0.074 ~ T ~. D L L DEPT. 9800.000 G~tCH. DLt~ aRES.DLL 0.074 07oo.ooo B~P~. g600.000 GRCH.DLL DFP*. 9500.000 GRCH,DLL ~PES,DLL 0.076 DF]PT. 0400.000 GPC~{. DL.L ~ES.DLL 0.077 D~PT. 9300,o'00 GP, CI-t, DI, L gRES.DI.,L 0,O77 DEPT. 9200.000 )q~E-g. OI.,L 0.077 D~PT. olO0.000 GRCH.DLL ~,~ES. DLL 0.078 DFPT. 9000.0nO GRCH.D[,L ~RES. BBl., 0.078 ~TE~. DLL D~PT. ~900.00{3 GFCf~. DLI, ~,~FS. DLI, 0.07~ ~TE:~. DLL 9-gAR-1993 1.3:21. I , 1. 2,938 T E 99,413 TENO.OLL 1.51,576 67.938 TENDoDLL 150.432 93.59~ TEND.DLL !00,154 TE~D,DLB ~47,578 71.955 TE~D,D[~L !47.001 98.054 TEND,DLb ~45i814 47 832 TE~D°DLL 143'864 56.673 TEND°DLL 143.043 51.~49 TESD°DLL 1,42.109 52.069 TE~D,DLL 70.117 TESD.DLh 139.6i4 55°9!3 !.3~,756 43°735 T~ND.DLL 138.106 66.092 TE~D.DLL ~37'~73 60 132 I227.531, 1.212.!65 1230.089 !239.503 1206.078 1~39.457 1,192.084 !191,285 1180.864 1!,84.88~ 1175.003 !152.797 1145.562 1168.4~4 1199.728 !~07.945 1211.859 !!82.1~6 TENS.DLL TE~S,DLL TENS.DLL TENS.DLL TENS.DLL TEBS,DLL TENS.DbL TEN$.DLL TE~S.DLL TENS'.DLL TEN'$.DLL TE~S.DLL TFNS.DLL TENS.DLL TEPS.DLL TENS.DLL TENS.DB!, 5680,000 5375.000 5395.000 5235'000 5i!0,000 5025.000 4975.000 4775.000 4805.000 4885.000 4690.000 4630.000 4555.000 4465,000 4495,000 46~0.000 4880,000 44!5.000 LIS Tame Verification Listino Schlumberqer AlasKa Computino Center DEPT. 880{), (;00 iMRES. DLL 0.079 b~TE~. DLL DEPT. 8700.000 GRC}.~. DLb ~RES. Dbb 0. 079 D~P~. 8600.00O ~RES. DJ, I,, (),0~0 MTEM' 9LL DEPT. 8500.000 GRCH.DLL ~ES.Dbh 0,080 DSPT. a400.O00 GRC!~!. O.LL ~'~KS. DLL 0.0~! DEP*. ~300.000 GRC~.Dt, L ?~RES. DLI~ 0.0gi DFPT ~'200.000 GRC~-i DLb ~ i t~ ..... NRES.DLb 0.081 I.)FPT. 8 1 O0.0 O0 GRCH. Dbl., gRES.Dbb 0.082 ~TE~4. DLL DE.D. ~(}00 000 GRCH Bbb . . MRES~DUb 0.082 DEPT. 7900.000 ~RCH.DLh ~ES.DLL 0,082 DFPT. 7800.000 GRCH.DBL ~ES. I)LL 0.08] ~T[~. DI.~L DFPT. 7700.000 GRCM.DLL ,~ES.DLb 0.084 DMPT. 7600.000 ?~R~S.DLb 0,0~4 DEPT. 7500,000 DFPT. 7400.000 ~ES, DLL O, 0~5 DFPT. 7]00.000 GRCH.DLL DFPT. 7200.000 ~ES.DLL 0.9A5 UTFM.[)LL 9-MAR-1993 13:21 63,744 T~:,:[ .OLL 135. 562 57.838 TF.,rq D. DLh !.34,755 48.5!6 TEND.OLL 134.11,4 46.251 TE~JD,DbL !33.250 42.617 TEND, DI.,b 132'653 . 35 548 TEND 131:9S5 13!.155 61.039 TENO,OLb 130.603 ' ~29:867 40 552 TE_~D DLL ~29.071 47.175 TEND. DLI., 127.688 126,654 45,19a ~FT~.ID, DLL 126.06g 48.6S3 23.173 T~.;N0. DLL 124.~12 12o4.33a 1197.o67 1!54.o14 l!8O.437 t~19.127 1151.410 1~24.379 1186.578 1143.04~ 1147.564 !.161.529 1174.092 1171.030 1161.699 1153.234 113o.38~ 1113.599 TEM$.DbL TENS.DbL TEMS.DbL TMNS.DLL TENS.Dbb TENS.ObL TENS.DLL TEN$.DLb TENS.DbL TENS.DbL IEMS.DLL TENS.DLL TENS.DLL TMNS.DbL TENS.DLI~ TEMS.DLL TENS.DLL PAGE: 4395.000 4490.000 4400.000 4430.000 4430,000 4210.000 4170.000 4210.000 4250.00O 4235.000 4200.000 4050.000 4070.000 4095.000 3870.000 3915.000 3960.000 L!8 ~aue Verificatlon Listin $chlumberoera!aska Co~'~putin DEPT. 7100,000 MP[iS. DLL 0. DEPT. 7000.000 DEPT. 6900,000 '~i~ES. DLb O, 086 D~PT. 6800.000 D~PT. 6700. M~g8. DLb O. 0~7 D~PT. 6600, t.)OO a~gS, Dbb 0.0~7 DSPT. 6500.000 DEPT. 6400, ()0C' ~ES.DLb O.0~9 DEPT. 6 300,000 ~4~ES. D!.,b 0. DEPT. 6200. 000 ~PE8. D.bl, O, 000 DEPT. 61.()0. 000 ~!~E~. DL!., O. 092 D~PT. 6000. 000 ~:~P ES, DLL 0,094 I)FDT, 5900,000 [)~3pT, 5800, aPES, DLL 0,006 [.)~pT. 5700. OD0 5~ES. DLI, O. 097 t)~PT. 5600. CO0 ~,~ES. DLL O. <;97 DFuT. 5500. 000 ~E,~, {}LL 0,098 DEPT, 5400. N~E8. nLI, O. 100 Center 9-~AR-!993 13:2~ 32.887 ~.24,290 47.868 TENO,DLL 1.23.504 28.3U5 TE~D,DLb ~23,0~9 54 296 ~END,DLb !22[720 47,750 TEND,DLL 12~,417 48,805 TEMD,DLL 1,21,561 48,$8~ TE~ID,DLb ~20.082 33,871 TEND.DLL 120.001 5~.965 TEND.DLL !18.750 61.!4! 118.045 37.707 TEUO.Dt, t, 117,~.35 24 732 30.313 TE~!O,DI, L 37,756 TE~JD.OLL ~i~.41,7 28,398 TEND.DLL 1I!.2~7 19.968 TEbiD.DLL 11o.~60 24.329 tOq.2Ol 54.445 TEr~D.DLL !1,2!.226 I195.590 !158.318 1,173'039 !.!71.421 11,54'123 1,140.505 1155.688 i15~.313 1178.570 1149.500 1127.016 !169.121 1135.828 l!46.750 1!82.~13 1!73.70] 1195.217 TEN$.DLL TENS.DLL TENS.DLL TMNS.DLL TEM$.DbL TENS.DbL TE~S,DLL TEMS.DLL TEM$.OLL TENS.DLL TENS,DLL TENS.DLL TE~S.DLL TENS.DLL TEMS,DLI~ TEMS.DLL TENS.DLI, TENS.DLL PAGE: ! 0 3865.000 3890,000 3875.000 3775,000 3755.000 3565.000 3650.000 3694,996 3634.875 3490.000 3410.000 3435.000 3440.000 3309,875 3355.000 3399.935 32~5.000 3240.000 LIS Tape Verification !,tst.in~ $chlu,..mber~er Alaska Comput:ln,:~ Center DEPT, 5200.000 GRCH, DI,,L ~RE$. DLL 0. I01 DEPT 5100,000 GRC},.DLL [)F~:PT. 5~o0.060 GRCH,DLL ~ R E S ' D b L 0.102 ~,! T E {4. [) L L D~PT. 4900.O00 GRCH.DLL D~PT. 4800.000 GRCH.D[,L DEPT, 4700.0e:0 GRCH.DLL M R g $. D L b 0.104 P K P T. 46 o O. 0 o 0 G ~ R E g. D L [, 0. ! O 5 ~ T E ~. D L L DEPT. 45o0,000 GRCH,DLL :4RFfS, DLL O'106 MTEa. DT_,L DEFT 4400 00o g R [<:.q. DLL 0.107 ~TE~. DLL DEPT. 4300.000 ~:~PES, DLL 0.107 a'T~. DLL DEPT. 4200,000 GRCH.DLL ~ES. DL.L 0.107 HTE;t~. [)LL . GRCr, DLL DFDT 4100.000 ' ,'t. ~RES. D!.,[, 0,108 ~ITE~. DLL, D~PT. 4000.000 GRC~4.DLL ~E5. DLI, O. ! 09 DEPT. 3909.500 MPFS. DLT O. ! O~ ~,,?TE;~. i.)LL O-~{Aa-! 993 ~3:21 37.590 T ~; N O. D L .107. 194 46.:~23 106..6.07 49.9~4 TEND, !.05.912 50.454 TEND.gDL !. 05. 456 34,008 TENg. DL[,~ 104,675 72.358 TEND.DLL 103. 430 46.871 T~ND, Db.b ~ O2,652 ~02.243 ~ · ..~. % ') ~7.3a8 ~g[~t .DLL ~ 01,229 43.788 T~ID, DLL 46.158 TEND, PbL ~00,064 46,702 T~ND, 99,6!6 98.722 30 . 185 T~:ND. DI.,L 98.277 1155,567 1155,719 1246,000 1.194.467 1230.422 !167,446 I175,664 1213.584 I205.854 1240.084 1198.719 1199.394 1!88,350 1~.77.521 1203.094 T E ~i $. D TENS. DLL TENS, DbL T~N'S. DLL TENS. DLB TEN'$. D t, t., TENS. ' ~ ' TE,. S, TENS. DLL TENS. DLL TENS. DLL TENS, DL[., _ENS.DLL TE~IS. DLL PAGE: !1 3080,031 2975,000 3250,000 3165,000 3125.000 3040,000 3!30.000 3080,000 3055.000 2865,000 2930,000 28t5.000 2865.000 2845.000 2765.000 LIS Tape Verification Listing 8Chlumberc~er AiasKa Computinq Center q-~AR-I993 13:21 PAGE: FILE NA~E : EOIT .002 S~TRVlC~ : DAT~' : 93/03/ 9 F!LF TYP~ : LO baST FILE : **** F!L,E HEADER **** Fl'bM NA~E : EDIT ,003 SERVICE : WblC V .W..:R$ [ O~,~ : 001ho7 D,~TE : o3t03/ 9 ~.X REC SIZE : 10~4 FILE TYPE : LO LAST FILE : Ct~rves and :1, o~ header data for~eacb rum and..tool string In separate files; Tool St:ring #1 fo Sadler. ochit r~ln mresented firs~ (prl~a~y depth control string Used t,O depth shift the Sadt. er interval) followed by files for other main pass strings per run. TOOL ~TRING ~[JMBER: PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FI~ SUMMARY VENDOR TOOL CODE START . . 0bi., !.1189.0 C~*'~H 11 l. 55.0 LOT 1. I !. 70.0 bog !.IE~DE~ DATA mATE LOGGED: SOFTWARE VERSION: · i~E C!RCULAWlON ENDED: TI~E LOGGEP O~ BOTTOm: TD DRI[,bMR TD .GOGGE~(FT): · OP LOG INTErVAl, (FT): n[iTTOM 5fIG INTERVAL LOGGING SPEED 7'(][!L STRING (TOP V~NDO~ TOOL CODE ~'OO[, TYPE; STOP DEPTH 1.520,O 10520,0 10520.0 10520.0 09-FES-93 5C0-42~ 113o 1718 11212.0 3950.0 11.200,0 1~00,0 0g-FEB-93 0g-FEB-93 TO05 ~3!J ~g ER LIS. TaLe Vertf,ication Listl, ng Sch!umberoer Alaska Comoutinq Center 9-~A~-~993 13:21 13 ~]CH TELEMETRY CARTRIDGE GR G.AM~A RAY GR G i,~: i RAY LDTD ~UCL~iAR SERVICE CART, LDTD DENSITY RESISTIVITY' Dbb DUAL LATEROLOG ObL DUAL LATEROLO~ CART, DSL DU.AL LATEROLOG S[3NDK DLb DUAL LATEROLOG -l, iSFL D,LL Dt~AL LAT~ROLOG -~SFL DRtLSERS CASING DEPTH (FT): LOGGERS CAS!~G DEPT~ (FT): ~OPEHOLE CO:qDITIO~S MUD TYPE: ~UD DENSITY (LB/G): MUD VISCOSITY (S): ~UD FLUID bOSS (C3): ~AXIMU~ RECORDED TE~PERATilRE (DESK): RESISTIVITY (OHMS) AT T~PE~AT[I~E (DEGF): ~UD AT MEASURED TS~PERATURE (MT): MUD AT Br)TTO~! HOLE TEmPERATUrE ~UD FILTRATE AT ~UD FILTRATE AT ~UD CAKE AT (~W): ~UD CAKE ~T 8GH-~ 50 SGC-SA 60 C.~ C- !{,~ ~!90 CNC-AB 2.!_ 6 ~ GSR-J 1.815 ~GD-G 1815 NSC-E 775 ~C~-MKA 781 DRS-C 4950 PDH-L 3765 DhH-CB 2748 DLC-D 761 DLS-F 975 SRE-F 776 S~S-D 8 50o 107]2.0 2% KCL SYSTE~ 9.40 44,00 9,50 6,30 160.0 0,195 70.0 0.157 67.0 0.359 70.0 TOOL TYPE (EP!TgEP~AL OR THERMAL): ~ATR!X; ~&TRIX DE~SITY: HOLE CORRECTIO~-~ (IN): TCOL STANDOFW PE~APK$: THERmaL SANDSTO}~E 2.65 1.3 TnObSTR I.~,~G: ~S?T,=DLL-LDT-C~ L-GR -TCC-.~ ~S- BR IDLE-SP- HE AD. RAN !,3" TEFbOk~ STANDOFFS [;:~J TPE OI.,b, .AM~ ~;qD RIGID BPIDL~, . ~A:'~ 2 ROL[.,DVER SLKEVE~. o TO lJELP"Tu~:'J THE I,DT AND ~SFL PADS. D~'TbLING ~UD HAD 24,000 PP~ CHLORIDES. CNL ::ATRIX = gA~DSTDNE, D~C = i~ONK, ~.{DEN = 2.65 G/CC. ~C = LOT CALIPEr, FD = 1.0 G/CC. LOGGED GR OMbY IL: CAS!N~ F~C~': 9 5/~" CiSING 8OTTO~ T0 LIS ?'a~e Verif.tcation I~istino S6hlUmherger~. asKa Computing Center $ # L~$ FOR~,~AT DATA PA~E: 14 ~ 66 0 3 73 ~20 4 66 1 5 66 6 73 7 65 8 6~ 0,5 1~ 68 13 66 0 14 65 pT 1.5 66 68 16 66 1 0 66 ~ ** SET TYPE - CMAN ** --:: .......... ...............: ..... . ....... :.-.. ...... ....... ..... . ...... t,}~ S~:RV U~IT SERVICE ~P...~ ~PI AP! A~I FILE Nt,J~IB NU~8 S,I. Zg ~EPR .PROCE. S~ I0 ORD~P ~ bOG TYP~ CBASS ~OO ~,!~8 S~P ~[,Eg CODE (HEX) DgPT FT 599363 00 000 00 0 3 1 1 4 68 LL$ DLL O}la t.~ 599363 OO 000 00 0 3 I 1 4 68 LI,D DLL C, ~'.l ~ t;: 599363 O0 000 00 0 3 i 1 4 68 Ca[,S DLL IN 599363 O0 0fi0 00 0 3 1 ! 4 68 CALl ~ [~ [., IN 599j63 00 000 O0 0 3 1 1 4 6~ C,~L1 DLL IN 599~63 O0 0O0 00 0 3 1 1 4 68 sm Db[, ~V 590363 O0 000 00 0 3 I 1 4 68 (;~ DLL G~PI 599363 DO 0o0 O0 o 3 1 I 4 68 TF~S DLL .L~ 599363 O0 000 O0 0 3 1 1 4 68 ~.~r~;- ~LL DEGF 599363 O0 000 00 o 3 1 ! 4 68 H~ES DLL O~a~ 599363 00 000 00 0 3 1 1 4 68 HTE~ DLL LB 5993~3 o0 000 nO O 3 1 I 4 68 MSF~, D!.,L {]H.~, 599~63 00 000 O0 0 3 ! 1 4 68 S~!" Obr, OH~,~ 599363 O0 or, o O0 0 3 1 I 4 68 S~NO O[.,[ OH~4~ 599363 00 00O 00 0 ~ 1 ~ 4 68 DPHT bl')T PU 599363 O0 000 O0 0 3 1 ! 4 68 RFOn LDT G/C3 59~363 O0 OOG O0 0 3 1, 1 4 68 [,)~0 LOT ~/C3 599363 O0 000 O0 0 3 1 1 4 68 0000000000 O000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 O000000000 0000000000 0000000000 0000000000 0000000000 000O000000 0000000000 0o00000000 0000000000 LIS 'raVe Verification Llstin~ $chlumberoer AlasKa Computino Center PAGE: 15 ! PEF LD7 OSS LD~ BS I,,~D ~ CPS I.,U !~D? CPS SS 1 !,,D~ CPS SS2 LOT CPS LSP~ LDT V 8SHV I.,,D T V 81~" LDT G/C3 l.~S~ LDT G/C3 T,,URH LDT G/C3 CA61 I.,D~ C~L! LDT G~ I~DT O~PI ~'r ~; ~ LDT DEGF g'~ES LDT }.~TEN LDT L6 NPHI CML PU RTN~ C ~ i.., TNp~ CNL PU TS~a CNL NPO~ C N' I.., PU ~CNT C~L CPS RCFT CNL CPS C~{TC CNL CPS C~TC C~L CPS G~ CNL GAPI C~.LI C~!L IN C~,LS CC;L I~ T~NS CNt, LB M TE ~.~ CML DF;GM H T~:~ C'NL VIC,,,,.; D ORDE~ # bOG ''''''''''''''''''''''599 Oo 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 OO 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 599363 O0 000 590363 O0 000 599363 O0 000 599363 O0 000 599363 00 000 599363 00 000 599363 O0 000 599363 00 000 590.363 O0 000 599363 O0 000 599363 O0 000 59~363 O0 000 5993~3 O0 000 599363 O0 000 59o363 O0 000 599363 fl0 59o363 00 000 599363 O0 000 590363 o0 000 '.PI APl ~P! FILE ~,~B NU .... SIZE RE P~OCESS TYPE CLASS ~OD NI,!~B SA~P ELE~ CODE {HEX) · . 0 O0 0 3 I I 4 68 o0000000 0 00 0 3 I 1 4 68 0000000000 O0 0 3 I I 4 68 0000000000 0o 0 3 1 1 4 68 0000000000 00 0 3 1 1 4 68 0000000000 O0 0 3 1 t 4 68 0000000000 O0 0 3 I 1 4 68 0000000000 O0 0 3 t 1 4 68 0000000000 00 o 3 I 1 4 68 0000000000 00 0 3 1 1. 4 68 0000000000 O0 0 3 ! 1 4 68 0000000000 O0 0 3 ! 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 00 0 3 ! I 4 68 000O000000 00 0 3 1 I 4 68 0000000000 O0 0 3 I 1 4 6~ 0000000000 O0 0 3 ! I 4 68 0000000000 00 0 3 1 ! 4 68 0000000000 O0 0 3 1 ! 4 68 0000000000 00 0 3 1 1 4 68 0000000000 00 o 3 1 1 4 6~ 0000000000 00 0 3 1 I 4 68 0000000000 O0 0 3 1 ! 4 68 0000000000 O0 0 3 1 1 4 08 0000000000 O0 0 3 I 1 4 68 0000000000 O0 0 3 i I 4 68 0000000000 00 0 3 1 1 4 68 000000000o O0 o 3 1 ! 4 68 0000000000 O0 0 3 I t 4 68 0000000000 O0 o 3 1, 1 4 68 0000000000 O0 o ~ I I 4 68 0000000000 O0 0 ] 1 I 4 68 0000o00000 00 0 3 1 I 4 68 0000000000 O0 0 3 1 I 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 00 0 ] 1 1 4 68 0000000000 O0 0 3 1 1 4 68 0000000000 112!5.500 7.225 4335.000 4.056 2.!6t 0,027 l~6.614 1216.b5~ 7,225 bLS. DLL CALl .DLL DRHO.DDT LS. bDT SSi .BDT S!PW,L~T CAI, 1. bDT 73.770 LLD.DLL 60.520 CALS.DLL 7,057 SP,DLL -20.000 GR.DLL 163.~54 MRES.DLL 0.065 HTEN.DLL 0.133 SgNO.DLL -0.029 DPHI.LDT 0.261 P£F.LDT 25.014 0I, S.LDT 805 928 !,[.i.LDT 744.273 LI,.LDT 373:~75 8S2.bDT 531.554 LSHV.LDT 1.404 LSRH.LDT 1.O02 LItRH.LDT 7.057 Ga.bDT 175.24o TEMS.LDT 7.133 175,249 428.945 29,492 -0.043 433.792 1159.650 1,941 4335.000 LIS Tape Verification L!stino $c.hlUmberger Alaska Computin,~ Center ~4TE~.LD~' 163,~54 ~RES,.LDT RTN~,CNL 3.200 TNP.H, C~.iL RCN T, C~[., I972,289 RCFT.CNL G~.C~[, 175,249 CALI. C~.~L ~ES, C~gL 0,065 ~4T~4, C~:~L DEPT. l 1200,000 bLS, DLL CAb!.DLL 7,225 CAL1,DLL T~S, DLL 6250,000 ~TE~4, DL5 ~SFL,DLL 5.654 S~'~IN,DLL ~40~,LDT 2,163 DRY{9, LDT OSS. LOT 0.0~7 LS. LDT L!T~. LDT 126.614 SSI. LDT SSF~V. LDT ~2!6.65~ S1R~.LDT CaLY.LDT 7.225 ~TgU,LDT 163,854 ~RES, bDT RTN°.CNL 3.200 RC>~'T C~<[, 1972'2~9 RCFT. · ...... CNL GP.CNL 175,249 CAL !'. Cr-~L M~ES. C~L 0. 065 ~TE~a. C~,~L D~PT. I I 1 O0,000 LLS. DLL C5. L~!.DLL 8.564 CAI, I.DI.L TENS,DLL 5925.000 ~SFL. DLL 5.!8! S~'~IN. DLL RHO~.LDT 2.474 DRHO.LDT OSS.LDT 0.098 LS.LnT ~T~. LDT ~9.024 SS1. LDT SSf'!V. LDT ~21.7.837 SI~.LDT C~I.,T.LDT ~.564 CALI,LDT MT'Eu. LOT 162.629 ~kES., LDT a'r,~.cNL 3.133 ~Ct~. C~:; I, 2062.202 RCFT.CNL G~.CNL I 1 1.5~2 CALl, D~T. I I 0OO, 000 bLS. DI.,L CALI.D[,I, 8.683 CAI., 1. D!.,L T~?~S. DLL 56~5.000 ~,'TEa. DI,L ~,~Fr.. DLL ,1.488 S~'tl N. DI.,L ~SS. EDT u. 040 LS. LDT L!TP. LDT ~7.6~1 SS 1. LDT SgHV.LDT 12!9.055 SI~.LDT C~LI.LDT 8.6~ CALl .LD7 aTEU.LDT 163.1!4 ~RES. LDT ~C~T.Cf~L 2737.646 PCFT.CNL GP.CNf, 44.986 CALI.CNL ~ ~ E,g .Caf,, 0. 066 ,~TE~4. Ca~.OI, L e.489 CA[,i.DLL TEk~S.DLL 5505.000 NSFL.DLL 2.176 9'~AR-I993 13:2I 0,065 HTEN,LDT 33.741 TN~A.CNL 609,607 C~TC,CNL 7,225 CAL$,C~L !b3,8~4 ~TEN.CNL 73.770 LI, D.DLL 7,199 SP,DLL !63,~54 ~RES,DLL 0.!65 SMNO,DLL o-261 PEF.LDT g05,928 LU,LDT 37],275 SS2,LDT 1,464 LSRH,LDT 7,199 GR,?DT o 065 3317~J ~!NRA.CNb 609.607 CNTC.CNb 7,225 CAbS,CNL 163.854 "TEN,C~L 8, 8 Sp. DLL 152.629 0,21@ S~O,DLL 0°244 PEF,bDT 453.685 LU,LDT 1.813 LS~H,bDT 0.066 35.176 &37.140 CNTC.C~L 8.564 CAb$.C~L 162.629 HT~lt.C~L @,OAS LLO.~LL 8.109 SP.DLL 163.114 ~RES,.DLL 0.474 0.050 PEF.LDT 401.234 Ld. LgT ~71.3~7 2.!~ LSRH.LDT 0.066 HT~.LDT 24.539 T~A.C~L 9~7.~24 CNTC.C~L 163.~14 HTFN.C~L a.~95 SP.~LL 162.803 ~RE:S.OLt, 428,945 2.979 190!.224 7.t33 428,945 60.520 -20,000 0.065 0.~6.4 9,.76 744.~73 531,554 1.902 1.75.249 1461.296 2,979 190~.~24 ~,056 !461.296 4.O86 -!0.188 0.066 0.188 5853 4262119 417.707 ~.230 ~1.522 1305.946 2.977 2003.640 8.633 1305.946 9.080 -28.g38 0,066 o.664 4.788 375.~22 364.382 2.303 44.986 1~63.315 2.346 252~.740 ~.550 1203.315 -19.500 0.066 0.446 NPHI.CNL ~POR.CNL CFTC,CNL CALS,DLL GP,DLL HTE~,DLL DPHI.LDT aLS,bDT LL,LDT bSHV.LDT LURH.LDT TE~S.LDT NPH!,CNL NPOR,CNL CFTC.CNL TENS,CNL s ~L CAL,, NTEN.DLL DPSI.LDT QLS,.LDT LL.LDT LSH¥.LDT LU~H.LDT TENS.LDT NPHI.CNL NPO~.CNL CFTC.CNL TENS.CNL C~LS.DLL G~. DLL }{TEN. DLt, DPHI.LDT OLS,I, DT LL.LDT LOHV.LDT LURH.LDT TENS.LDT NP~I.C~L CFTC.CNL TE~S.CNL CALS,DL{, G~. DLL ETEM. DLL DPHI. LDT PAGE; 35.36~ 33,741 648,696 a335,000 8,056 175 249 29.492 -0'043 433,792 I!59,650 1,941 6250'000 35.368 33,741 648'696 6250,000 8'633 111'522 1.305.946 10.654 -0.022 240.625 1163,467 2,247 5925,000 3~.546 35 508 6622253 5925.000 8,550 44,9~6 1263,315 18.012 -0.013 21:t,324 !!64,750 2.320 5695.000 23.874 23.067 1078,408 5695.000 8.604 33.166 1205,354 24,943 16 LIS Tape verification Llstinq Schlumberger Alaska Co~Dutin~ Center RHO'~..!..,DT 2,238 0~, bi)7 0,079 L~, bDT L't . LOT 1 ~5,54.8 SS 1. SSHV, L[)T 1219,573 SI~H,LDT C~,L!.LDT 8,,~9 CAL!.LDT F~'TE~, bDT 162.~03 HRES,LDT ~:TN~.C~JL 2, 33 TNPH ~C~T. CN:L 2203.1~8 ~.CNL 33,166 CALI, C~.{L ~.) E P T. ! 0800,000 b L 8,. D l, L CAL!,DLL 8.602 CALI,DLL TENS.DLL 5625.000 MTE~,DLL ~SFL,DLL 2,4~2 R~O~.LDT 2,204 DRHO,L[)T 0 S $, b D T 0,062 b S · L D T LITe,LOT 1 ~2. 348 SS1. bDT SSHV.LDT !220.049 SI~H.LDT CALI.LDT a ,02 CaLl.bDT ~4TE~, L!)T 161,951 ~Ta~ CML 3,056 T~PH. CMl.,, G~.CNL 29,279 CALI C}~L DEPT, I0700.000 LLS,DLL CIL!.DLL 8.679 CALI.DLL T~NS'DLL 5615.000 ~TE,~.DLL ~SFL.DLL C.650 SMIN.DLL RHOg. LDT 1,944 DRHt),[~DT OSS.LDT '0,065 LS.LDT LITH.LDT 22.~02 SSI,bDT SSHV.!~DT 1221,3~8 SI~H,LDT CnLI.LDT ~.679 CALl,bDT ~T~".LDT 159.35~ ~RE$.LDT ~TigR,CN'L 4,371 TNPH.CNb RCNT.CNL !~49.]32 gCFT.CNL GD,CNL °4.350 CAI,I,C~L ~PMS.CM!, 0.067 DEPT. !0600.000 LL$.~LL C~LI.DLL 8.608 CALI.DLL TENS.DLL 5445.000 ~TE~.DLL ?SFI.,.DLL 0.144 SHI~.DLL RHOP.LDT 1.894 D~HO.LDT QMS bDT -0.052 LIT~.I.DT 20.q41 SSI.bDT S~H¥,LDT !222.09~ SIRH.LDT ChLI.[,DT 8.698 CALl.bDT hTE~,.LDT 15~.298 MRES.LDT RT~.CN!~ 4,026 TacH.CML RCN~.CN!, ]353.1~7 ~CFT.CNL GR.CNL 109.860 CAbI.C~iL ~ES.CNL 0.070 MTE~.C~i, 9-~A~-1993 13:21 0.098 PEP.bDT 540.272 LU.LDT 300.1,17 $S2.LDT 1,937 LSat,bDT 8.195 GR.LDT 0.066 HTE~,bDT 29.444 TNRA,CNL 766,358 CNTC,CNL 8.489 ChLS.CNL ~6~.803 HTEN,CNL 3,2~0 ~.0 7 SP.DLb !61.951 ~RES.DLb 0.3~9 S~NG,DLL 0,031 PEF,, D bDT 512,075 LU,L,T ~74,578 SS2,LDT 2.086 LS~H.LDT 8.077 GR,LDT 0,066 HTE~.LDT 31.016 16I. 5! 0.149 LLD,DLb 8.707 SP,DLL ].59.35~ ~RES.DLL 0.039 SMNO,DLL -0,77~ PEF.LDT ~96,520 LU.LDT 79.70~ SS2.LDT 4.293 LSRH.LDT 8.7~7 GR.LDT 0.o67 HTEN.LDT 51.772 TMR~.CNL 281.036 CNTC.C~L 8.679 CAI~S.CNL 159.358 HTEM.CNL 98.600 LLD.DLL 4,829 SP.OLb 156.29~ gRES.DLL O.067 SMMO.DLL -0,804 PEF.LD1 200.063 LU,LDT 77.9u4 SS2.LDT 4.323 LSRH.LOT 4.~2g GR.LDT 0.070 MTEM.LDT 47.740 T~RA.CNL 305.503 ChTC.CNL R.69R CAbS.CML 156,~98 HTE~.CNL 4.4~2 504.161 392.852 2.!40 33.166 354 2!68.074 8.604 1205,354 3,524 -37.000 0 066 3.< 57 474:26 368.523 2.173 29~279 1297 8O5 2 782 21~4 054 8.502 1297,805 0.089 -34 250 0:067 -0.297 !.6.774 ~93.424 ~21.445 ~.715 94.350 1290.580 4.026 1221.2@9 8.900 1290.580 6n.52o -31.625 0.070 -0.t06 24.~43 198.916 !17.171 2.698 1.09.860 1202.846 3.990 1286.276 4.711 1202.846 OLS. bDT LL bDT bS~V :LOT bURH.LDT TEES.bDT NPM!,CML NPOR.CNL CFTC.CNL TENS.CML CALS.Dhb GR.DLL HTEN,DLL DPHI.LDT OLS.LDT LL.LDT bSMV.LDT LURH.LDT TENS.bDT NPH!,CNL NPOR.,CNL CFTC.CML TE~S,C~L CALS.DLL ~R.DLL ~TES.DLL DPHI.LDT OLS.LDT LL.LDT LSHV.LDT LURH.LDT TENS.bDT NPMI.CNL NPOR.CNb CFTC.CMl., TENS.CML CALS.DLL GP.DLL HTEN.DLL DPHI.LDT QLS.LOT LL.LDT LSHV.LDT LURH.LDT TE~S.LDT MPHI.CNL MPOR.CNL CFTC.CNL TE~S.C~L -0,034 2~8,I91 11.65,94t 2.152 5505.000 ~9.6!4 30.22! 817,!56 5505.000 8,502 29.279 1297 805 27 035 274 ~3 1165,301 2,I86 5625,000 30,51.9 31.492 776,830 5625'0O0 8,900 94,350 1290,580 42.812 -o.ool 99 Bog 11672938 2,760 5615.000 52.569 52.555 301.079 5615.000 4.7~1 109.860 1202.846 45.797 -0.025 100.605 1168.974 2,738 5445.000 51.898 47.011 337.188 5445.000 17 LIS Tame Yertflcation ListJ~no Schlumber¢~er-~A!as~a ComputinQ Center g-N&R-1993 13:21 18 DEFT. 105 .! 9.000 b .[.,~. DLL CAbl.D[~5 2.906 CA[,I.DLL T~NS. PL..5 5335.000 ~SFI.,. DLI, 0.144 $~4!N'. DLL R~OB.LDT !. 410 DRi{O.LDT OSS.LDT -O.O26 LS.LDT L!T~{. LDT 25fi. 620 SSt. LDT SSHV.LDT !.218.309 $!RH.LDT CALI.LDT 2.906 CALl.LOT ~'TE~ LDT 152 9~8 RTb!R CNL 4.316 ~C~!~.CNL 1391,3!6 RCFT,CNL G~. CNt,, 111.269 CALI.C~:~h .~ ~ ~. .. . ~ ..... CN.L 0.071 ~ T E,14 C~.~L 3.390 LLD.DLL 482~ SP,DLL 15~.~.- .98~ ~RE$.DLL 0o0~9 S~NO.DLL '0.020 PEF.LDT 1889.542 LU.LDT ~75~91 SS~.LDT 1'~12 LSRh. LDT 4.~29 ~R.LDT 0.07! 51,~32 T~RA,CNL 345, ..86 CNTC.CNL 15~.906 CALS.CNL · .98~ HT~q. CNL 60.520 0.071 -0.305 12,111 1945.170 47.4.545 1.430 111.269 I~13.866 4.147 1350.562 4.705 !~13o866 CALS.DLIi:, HTEN.DLL DPBI.LDT OLS, LOT 5L. BDT LSHV. LDT LURN. LDT TE~$.LDT NPHI.CNL NPOR.CNL CFI~C C~I, T~NSiCNL 4.,705 1!1.269 1213,866 75.!68 -0.i98 916.956 1!60.560 1.458 5335.000 61.499 51~I, I3 348'541 5335.000 **** FILE T~AI[,E~ **** FIL~? N.h~IE ; EDIT .003 SERVICE ; FLIC VERSIO~] : 001107 .MAX REC S.[ZE : 102.4 FILE TYPE LAST FILE : **** FILE HEADER **** FILK MA~E : EDIT .004 S~RVICE : FLTC VFRSION : 00!A07 D~T~ ~ 9310.3/ 9 FIL~ TYPE : LO L~ST FI[,E FTL~ ~UHBER 4 Curves and loq ~eader data for each RT)~,~ NIIHBER: 1 TOOL STRING FTLF SU~!ARY VS][~DOR TOOL C(-ID~? START DEPTH mass, tool STOP DEPTH strinq, and rUB iD separate files, Schlumberger Alaska Computing Center !3:21 PAGE~ C N T H LOT $ # ~ATE LOGGED SOFTWARE VERSIO~ T!~E CIRCU[,ATIO~ E~DED: TD DRILLER TD LOG~E~ (FT TOp LOG I~TERVAL ~OTTO~i bOG I.~!TERVAL LOGGING SPEE[~ (FPHR) 1!144.0 1!.!88 0 ! ! ! 7 0.0 10702,0 t0702.o 10702,0 !070~,0 TOOL CoD~ TOOL TYPE .A{}XILLiA~Y ~EASUR~t~iE~T ECH C~T~ CNTH LDTD DDTO LOTD LDTD LOTD LDTO DLL D L [, DLL [)LB DI~L S TMLE~ET~Y CARTRIDGE CO~4PEr-JSATED ~EUTRO~ GA~A RAY SOURCE POWERED GR DETECTOR LOTD DE~qSITY RESISTIVITY POWERED G~ Hr][)SING DUAL LATEROLOG HOUSIaG D[I&L I.,~T6]ROLOG CART, DUAL LATEROLOG SGMI)E DUAL LATEROLOG -MSFL DUAL LATC~OLO~ gOREHOLE AND CASI~G DATA OPEN HOLE BIT SIZE (IN): LOGGERS CASING DEPTH gO~EgOLE CONDItIOnS Wild TYPE: ~UD DENSI?Y (L~/G): gUD VISCOSITY aUD FLUID LOSS ~AX[~IJM R~CORDED TEqPERAT[IRF (DFGF): RESISTIVITY (O;l~) AT qUD AT ~EASURED TE~PERATI~RE (MTL: ~UD AT 80TTO~ MUD FILTRATE AT (~T): 09-FEB-93 5C0-42~ 113o 1718 11212 0 11~05~0 3950 o 1800,0 09-FEB-g3 0g-FEB-93 AM~-AA 724 ECS-KC 2320 SGB-K 50 SGC-SA 60 CMC-H& 2190 CNC-A6 2168 GSR-J 1~1.5 PGD-G 1815 ~SC-E 775 DRS-C 4950 POH-L ]765 OLH-CS 2748 OLC-D 76! OLS-F 975 SRE-F 776 SR$-D 947 38?0 1.0732.0 2% KCL SYSTEM 9,40 44,00 0,50 6.30 O.195 70.0 0.157 67.0 $.chlumber.~er Alaska Computln¢ Center 9-~AR-!99] !3:21 FIbTRATE AT CA, K .F AT CAKE AT fiN) 0,3 5 9 70.0 THERMal., SANDSTONE 2.65 'raol~,ST~: ~SFI,,,-Db~,-bDT'.CN[~,-GR-,TCC-AMS-,0R IDLE-SP-HEAD. , , ~N THE DL5 AMS. A?~D RIGID R~N ! 3" TEFbD~~ STANDOFFS F'7 , BRIDLE. RAN 2 ROI, LOVE~ SLEEvEs TO HELP 'TUR~ THE bDT APeD ~SFb PADS. DR'IbLING ~UD HAO 24,000 PP~ CR, bORIDES. CML !~%ATRIX = SANDSTf]NE, D~C = NONE, ADCW = 2.65 G/CC. MC = bDT CALIPER, FD = 1,0 G/CC GOGG_,D GR OMbY IN CASING FRON 9'5/8" CASING BOTTOM TO THE $[iRFAC~ CASING. ~E PAG ..... : 2O .... 'C. .qM RECORD ** ** DATA VOR~,~AT SPE !FICAT!~ ..... ** SET TYPE - 64gB ** TYPE REPR CODE V~bUg I 6 6 0 2 66 0 3 73 220 4 66 5 66 6 73 7 65 8 68 0,5 9 65 FT 1! 66 4 12 68 1.3 66 I4 65 FT 15 ~6 16 66 1 0 66 ~mmmmmmmmmm#mm{mm~mmmmmmmmmmmm LIS T~De Verification L!stlnq $cbtumberoer Al, asKs ComDutinq Center NA. SENV w SER'?IC~I APl A~.I AP1 API F .~ M[JM~ SI ID ~OER ~ hOG TYPE CL.ASS '~OD 6U~B S~MP ELEM CODE (HEX) ooo oo o ...... 'i" ....... .... ooo'"gg'"'"'ooooo LbS DLB 0 H ~4 ~-~ 590363 O0 000 O0 0 4 1 I 4 68 0~00000000 bED DbR OHa~ 599]63 00 000 00 0 q 1 I 4 CALl D~R lin 59q363 00 000 00 0 4 1 1 4 ~!.. L1. D[.,R IN 599363 00 000 00 0 t 1 ! 4 SP DhP aV 599363 00 000 00 0 4 I 1 4 a~ Dg~ GtPI 599363 O0 O00 O0 0 4 1 I 4 TEaS DDR BM 599363 00 000 00 O 4 1 1 4 MTE~ DL~ DEGF 599363 00 000 O0 0 4 1 I 4 MRMM DLR OHMM 599363 00 000 00 0 4 1 1 4 HTEU DI,,R bB 599]83 O0 000 00 0 4 1 1 4 ~8FL ~L~ OH~M 599363 00 O00 00 0 ~ ! ! 4 S~!N Dba Oaaa 599363 oo 000 00 o 4 l, I. 4 ¢~uo Di, R OHM~ 599363 00 0O0 O0 0 4 1 ! 4 [)Pa! [,D~ PU 599363 00 000 00 0 4 1 I 4 RaOg [,DR G/C3 599363 00 O00 00 0 4 1 1 4 DRHO LD~ G/C3 599363 00 000 00 0 ! ! I 4 PMF LDR 599363 O0 000 O0 0 4 1 I 4 O[,S I,D~ 599363 O0 000 O0 0 4 1 I 4 OSS LD~ 599363 00 000 00 O 4 1 1 4 LS BDR CPS 599363 O0 000 00 O 4 1 1 4 ~U LDR CPS 599363 00 0o0 00 0 4 1 1 4 bL LDR CPS 599363 00 000 00 0 4 I I 4 L!TH I,DR CPS 590363 O0 OOO O0 0 4 1 I 4 SS1 LDR CPS 599363 O0 OOO O0 0 4 1 I 4 SS2 LD~ CPS 599363 O0 000 O0 0 4 l. 1 4 [,MMV LDR V 599363 O0 000 O0 0 4 1 i 4 SSHV LD~ V ~99363 O0 000 O0 0 4 ~ 1 4 SI~H LDR G/C3 599363 O0 000 O0 0 4 1 1 4 LSRH [.,OR G/C3 599363 O0 000 O0 0 4 1 I 4 LU~H LO~ G/C3 599363 O0 000 O0 0 ~ 1 1 4 CAL! [,DR IN 599363 00 000 O0 0 4 1 1 4 CAI,! LDR IN 59q363 O0 000 O0 O 4 1 ~ 4 G~ LDR GAPI 599363 O0 OOO O0 0 4 1 1 4 TFNS LDR LB 599363 O0 000 O0 0 ~ 1 1 4 HTE" bDR DEGF 599]63 O0 000 O0 0 ~ 1 1 4 ~R~g LDR OH~~ 599363 00 000 0O 0 4 1 1 4 hW~ [,OR b~ 599363 00 000 nO 0 4 1 1 4 ~iPHT CNR PI.! 599363 00 O00 00 0 4 1 1 4 R?~ CN~ 599]63 O0 000 O0 0 4 I I 4 TM¢~ Ca~ pll 599363 O0 OOO 00 0 4 1 ~ 4 TNRI C~R 59936~ 60 000 O0 0 4 1 1 4 NPO~ CNR PU 599363 00 000 00 0 4 1 1 4 RCNT CaP CPS 599363 O0 000 0O 0 ~ ! 1 4 RCF? CNR CPS 599363 O0 000 00 0 4 I ! 4 CNTC CN~ CPS 599363 0o 000 00 0 4 1 1 4 CFTC CNR CPS 599363 00 000 00 0 a 1 1 4 Gp CNR GAP! 599]63 0O 000 00 0 4 1 I 4 CAbT C~]R IN 599]63 O0 000 00 O 4 1 I 4 68 68 68 6~ 6~ 68 6~ 68 6~ 6~ 68 68 68 68 68 68 68 6~ 0000000000 0000000000 0000000000 0000000000 0000000000 000000o000 0000000000 0000000000 0000000000 oo000o0000 0000000000 0o00000000 0000000000 0000000000 o000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0o00000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 00000o0000 00o0000000 o000000000 000o000000 o000000000 0000000000 OOO0000oo0 0o00000000 000000oo00 oo000o0000 0000000000 0000000000 0o00000000 o0o0000o0o 000000o000 0000000000 o00oo00o00 o0000000o0 nOoooooooo 0000o000o0 !--.IS Ta~e Ver,,t,.f,',icatlon b;[stin~ Sch!~mber~er AlasKa Comput~nq Cemter PAGE: .22 ~) O~D~'~ # LOG · +y - · ............. PR ..oS HOD ~!!~ S~P ~.~..~,~,~ CODE (HEX) C~h~ CN'~ IN 599:'6.3 nO 000 O0 0 4 I I 4 68 OOO0000000 TENS C~R L'B 599363 O0 000 OD 0 4 I I 4 68 0000000000 ~.?~Y C~R DEGV 599363 O0 000 O0 0 4 1 ! 4 68 0000000000 D~P'r. li2~{7,000 .[,LS. ~r.,,R 7. P,,47 LL0.DLR 5.847 CA[~S'DbR C.~LI.DLR 8.4.]5 CALl. LR ~,365 SP DLR -20 O00 G~ DLR TENS,. . DLR .4195.000 ...... ~TE~. DLR 1.59. 049 ~R~[~.DLR""' ' 0.O67' HTEN.DLR' " NSFL.DLR 7,0~8 S~I N. D[.,R 0.3~, SMNQ.DLR 0.486 DPHI.LDR R~('}~. LDR 2'446 DRHO,LDR 0.220 PEF'LOR 15.~95 OLS.LDR LITH.L~ROSS'LDR !49~.560042 LS.[,DR 471.421 '"LU'LD~ 431.~38. LL. SS~.LDR ]33.346 SS2.LDR 440,664 LSHV'.LDR SSH~.LDR ~215.5~5 S1RH.LDR 1.840 LSR~.LDR 2.226 C~ !,,~ .LDR 8.435 CA. L1, LD[~ ~.365 GR,LDR 13l,.437 TENS.LDR ~ T~;~.~'. [,,DR 159.049 ~R ES. [,,,DR 0.067 HTEAi. LDR 36~ ~12 NPH!.CNR RTN~.C~tR 3.000 TN'PH.CNR 30939 TNRh. CNR ~. 9~ RCNT.CNR 22~3.5~0 RCFT.CNR 732:386 CNTC, CS~R 21 4~:42.2 CFTC.CNR 6R.CNR ~31,437 CALi.CNR ~.435 CALS,CNR ' 575 TENS.CNR ~!RES' CNR 0,067 MT~W,, CNR !59,040 HTEN,CNR 362'7~2 ' DFPT. 11.200.000 LL$.DLR 7.905 L[.,D.DLR 5 991 CALS DPR C~LT.DLR ' !1.435 CALl. DI.,,R 8.~23 SP.DLR -20:000 GR:DLR T~NS.DL~ 65~5.000 ~':rE~l. D I,R 159.040 ~RES.DI,R 0.067 HTE.N. DI,,,R MSFL.DLR ~'0.911 SMI~.DLR 0.3~2 SNNO.Di, R 0.620 DPHI.LDR RHOg. LDR 2.446 DRHO.LDR 0.220 PEF.LDR 2.718 OLS.LDR 0S,g.[ DR 0.042 LS.LDR 47~.421 LU.LDR 431.138 LL.LDR LT T}{. [.,r)~ I49.156 SSI.LDR 333.346 SS2.LDR 440.664 LSHV.LDR SSHU.LDR 12i5.5~5 SlRH.LDR I..840 LSRH.LOR 2.~26 LU~H.LDR ALI.[,~R '~.435 CALI.LDR ~.123 G~.LDR 131.437 TENS.LDR ~TE~. I.,OR ~59.049 ~.~RES. LDR 0.067 HTE~. LDR 1306.424 NPHI.CNR RTc~R.CNR 3.000 TNPH.CNR 30.939 TMRA.CNR 2.79] NPOR.CNR RCN T. C~'~ R 2223.54o ~C~T.CtiR 732.386 CNTC.CNR 2143.422 CFTC.CNR G~.C~R 1~1.437 C~Li CN[{ ' 8.435 CALS.CNR 8.421 TENS.CNR M~E.g. Cfu R 0.067 MTEM:C~9 159.640 HTEN.CNR ~ 306.424 D.?.Pq'. 11.!00.000 bLS.DIoR 5.284 I..,LD. OLR .4.073 CALS.DLR C./%LT. nLR 8.526 ChL1.D~,R 8,!44 SP.DLR -20.750 GR.DL~ ~:~<S. DLR 5975.000 ~TE~. DI"R 158.~97 M~ES. O[,.,g 0.067 HTEN.DLR USFL.DLR 4.945 S ~-~ T ~. [.)L ~< 0'179 SM~O. D[,R 0.092 DPHI.LDR [~Og. l.,OP ~.377 DRMO.LD~ 0.!65 P~V.LDR 5.355 OLS.LDR DSS. ~,r')R 0.132 LS.LDR 470.343 L{]. LD~ 44~.6~] I.,L. LDR LT'F~. LL)R 97.3~4 SS1 .LD!{ 318.62] SS2.bDR 382.585 LSHV.LD¢ S5gV.LDP 12~6.744 StPN.LDR 1.996 bSRH.LDR 2.212 LURH.LDR CAL!.LDR 8.525 C~bl.bOR ~.144 ' GR. LDR 116.224 TENS.LDR ~T~;U · !.,DR 158.907 M~S.LDR 0.067 HT~N.LDR 1293. 381.3 ~JPHI.CNR R~ ~ ·CS:~R 2.852 T>~DH. CN R 3~ .6~9 T~R.[. CNR 2.778 NPDR.CN~ 8.575 !31.437 362.712 12.384 255.852 !156.257 419 000 30.889 30,939 779,347 ,4195.000 8.421 1306"424 12.384 0.011 255,852 1~56.257 2.241 6545.000 30.889 30.939 779.347 6545.000 8.412 116.224 !293.380 16.561 -0.031 249.002 1160.200 2.225 5975.000 ]0.549 32.044 5!$ Taee veriffcatlon Listlna Schlu. mberQer Alaska Computin0 Center RCNv.CMp 2080.665 RCFT.C~{R GR CNR !2.6.224 MR~$;CMR O. 067 D~PT. { 1000. 000 bLS. t)LR CA[,I. DLR 8.701 CAL!.DLR TEN$.DLR 5620.000 ~SFL. DLR 4.679 S~!N. DLR RgO~.LDR 2.375 DRHO.LDR OSS. L[)R 0.0.49 !,$. LDR LITH. LD~ 79. 662 5S I. LDR SSHV.LDR 1218.442 S1Ri~.LDR CALI.[,DR 8'70! CALl, .LDR ~TEu LOR 160.427 ~T~J~ ~ CNR 2,609 RCNT.CNR ~4~1 -016 RCFT. CMR G~.CNR 40.486 CALI.CMR DEPT". 10900. 000 bLS. DLR C~.[,!.DbR 8.46! CALi.DLR T~N.~, DLR 5365.000 ~TE~.DLR RHO~,.LD~ 2.209 DRHO.LDR OSS. LDR 0. 079 LS. LDR LITW. LDR 1 31.319 SSl.b~R SS~U,[,D~ I21.8,9~6 SI~H,LDR C.~LI.LD~ 8.461 CAL1.LDR ,~TE~.LD~ 160.116 ,~RES. LDR RTNR.CMR 3.011 TNPh. CNR RCNT.CNR ~302.208 RCF=~f. C~jR GP.CNR 29.832 CALI.CMR ~'4RES. CNR 0.066 DF. PT. ! 0~00,000 LLS. DI.,R C~LI'.OLR 8,5~2 CAL1.DLR MSFL.DLR 2,429 S'4IN, O.LR RgO.g. LDR 2.186 ORHO.LDR OS.q. LD~ O. 053 l.,S. bDR LITH.LDR 1~7.~93 SSI .LDR SSHV. Ll)~ 1220.062 Ca L~ · [...DR 8.582 CALl .LDR MTE~,LOR 158,964 ~RES. LDR RT~]P, C~; R 2,91.0 T~Pg.C~R RC~:~T.CNR 2068,301 RCFT.C~JR Gm.CNR 30.5]7 CALI. C~g!~ ~f]g.CNP 0,667 MTE~4. C~]R 9-~A~-1993 !3:21 692.574 CMTC.CMR 8.526 CALS,C~R 158.8§7 HTEN,CMR ~.730 LLD.DLR 7.955 !60.427 0.401 8MNO.DLR 0.036 DEF.LDR 264'0~3 SS2-LDR 2.~43 LSRH.LDR 7,955 GR~LDR ¢) ~6:6 HTE~i' .... .b.R 25:37 T~RA,Ct~R 954,560 CNTCoC~R a.~Ol 160,427 HTE~oC~R 2.665 LLD.DLR ~.063 SP'DbR 160.116 MRES.OLR 0.556 SMNO.DLR o lo9 ~EF,r, oR 5~0~772 LU,LDR ]07.020 SS2.LDR 1.~78 LSRH,LDR 8,063 GR.LOR 0 066 HTEN. 31~584 726.841 CNTC,CNR 8.46~ CALS.CNR 3.171 bLO.DLR 8.024 SP.OLR !58.964 ~RE$.OLR 0.277 0.014 PEF.LDR 511.~68 LU.LDR 268.97~ SS2.LDR 2.115 LSRH,LDR 8,024 GR,LDR 0.067 29,72~ TNRA.CMR 701.388 CMTC,CNR 8.582 CALS.CMR 158.964 ~TEM,C~R 2023.882 ~,412 1293.380 8,772 -29.625 0.066 0.547 4'982 353.488 348.525 2.339 ~0.486 1197.478 2.416 2454.556 8.381 1197.47~ 2'141 0'066 0.578 4.71.8 404,461. 2.1oo 29.832 1217'026 2.784 2195.412 8.462 1217.026 3.494 -49.688 0.067 0.225 3.985 471.589 365.733 2.172 30.537 1334.~64 2.850 2075.689 8.447 1334.864 r)Ep,. 10701.00C) bLS.!)LR 0.140 LLO.DL~ 0.090 C/~LI.DL~ 8 670 CA[,1.DLR 9.751 S~ r, LR 46.438 TE,~'~. DLR 5605.000 ~'~ TE ~. OI..~R 155.666 URES.OLR 0.068 ~48FL. DL, R -999.250 8~4 I~. f)LR -99g.250 S~O DLR -990.250 PNO~.LDR I .966 DRNO. [,,OR -0.757 PEF:LDR 25.O14 OSK. I, DR -0. 062 I.,S. LOR 194.663 LU. [,DR 194. 596 CFTC CN~ CAbS,DLR GR.DLR MTEM.DLR DPHI.LDR OLS,LDR bL.LDR LSMV,bOR LURH,LDR TENS.LDR NPHI.CNR NPOR.CNR CFTC.CMR CAL$.DLR HTEN.DLR DPHI.LOR OhS.LDR LL,LDR LSHV,LD~ LURM,LD~ TENS.LOR NPMI,CNR CFTC,CNR TE~S,CMR CAI,S.DLR GR.DbR HTEN,DLR DPBI,LDR OLS.LDR LL,LDR bSMV,LDR LURH,LOR TE~!S.LDR NPHI.CNR NPOR.CNR CFTC.CNR CALS.DLR G~.DLR HTEN.DbR DPHI.LD~ OL$.LDR LL,LDR PAGE; 722.8!6 5975.000 8 ~8! 40~ 86 1197.478 16.652 -0.013 198.606 1162.088 2,357 5620.000 24'913 26,534 1017.281 5620,000 8.462 29.832 12~.7.026 26.717 '0 038 3092916 1163.113 2.112 5365.0O0 30,7!8 31.164 786'3!6 5365.000 8.447 30.537 1334.864 28.102 -0.016 276.073 1164.212 2.190 5735.000 31.560 31.258 775.950 5735.000 9.014 102.651 1330.153 41.454 0.002 97.365 23 LIS Tane verification Listin~ Schlumberger ~%laska Cou~D!.]tinQ Canter 9-NAR-!Dg3 !3:2! 4 LITM. bDR 20.511 SSi .LDR SS~!¥.LDR !222.0a3 SIP~H.LDR CALl .LD~ 8,670 CAbl.LDR ~TE~. L.O} 155,666 MaEs.. LDR RT~P.CN~ 4,515 T~qPH,CNR RC~'~T. Cb~R !3!0,748 ~CFT.CNR GP.CMR 102,651. C.ALI,CNR 8,751 GR.LDR 0,068 MTEN.LDR 61,019 TNRA.CNR ~84,034 CNTC,CNR 8.670 CAbS,CNa !55,666 HTEN.CMR 1.22.512 2.723 LU~.LD~ t02.651, 1330.~53 NP~I.C~ 4,505 NPO~.CN~ 1281.6~0 CFTC.CMR 9.014 1330.153 116~.763 5605 .773 .000 61.354 62,932 295,919 5605.000 F,?L~ NA.~E ~' EDIT .004 SFRVICE : FLIC VERSION : 00!107 D.ITE ~ 93/03/ 9 ~ilX ~C SIZ~ : t024 L~.ST FILE F'!L~ ~tANE : EDIT .005 SERVICE : FL!C VKR$IOM : 0Ola07 i)AT~ : 93/03/ 9 N~l R~C SIZE : 102.t FIL~ TYPE : bO baST ~I[,E : FILF ~4EADER FIL~ NUMBER 5 R~W CASED },'.,'O[,E MAIN PASS Curves and ldo header data ~or open hole logs run into casing. TOOT, STRING ~U~'~BER: 3 D~P~i I.~,iCR E~EMT: -.5000 ................. .... TIM~ CTRCt!!,A'I'IO>~ EM[)ED~ STOP DEPTM Oq-FEa-93 5CO-423 1130 09-FEB-93 LIS TaPe Verification LIstJ, nc~ 'Schlumberger AlasKa ComDutlnG Center 9-~AR-!993 i3:21 PAGE: ~5 TD OR!LLER (FT): TOP bOG INTERVAL ~OTT0~ LOG INTERVAL (FT}: bOGGING SPEED (FPHR): TOOL STRING (TOP TO BOTTO~) VE~}DOR TOOL CODE TOOL TYPE A~ AL{XILLIARY ~EA SUR~ME~,~T ECH TELEMETRY CARTRIDGE GR GA ?~1 ~ A RAY GR GA ~4A RAY C~TH COMPENSATED CNTM COMPENSATED LDTD G~M~A RAY SOURCE LDTD POWERED GR DETECTOR LDTD }'..)UCLE~R 8MRVIC~ CART. LDTD LDTD LDTD D~NSiTY RESISTIVITY LDTD POWERED GR HOUSI[~G D!,L DUAL LATEROI.,OG HOUSING DLL DUAL LATEROLOG CART, DL[,, DUAL LATERObOG SOND~ DLL DUAL LATEROLOG DLL DUAL LATE~OLOG ~ODEHOLE AMD CASING DATA OPEN HOLE BIT SIZE DRILLERS CASING DEPTH LOGGERS CASING DEPTH mOPEHObE CONDITIONS ~UO TYPE: DENSITY VISCOSITY PH: FLUID bOSS (C3): NAXI~U~ RECORDED TE4PERAmURE (DEGF) RESISTIVITY (OH~) AT TEMPERATURE MHD A? MEASURED TEMPERATURE ~UD AT BOTTO~ HOLE TEMPERATURE ~ijn FILTRATE AT fMT): WIjD FILTRATE AT (BHT): MUD CAKE AT ~!jD CAKE AT (BHT): NEUTRON TOOL TOOL TYPE (KPITHER~iAb OR THERMAL): MATRIX: HOLE CORRECTIO;~ (IN): 1!20 0 3950.0 1~,200.o 1800,0 TOOL NUMBER ECS-KC 2320 SGH-K 50 SGC-$A 6O CNC-HA 2~90 CMC-AB 2!68 GSR-J 18~5 PGD-G 18!5 NSC-E 775 ECH-MKA 781 PDM-L ~765 Db~-CS 27~8 DLC-D 761 SRE-F 776 SRS-D 847 8,500 I07]~,0 !073..,0 2% KCL SYSTE~ 9,40 44.00 9,50 0.195 70.0 0.157 67.0 0.359 70.0 SAi~.~DSTONE 2.65 LIS Tame Verification I, isttnq Schlumberger Alaska Computing Center 9-~AR-!.993 !3:2! ~E!.~ARKS: T[]OLSTRING: MSF[,-OLL-LDT-CN L-GR~TCC-AMS-BRIOhE-SP-HEAD. RAN 1,3" TEFLO~ STANDOFFS ON Td.E DLb, A~S, AND RIGID B~IDLK, R~N 2 ROL[,,C~VF~R SLEEVKS T(,} HEbP TURN TF~E LDT AND ~SFL PADS, ~RILblNG .NUD H,AD 24,000 PP~q CHbOR~DES. CNL ~.AT~IX : SANDSTONE~ DHC : N~NE,~'~qDEN : 2.65 G/CC. HC = LDT CALIPER, FD = 1.0 G/CC. ~" ' po~' LOGGED GR ONLY !N CASIMG F~O~ 9 5/8" CASI.~G ~..~.tTO~ T(I T~qE SURg"ACE CASING. LIS FORMAT DAT~ PAGE: 26 DATA FORMAT SPECIFICATION ~EC[)~D ** SET TYPE - 64gB ** TYP~ REPR CODE ! 66 0 2 66 0 4 66 5 66 6 7 65 8 68 0,5 9 65 FT 1! 66 42 12 68 14 65 FT 16 66 0 66 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmm ** SET TYPE - CHAN ** ' ~ ............ 7~'~ .... '''?:r''rr:'':::'':%:~~,,~~ ....... ~ ..... ' ..... ::::::::::::::::::::::: lO ORDER # bOG TYPE CLASS ~OD NUMB SAMP ELE~ C~DE fHEX) DFPT FT 599363 O0 OOn O0 0 5 ! I 4 6~ 0000000000 G~ CSG GAP! 599~63 O0 OCO O0 0 5 1 1 4 68 0000000000 TFN$ CSC L~ 590363 O0 000 O0 0 $ 1 1 4 68 0000000000 MPE$ CSG OBM~ 599363 O0 009 O0 0 5 1 I 4 68 0000000000 gTE~ CSG DEGF 599363 O0 000 O0 0 5 1 1 4 68 0000000000 ~TE~! CSG LB 599363 00 000 00 0 5 1 I 4 68 0000000000 LLO'O LLO'O LLO"O 9/.0"0 §LO'O ~/.,0' 0 ~/.,0 "0 ~'LO'O ~/,.0'0 ~£0'0 ~LO'O g£O'O t~O '0 ~tO'O '~0'0 0£0'0 0£0'0 oo0'g6~ oO0'g9~ O00'~q[~ O00'O[DP 000'089~ 000'~88~ O00'fi08~ OoO'~LL~ O00'SL6~ 000'~0~ O00'Ot[~ O00'l£~S 000'~6[§ O00'~L[~ 000'§~ 000'~0£ O00'S~6I 8~L'66'[I D~D'SNa& Lt['OL D~D'SN~£ £L9 DDD°~NM$ ~ 86 L~'6f~ D~D'SN3i 86§'E6 6~O'O~g~ 99~'008 DSD'~N3£ ~[['OL DSO'MD 000'00~6 9SO'a9 000'00~o DSO'ND O00'OOLo D~D'HD o00'0086 DSO ~D 000'0066 DSD'NM£H lO0'Lv[ D~D°HD 000'0000I D~D"N3&H 8L§'L~'[ D~D'~D 000' (:)OEO 1 D~D'aD 000 OO['OI DSO'~ OOO'O0~ol D~D'M9 O00'O0§OI :,~3"a~) 000'0090:'[ ,.)$~ 8D O0'OOLOi DgD'~D O0~'[OLOl §80'0 ~80'0 e80'O ~0'0 £80'0 gSO'O gSO'O ~80'0 t80'0 IBO'O t80'0 080'0 080'0 6£0'0 6LO'O 8&O'O 8LO'O 8LO'O o0o'oL8£ ooo'g60~ ooo'oLo~ o0o'o~o~ O0O'OOg~ o00'0~ O00'Olg~ O00'OL/~ O00'Oig~ 000'0~ 000'0~ 000'00~ 000'06~ 000'~6£~ oO0'~i~ 000'089~ 000'0~9~ 669 ' Iq ~ I DWD'SN3£ D~D'SN3~ g60'~L['[ 8L§'98'[I D~D°~NM£ LlS°g~ LSO'L6[t D~D'SN3~ g60'99 D~O'SN3i SEL'E~ D~D' ~D 000' O0~L DRD' ~D oO0' O09L DRD'N3iH 889'ggI DRD' aD 000' OOLL DSD' aD 000' OOBL DgO' ~D 000' O06L DWD'MD 000 0008 DSD'Ni~H ~Oq' SE t 9sO'a~ soo'sola ,,..] ~ .:, ,.SO 89 000 00~8 f)RD ~iD 000 0088 9~0 ";~D 0oo ' 0068 mSD"aD 000' 0006 DSD'~3AH qO'I'BCl 990' aD GO0' 00'[6 £60'0 960'0 ~60'0 ~60'0 g60°O 060'0 060'0 680'0 8~0'0 LSO'O L80*O LSO'O 980'0 980'0 980'0 ~80'0 ~80'0 oOo'gg£E 000'0~[ 000'g£9£ 000'~69~ 000'0S9£ O00'~LE O00'~LLE 000'~L8£ 000'068[ 000'~98£ 000'096£ DSD'gNHi '~qL'L£ L~O'L~[I D~D'~N~£ L96'9~ DgD'gN~ 9~D'SN~£ ~08'8~ 6C6'EL['[ DSD'~N3Z [89'8~ DSD' ~D 000' OOLS DSD' aD 000' Ot)6S 9S'D'~D 000' 006~ DSD'89 000'0009 DSD'aD 0o0' O0 DSD'aD 000' 00~9 D83 ' 8Q O00 ' DgD'~D 000' 0089 D W D ' ~ ........ 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