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201-044
Image~oject Well History File Cover I:~e XHVZE This .page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. RESCAN DIGITAL DATA OVERSIZED (Scannable) [] Color items: [] Diskettes, No. [] Maps: [] Grayscale items: [] Other, No/Type [] Other items scannable by large scanner [] Poor Quality Originals: [] Other: OVERSIZED (Non-Scannable) NOTES: [3 Logs of various kinds [3 Other Project Proofing BY: E~EVERLY ROBIN VINCENT SHERYL ,~WINDY DATE;7~/~)~.~ /SI ~7~ ScanningPreparatio. __~ x 30: ~ +~_: TOTALPAGES BY: BEVERLY ROBIN VINCENT SHERYL~WINDY DATE: '~/~{~S/ Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION: ..~ YES ~ NO Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES ....... NO (SCANNING IS coMPLEI'E AT'rillS POINT UNLESS 81~ECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAySCALE OR COLOR IMAGES) RESCANNEDB¥: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /$/ General Notes or Comments about this file: Quality Checked 12110102Rev3NOTScanned,wpd • STATE OF ALASKA • �/�� ALASKA OIL AND GAS CONSERVATION COMMISSION 1a.WeIlStatus: WELL C OR ETIO LOG 20AAC 25.105 20AAC 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: September 18, 2012 201 - 044 / 312 - 253 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 March 8, 2001 50 029 - 23006 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 2152' FSL, 2574' FEL, Sec. 35, T11N, R10E, UM March 23, 2001 1J Top of Productive Horizon: 8. KB (ft above MSL): 29.6' RKB 15. Field /Pool(s): 1943' FNL, 683' FWL, Sec. 26, T11N, R10E, UM GL (ft above MSL): 77' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1724' FNL, 624' FWL, Sec. 26, T11N, R10E, UM 9609' MD / 6227' TVD Kupuruk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 558635 y 5945963 Zone 4 9850' MD / 6350' TVD ADL 25661 TPI: x- 556554 y - 5952414 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 556493 y 5952632 Zone 4 nipple @ 524' MD / 523' TVD 471 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1602' MD / 1547' TVD 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 none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 16" 62.58# H-40 35' 115' 35' 115' 24" 460 sx AS I 9.625" 36# J -55 35' 5639' 35' 3949' 12.25" 653 sx AS Lite, 340 sx LiteCRETE 7" 26# L -80 32' 9198' 32' 6011' 8.5" 184 sx Class G 3.5" 9.3# L -80 8981' 9807' 5893' 6328' 6.125" 196 sx Class G 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET (MD/TVD) 3.5" 9027' 8988' MD / 5897' TVD perfs cemented off RE-E1,; 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. U 0 2 Zf Was hydraulic fracturing used during completion? Yes El No 0 NOV Y 2 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED AOGCC 9609' - 9739' 7 bbls 15.8 Class G 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period - > Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No Q Sidewall Cores Acquired? Yes ❑ No 0 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 25.071. NONE R8DMS NOV 02 2012 ' 4441,43 2 0 lit' . Form 10 -407 Revised 10/2012 CONTINUED ON REVERSE 0,... f Submit original only �^± �� 11 1 l' " .0°° 4 G 29. GEOLOGIC MARKERS (List all formations and mill encountered): 30. FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1602' 1547' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and corre the best of my knowledge. Contact: K. Starck @ 263 -4093 Email: Kai.Starck@conocophillips.com Printed Name Lamar Gantt CTD Supervisor Signature keLlytkeluk r 1 " ,YJUU f Phone 263 -4021 Date / //CO / 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 la: 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 elevations 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 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: 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 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 i KUP . 1J -09 ConwtoPhilli I Well Attributes Max Angle & MD TD A'd` a • Inc Wellbore API /UWI Field Name Well Status Incl ( °) MD (ftKB) Act Btm (ftKB) 500292300600 KUPARUK RIVER UNIT PROD 59.31 9,521.69 9,850.0 ""`" Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date "' SSSV: NIPPLE 80 9/25/2011 Last WO: 38.05 3/27/2001 Well Confi9: -1 J-09, 9/15/2012 11:09:11 AM Schematic - Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 9,686.0 7/8/2012 Rev Reason: ADD CEMENT, SET PLUG ninam 9/15/2012 HANGER 30 f Casing Strings Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd II - P CONDUCTOR 16 15.250 35.4 115.0 115.0 65.00 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd SURFACE 95/8 8.921 35.3 5,639.0 3,948.9 36.00 J -55 BTC -MOD - - + - - - - - Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 32.2 9,197.7 6,011.3 26.00 L -80 BTC -MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String .. String Top Thrd LINER 31/2 2.992 8,981.0 9,807.1 6,328.0 9.30 L - 80 SLHT CONDUCTOR, t 35-115 Liner Details Top Depth 111 k¢ (TVD) Top Ind Nomi... ' Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) NIPPLE, 524 ,,. 8,981.0 5,892.7 55.40 TIE BACK TIE BACK SLEEVE 5.250 Ilk 8,988.3 5,896.9 55.48 PACKER BAKER ZXP TOP PACKER 4.438 8,995.0 5,900.7 55.56 HANGER BAKER FLEX -LOCK LINER HANGER 425.... _.. 9,007.8 5,908.0 55.72 SBE BAKER 80-40 SBE ' 4.000 GAS LIFT, 2,922 .." 9,066.6 5,941.0 57.60 NIPPLE XN NIPPLE w/ 2.75 NO GO 2.750 glil Tubing Strings Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd 11♦ TUBING 31/2 2.992 29.6 9,026.5 5,919.5 9.30 L -80 EUE8RDMOD GAS LIFT, 5,088 Completion Details l Top Depth (TVD) Top Inc! Nomi... Top (ftKB) (ftKB) fl Item Description Comment ID (in) 29.6 29.6 1.20 HANGER FMC GEN V TUBING HANGER 3.500 523.5 522.9 6.23 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.875 t 8,945.1 5,872.3 54.98 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.812 SURFACE, 355,639 8,988.5 5,897.0 55.49 LOCATOR BAKER NO GO LOCATOR 3.000 8,989.8 5,897.7 55.50 SEAL ASSY 'BAKER GBH -22 SEAL ASSEMBLYw /MULE SHOE 1 3.000 GAS LIFT. - Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 6,858 Top Depth (TVD) Top Intl ® Top (ftKB) (ftKB) ( °) Description Comment Run Date ID (in) 8,945 5,872.3 54.98 PLUG '2.81" CA-2 PLUG 9/13/2012 0.000 GAS LIFT, 9,549 6,195.9 59.27 CEMENT LAY IN CEMENT FROM 9596' TO 9550' CTMD, TAG TOC 9/6/2012 0.000 8.067 @ 9607 RKB, 9549 SLM I 9,609 6,226.6 59.17 WHIPSTOCK MONOBORE WHIPSTOCK (OAL= 10.5') 8/23/2012 0.000 III ME Perforations & Slots Shot Top TVD Btnl TVD Dens GAS LIFT T t P I i (TVD) ® Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date loft - Type Comment 9,590 9,599 6,216.9 6,221.5 C -4, 1J -09 8/22/2012 6.0 IPERF 7'x9' gun, 60 deg phasing, big hole ® dre charges NIPPLE, 8,945 ' 9,604 9,629 6,224.0 6,236.3 C-4, 1J -09 3/27/2011 6.0 RPERF 2.5" gun, Alt. DP, 60 deg. ph PLUG, 8,945 9,620 9,650 6,231.6 6,247.3 C4, C3, C2, 6/7/2001 6.0 IPERF 2.5" gun, Alt. DP, 60 deg. ph 1J-09 9,650 9,676 6,247.3 6,260.8 C3, C2, C1, 3/27/2011 6.0 RPERF 2.5" gun, Alt. DP, 60 deg. ph 1J -09 4tmulations & Treatments L r, Bottom r- Min Top M B tm Top Depth Depth LOCATOR, ;s.= Depth Depth (TVD) (TVD) 8,989 (ftKB) (ft013) (ftKB) (ftKB) Type Date Comment i 9,620.0 9,650.0 6,231.6 6,247.3 C SAND -RAC 6/13/2001 113M# poppant behind pipe, 9.2 ppa on Perfs SEAL ASSY, S Notes: General & Safety 8.990 "r" End Date Annotation 9/28/2010 NOTE: View Schematic w/ Alaska Schematic9.0 10/11/2011 NOTE: STRIPPED FISH NECK ON OV @ 6858'. IL PRODUCTION A ■ 32 -9,198 , CEMENT, 9,549 IPERF, 9,590-9,599 N CEMENT, 9,550 i Mandrel Details Top Depth Top Port WHIPSTOCK, (TVD) Intl OD Valve Latch Size TRO Run RP .60 5 ` I Stn Top (ftKB) (5108) 1 Make Model (in) Sery Type Type (in) (poi) Run Date Cont,.. 980¢g629\ 1 2922.3 2,405.8 53.42 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/14/2012 IPERF, 2 5,087.7 3,627.3 54.32 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 8/142012 9,820 -9,850 C SAND F98 \ 3 6,858.2 4,657.1 54.55 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 6/18/2001 See note RPERF, 9,6509,676 4 8,067.3 5,362.5 53.99 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/12/2011 5 8,893.2 5,842.2 54.36 CAMCO MMG 1 12 GAS LIFT DMY RK 0.000 0.0 6/1/2001 1 1 LINER, 8,9819,807 TO (I J-09), 9,850 1J -09 Pre Rig Well Work Summary • DATE SUMMARY • • 7/7/12 PULLED UPPER 3 1/2" ER PACKER AND PATCH ASS'Y FROM 6843' RKB. PULLED LOWER 3 1/2" ER PACKER FROM_6873' RKB. IN PROGRESS. 7/8/12 TAGGED @ 9686' SLM, EST. 41' OF RATHOLE. CLEAN DRIFT TO 9717' RKB W/ 17' x 2.62" DUMMY WHIPSTOCK. SET 2.81" XXN PLUG @ 9066' RKB. SET 2.75" AVA CATCHER @ 9033' SLM. PULLED OV FROM 5088' RKB. IN PROGRESS. 7/9/12 FINISH LOADING TBG & IA W/ DIESEL. CMIT TBG x IA TO 2600 PSI ( PASS ). SET 3/16" OV @ 5088' RKB. PULLED CATCHER AND XXN PLUG ( LOST PIECES OF PACKING ) @ 9066' RKB. RAN BRUSH AND 2.62" GAUGE RING TO 9679' SLM. READY FOR E -LINE. 7/11/12 RECORD SBHP SURVEY. INITIAL 10 MIN WHP SURVEY: PRESSURE =175 PSI, TEMP =79 DEG F 30 MIN STATION @ 9620': PRESSURE =2240 PSI, TEMP =154 DEG F 15 MIN STATION @ 9425': PRESSURE =2199 PSI, TEMP =152 DEG F FINAL 10 MIN WHP SURVEY: PRESSURE =186 PSI, TEMP =64 DEG F ATTEMPTED TO RUN CALIPER LOG, COULD NOT GET ARMS TO OPEN ALL THE WAY DUE TO SAND BUILDUP IN ARM TRACKS. TAGGED PBTD @ 9724' 7/13/12 SUCCESSFULLY LOGGED 24 -ARM CALIPER FROM 9660 FT TO 8850 FT. 8/13/12 MEASURED BHP 9620' RKB: 2398 PSI. UNABLE TO PASS HANGER w/ 2.82 CATCHER ASS'Y. IN PROGRESS. 8/14/12 SET CATCHER @ 8945' RKB, PULLED OV @ 5087' RKB, PULLED GLV @ 2922' RKB, SET DVs @ 5087' & 2922' RKB, PULLED CATCHER ASSY @ 8945' RKB, COMPLETE. 8/19/12 (PRE CTD) SV, MV, SSV PASSED DDT, SV, MV, SSV PASSED PT. 8/22/12 PERFORATED 3.5" LINER ATA DEPTH OF 9590' -9599' USING A 2 "X9' GUN LOADED 6 SPF, 60 DEG PHASING, BIG HOLE CIRCULATION CHARGES. WILL RETURN TOMORROW TO SET WHIPSTOCK. 8/23/12 RIH WITH A BAKER 3 1/2" Monobore Whipstock (2.63" O.D.) AND DPU SETTING TOOL. SET THE WHIPSTOCK AT A 349.8 D E G AA_D OF 9609' 8/29/12 PERFORMED BOTTOM HOLE PRESSURE AND TEMPERATURE SURVEY AT DEPTHS OF 9595', 9450', AND AT SURFACE. LOGGED 24 ARM MIT CALIPER ACROSS THE WHIPSTOCK FACE TO VERIFY ORIENTATION. LOG WILL BE POST PROCESSED FOR RESULTS. 9595': 2430 PSI AND 153 DEG F. 9450': 2400 AND 151.5 DEG F 9/5/12 RIH WITH MILLING BHA, DRY TAGGED NPL AT 9050 CTMD, MILLED TO 9053' CTMD, BACK REAMED ACROSS NPL, MADE TWO VERY CLEAN DRY RUNS FROM 9000' TO 9100' CTMD, F/P TBG WITH 25 BBLS WHILE POOH, JOB IN PROGRESS 9/6/12 RIH, CIRC S/D OOH, BULLHEAD 69 BBLS 100 DEG SSW FOLLOWED BY 35 BBLS S /D, PERFORM INJECTIVITY TEST .5 BPM /1 BPM (275 BASELINE WHP), TAG WS AT 9604' CTMD, PUMP 5 BBLS FW 5 BBLS 15.8# CMT, 10 BBLS 15.8# CMT WITH AGGREGATE, 5 BBLS 15.8# CMT, 5 BBLS FW, LAY IN CMT F/9596' CTMD T/9550' CTMD, CLOSE CHOKE, PERFS SEEM TO BE DRINKING THE CEMENT, UNABLE TO GET WHP ABOVE 330 PSI, PUH TO 9200' CTMD, WAIT 20 MINUTES, TRY TO APPLY WHP, UNABLE TO GET ABOVE 480 PSI, PUMP 2ND CEMENT JOB, 2 BBLS OF CMT OUT OF THE NZL AND PERFS LOCKED UP, PUH TO SAFETY (7000' CTMD), PERFORM HESITATION SQUEEZE TO FINAL WHP OF 1200 PSI AND HOLD FOR 1 HR, CONTAM CMT TO WS TRAY @ 9604' CTMD, CHASE OOH W/ SSW, F/P TBG TO 2500' RKB, READY FOR S/L TAG IN 72 HRS, JOB IN PROGRESS 9/12/12 UNABLE TO DRIFT PAST 6068' RKB WITH BRUSH ASS'Y. TAGGED @ EST. 9607' RKB WITH 2.5" BAILER. ATTEMPTED TEST TBG 1000 PSI. TBG CONSISTENTLY LOST 300 PSI / 10 MIN; IA NOT TRACKING. DRAWDOWN TBG TO ZERO; HELD SOLID 5 MIN. COMPLETE. 9/13/12 MIT IA 1000 PSI PASSED. ATTEMPTED MIT TBG, FAILED. GAUGED TBG TO 2.83" TO DS NIPPLE @ 8945' RKB. SET 2.81" CA -2 PLUG @ 8945' RKB. TESTED TBG 1000 PSI / 25 PSI, PASSED. READY FOR BPV. ` 4 • • ConocoPhi[lips Time Log & Summary WelNfew Web Reporting Report Well Name: 1J - 09 Rig Name: NABORS CDR2 - AC Job Type: DRILLING SIDETRACK Rig Accept: 9/17/2012 3:00:00 AM Rig Release: 10/3/2012 12:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 09/15/2012 24 hr summary Move rig 21:00 00:00 3.00 a MIRU MOVE MOB P Wait on Peak trucks for rig move. Doyon 25 had issues with their move so trucks were delayed until 7am 09/16/2012 Moved rig from 3N -07 to 1J -09. 00:00 09:00 9.00 0 0 MIRU MOVE MOB P Wait on Peak trucks for rig move. Doyon 25 had issues with their move so trucks were delayed until 7am 09:00 18:00 9.00 0 0 MIRU MOVE MOB P Move rig to new location. Minor trenching but clear of CPF3 bad • section of road. 18:00 00:00 6.00 0 0 MIRU MOVE MOB P PJSM with Peak,Doyon, Nabors and COP for spotting up rig to 1J -09. MIRU, NU on 1J -09. 09/17/2012 Completed NU, Performed BOP test, pumped slack management and pulled CA2 plug prong with Slickline. 00:00 03:00 3.00 0 0 MIRU MOVE NUND P Continue to rig up, Nipple up stack 03:00 04:00 1.00 0 0 MIRU WHDBO BOPE P Accepted rig @ 03:00. Start getting ready for BOP test. 04:00 07:00 3.00 0 0 MIRU WHDBO BOPE P Start BOP test @ 04:00. TEST Waived by Chuck Sheave. 07:00 15:30 8.50 0 0 MIRU WHDBO BOPE P Master Valve leaking call Valve crew to come and reservice tree. 15:30 16:30 1.00 0 0 MIRU WHDBO BOPE P PJSM - Pull BPV 16:30 17:30 1.00 0 0 MIRU WHDBO BOPE P RU to pump slack management. 17:30 19:30 2.00 0 0 SLOT WELLPF SLKL P Rig up slick line unit to pull CA2 plug. 19:30 00:00 4.50 0 0 SLOT WELLPF SLKL P Slickline completed pulling prong, working on plug body. 09/18/2012 Milled window from 9606.5'- Exit 9612'. Continue millin. formation to 9631'. Three ba kre- u' • • - - • run - clean. POOH. Mills guaged 2.79 ". Lost 27 bbls after window exit. 00:00 02:00 2.00 0 0 SLOT WELLPF SLKL P Pulled CA2 plug body with slickline- Complete. 02:00 04:30 2.50 0 0 SLOT WELLPF SLPC P Cut coil, MU coil connector and rehead. 04:30 07:30 3.00 0 0 PROD1 WHPST PULD P Rig up Milling BHA #1. 07:30 10:00 2.50 73 9,450 PROD1 WHPST TRIP P RIH 10:00 10:30 0.50 9,450 9,450 PROD1 WHPST DLOG P Tie in depth minus 7.5' correction 10:30 11:00 0.50 9,450 9,607 PROD1 WHPST TRIP P RIH Dry Tag TOWS 9606.5' Page 1 of 12 Time Logs • Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 11:00 17:00 6.00 9,607 9,611 PROD1 WHPST MILL P Start milling 1 fph, 10 LOHS, 1.75 bpm, 3239 ctp, 0 whp, 10.7 ecd, 16k ctw, 1k wob. Started losing weight, window exit. 17:00 19:30 2.50 9,611 9,619 PROD1 WHPST MILL P Continue milling - 9611.7' - Increase to 2fph. 19:30 20:00 0.50 9,619 9,628 PROD1 WHPST MILL P Stall - P/U weight 37K. pump min. rate up through window. RIH 10 LOHS 1.5 bpm, clean drift to TD 9620'. Continue milling -1.55 bpm, 2600, BHP 3380, WOB 1K, CT weight 16K, ROP 12 - increase to 50 fph, samples are 98% good clean sand, 2% light cement & Glocenite. 20:00 20:30 0.50 9,628 9,631 PROD1 WHPST MILL P Stall 9628' - P/U 10ft weight 36K. 20 -6 Continue milling. 20:30 22:00 1.50 9,631 9,620 PROD1 WHPST REAM P Start backreaming as per procedure, very light motor work. Dry drift clean 9603' - 9620' - 10 fpm. Roughly 10 bbls losses in past 4 hours. 22:00 00:00 2.00 9,620 62 PROD1 WHPST TRIP P POOH following MPD. Bump up at surface. 09/19/2012 Drill build section with 2.3+ AKO & hughes bit to TD of 9964'. Tie into RA marker. Total losses = 232 bbl/24 hours TOW = 9608' RA = 9613' BOW = 9614' 00:00 02:00 2.00 62 0 PROD1 WHPST PULD P PJSM - Undeploy BHA #1. Roughly lost 7 -9 bbls hour holding MPD. 02:00 02:30 0.50 0 0 PROD1 DRILL PULD P Make Up BHA #2 with 2.3+ AKO and Nf �W bi- center bit. Service injector. � J 02:30 03:00 0.50 0 0 PROD1 DRILL SFTY P Pre -spud meeting with Maddy's J crew. 03:00 04:45 1.75 0 62 PROD1 DRILL PULD P PJSM - Deploy BHA # 2 04:45 07:15 2.50 62 9,435 PROD1 DRILL TRIP P RIH pumping . 3bpm. 07:15 07:30 0.25 9,435 9,435 PROD1 DRILL DLOG P Tie in depth to K1 - 9.5' correction 07:30 08:00 0.50 9,600 9,631 PROD1 DRILL TRIP P Close EDC drift window with 2.3 AKO 08:00 08:30 0.50 9,600 9,600 PROD1 DRILL CIRC P Open EDC swap out milling fluid to drilling mud,. 08:30 08:36 0.10 9,600 9,631 PROD1 DRILL TRIP P Close EDC RIH to drill 08:36 08:42 0.10 9,631 9,637 PROD1 DRILL DRLG P Drill ahead 1.48 bpm, 1.35 out, 2480 ctp, 0 whp, 15k ctw, 10.7 ecd 08:42 08:57 0.25 9,637 9,600 PROD1 DRILL RGRP P PU into casing. 2 x 2 vavle SR 10 has small drip at connection. Bleed pressure and tighten. Online RBIH 08:57 11:27 2.50 9,600 9,749 PROD1 DRILL DRLG P Drill Ahead 1.4 bpm in, 1.3 out, 2545 ctp, 15k ctw, 10.7 ecd 11:27 12:42 1.25 9,749 9,756 PROD1 DRILL DRLG P Start losing .5 bpm. Drill ahead, slow ROP aciderite 12:42 13:27 0.75 9,756 9,780 PROD1 DRILL DRLG P Break thru hard formation. Returns increase. Losing .25 bpm Drill Ahead Page 2 of 12 i WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 24, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Whipstock Setting Record: 1J-09 fkA N (J ` ‘1, 7 Z Run Date: 8/23/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data (LAS), Digital Log file 1 CD Rom 50- 029 - 23006 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: l t2 Signed: AL /r_, 1 . • 2D 1-D9 • 2A1 2.5eS WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 23, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1J -09 Run Date: 8/22/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data (LAS), Digital Log file 1 CD Rom 50- 029 - 23006 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: )i\15/2-012— Signed: -` 2ot -D4 • 1:`IC ` WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. August 31, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 4L.A 44 0ED NC 11 2, Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) /Bottom Hole Presure Survey: 1J -09 Run Date: 8/29/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 23006 -00 Bottom Hole Pressure Survey Log 1 Color Log 50- 029 - 23006 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com ��� ��y Date: g 12 Signed: 1-2) J t • • F p ' r `b " h C ¢ SEAN PARNELL, GOVERNOR Y„ ti U r t `�1 ALASKA OIL AND GA.S 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 J. G. Eller a Ate V CTD Engineer ConocoPhillips Alaska, Inc. rf I 1 01+ P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1J -09 Sundry Number: 312 -253 Dear Mr. Eller: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, /74.6.4d./2 Cathy (ut F oerster Chair DATED this t day of July, 2012. Encl. .1 . STATE OF ALASKA RECEIVED _ AIWA OIL AND GAS CONSERVATION COMNDON APPLICATION FOR SUNDRY APPROVALS JUL 1 2 2012 20 AAC 25.280 0 77 ! Z 1. Type of Request: Abandon r Plug for I�edrill , . �� . Perforate New Pool r Repair well r Chang A •G J '"" Suspend r Rug Perforations Perforate r Pull Tubing r Time Extension r Operational Shutdow n fl Re -enter Susp. Well r Stimulate r Alter casing E Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development F , Exploratory r 201 - 044 - 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 23006 - 00 ' 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes f No ji+ 1J -09 ' 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25661 • Kuparuk River Field / Kuparuk River Oil Pool ' 11. PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 9850 • 6350 ` 9739' 6293' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115' 115' SURFACE 5604 9.625 5639' 3949' PRODUCTION 9166 7 9198' 6011' LINER 826 3.5 9807' 6328' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9604' - 9676' 6224' - 6261' 3.5 L - 80 9027 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - WEATHERFORD ER PACKER MD= 6843 TVD= 4648 PACKER - WEATHERFORD ER PACKER MD= 6873 TVD= 4666 PACKER - BAKER ZXP TOP PACKER MD= 8988 TVD =5897 SSSV - CAMCO DS NIPPLE MD= 524 TVD =523 12. Attachments: Description Summary of Proposal J 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service E 14. Estimated Date for Commencing Operations: g/i / p' %Ti 15. Well Status after proposed work: 77/ 2012 i 4 I I r Oil Gas r WDSPL -' Suspended P • 16. Verbal Approval: D ill WIND r GINJ I WAG r Abandoned r Commission Representative: GSTOR r SPLUG r 17. I hereby certi that the foregoing is true and correct to the best of my knowledge. Contact: Gary Eller @ 263 -4172 �� Printed N Ne 44,\ e J. G. er Title: CTD Engineer '''''',‘ Signature . 41kNe Phone: 263 -4172 Date 1 1\ i? ()VI_ Commission Use Only Sundry Number:a 2, 3 Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test VMechanical Integrity Test r Location Clearance r Other: 3S" p 5 / BO / '} ,- i l r� . Nvti / 5pre* a5 i,�c' / ��✓� e r �0 /i•4C`2�, lIZlL A q ft 1, /1 ,o /4 et ` p p Subsequent Form Required: ( n APPROVED BY 7 �j _ ('� / Appro by: r ////� /j' '�J4 COMMISSIONER THE COMMISSION Date: V FOrm 4T/ U= 3'tC>:ViS�EI14/M V L 2. f 2.� Submit in Du plicate � /, 11� O R6tNAL , i • KRU 1J -09 CTD Summary for Plugging Sundry (10 -403) Summary of Operations: Well KRU 1J -09 is an existing Kuparuk C -sand producer. The 1J -09A sidetrack will increase reservoir exposure and improve waterflood sweep. The existing C -sand perfs will be squeezed with cement in preparation for the CTD sidetrack to help minimize losses while drilling. This sundry request is being submitted for the abandonment of the original 1J -09 completion in preparation for this CTD sidetrack. ConocoPhillips requests a variance from the requirements of 20 AAC 25.112(c)(1) to plug the perfs in this manner. The 1J -09A sidetrack will exit the 3 liner at 9605' MD off of a mechanical whipstock and will target the C ' sand south of the existing well with a 3095' sidetrack. The hole will be completed with a 2%" slotted liner to the TD of 12,700' MD with the final liner top located inside the 3 liner at 9595' MD. CTD Drill and Complete 1J -09A Sidetrack: July /August 2012 Pre -CTD Work 1. RU slickline. Pull patch isolating the washed -out GLM at 6858'. 2. RU e -line. Caliper 3 liner and tubing. Get updated static BHP survey. 3. Run dummy whipstock to 9650' P6S5`- 4. Set 3 monobore whipstock at 9605' MD. RDMO e -line. C ivt ('r • 5. MIRU coiled tubing. Mill out the XN- nipple at 9066' MD to 2.80" ID. 6. Cement squeeze the C -sand perfs at 9604'- 9676'. Cleanout excess cement down to the top of the . whipstock at 9605' MD. a. Drift and tag cement. Drawdown test cement plug. If the drawdown test fails, set a mechanical plug in the DS nipple at 8945'. 7. Prep site for Nabors CDR2 -AC, including setting BPV j . AL Cr (1 n5 t ! t v' Zy h4 p ri " fi Rig Work l e5 r ! C 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 1/16" BOPE, test. 2. 1J -09A Sidetrack (C sand, south) PEA a. Mill 2.80" window through 3 liner at 9605' MD b. Drill 2.70" x 3" bi- center sidetrack to TD of 12,700' MD c. Run 2%" slotted liner from TD up to 9595' MD, inside the 3 liner. Will use 12.0 ppg brine to over - balance formation pressure while picking up slotted liner. 3. Set plug in DS nipple at 8945' MD. N c "i V 4. Freeze protect. Set BPV, ND BOPE. P T 5. RDMO Nabors CRD2 -AC. Post -Rig Work 1. Pull BPV and plug at 8945' MD. Install gas lift design. 2. Obtain static BHP 3. Re- install patch isolating the washed out GLM at 6858' 4. Put well on production Page 1 of 1 July 11, 2012, FINAL KUP • 1J -09 ConocoPhillips i Well ributes; Max Angle & MD TD Alaska, Inc Wellbore A tt API /UWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Canoaoit>apps 500292300600 KUPARUK RIVER UNIT PROD 59.31 9,521.69 9,850.0 Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date -' SSSV: NIPPLE 80 9/25/2011 Last WO: 38.05 3/27/2001 Well Confi9: -1 J -09, 11 61 /201 2 10 24 12 AM Schematic- Actual Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag SLM 9,707.0 3/26/2011 Rev Reason: WELL REVIEW osborl 6/11/2012 HANGER, 30 1 11. 1 Casing Strings i Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt.. String .. String Top Thrd 6 P CONDUCTOR 16 15.250 35.4 115.0 115.0 65.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (TVD) ... String Wt.. String ... String Top Thrd SURFACE 95/8 8.921 35.3 5,639.0 3,948.9 36.00 J - 55 BTC - MOD Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (ND) ... String Wt.. String ... String Top Thrd PRODUCTION 7 6.276 32.2 9,197.7 6,011.3 26.00 L - 80 BTC - MOD Casing Description String 0... String ID... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd LINER 3 1/2 2.992 8,981.0 9,807.1 6,328.0 9 30 L -80 SLHT CONDUCTOR. Liner Details 35 -115 Top Depth (ND) Top Inc! Nomi... Top (ftKB) (ftKB) C) Item Description Comment ID (!n) NIPPLE, 524 8,981.0 5,892.7 55.40 TIE BACK TIE BACK SLEEVE 5.250 illt 8,988.3 5,896.9 55.48 PACKER BAKER ZXP TOP PACKER 4.438 III 8,995.0 5,900.7 55.56 HANGER BAKER FLEX -LOCK LINER HANGER 425..., Elk 9,007,8 5,908.0 55.72 SBE BAKER 80-40 SBE 4.000 GAS LIFT, 9,066.6 5,941.0 57.60 NIPPLE XN NIPPLE w/2.75 NO GO 2.750 2,922 Tubing Strings - Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd I SIN TUBING 31/2 2.992 29.6 9,026.5 5,919.5 9.30 L -80 EUE8RDMOD Completion Details GAS LIFT, Top Depth 5,088 (ND) Top Inc' Nom'.,. Top (ftKB) (ftKB) (°) Item Description Comment ID (in) 29.6 29.6 1.20 HANGER FMC GEN V TUBING HANGER 3.500 523.5 522.9 6.23 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.875 8,945.1 5,872.3 54.98 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.812 8,988.5 5,897.0 55.49 LOCATOR BAKER NO GO LOCATOR 3.000 S 35-5,6 9 8,989.8 5,897.7 55.50 SEAL ASSY BAKER GBH -22 SEAL ASSEMBLY w/MULE SHOE 3.000 PACKER, 6,843 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) 1 Top Depth I (ND) Top Inc' ■ ) Top (ftKB) - (ftKB) ( °) Description Comment Run Date ID (in) PATCH, 6,846 6,843.0 4,648.3 54.63 PACKER WEATHERFORD ER PACKER 1/11/2012 1.750 GAS LIFT, L 6,858 6,845.8 4,649.9 54.61 PATCH SPACER PIPE & SNAP LATCH ASSEMBLY 1/11/2012 1.750 1 1 6,873.1 4,665.8 54.47 PACKER WEATHERFORD ER PACKER 12/28/2011 1.750 AFF IF PACKER. 6,873 Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (RKB) (ftKB) Zone Date (sh •• Type Comment 9,629.0 6,224.0 6,236.3 C-4, 1J -09 3/27/2011 6.0 RPERF 2.5" gun, Alt. DP, 60 deg. ph GAS 8,067 9,620.0 9,650.0 6,231.6 6,247.3 C4, C3, C2, 6/7/2001 6.0 IPERF 2.5" gun, Alt. DP, 60 deg. ph in 1J-09 9,650.0 9,676.0 6,247.3 6,260.8 C3, C2, C1, 3/27/2011 6.0 RPERF 2.5" gun, Alt. DP, 60 deg. ph - 1J -09 GAS LIFT. Stimulations & Treatments 8 893 , - Bottom Min Top Max Btm Top Depth Depth MI Depth Depth (TVD) (TVD) (ftKB) (ftKB) (RKB) (ftKB) Type Date Comment - 9,620.0 9,650.0 6,231.6 6,247.3 C SAND FRAC 6/13/2001 113M# poppant behind pipe; 9.2 ppa on Perfs NIPPLE. 8945 Notes: General & Safety 1 End Date Annotation 9 /28/2010 NOTE: View Schematic w/ Alaska Schematic9.0 LOCATOR, 8,989 SEAL ASSY, 8.990 � �i® w i Mandrel Details PRODUCTION, Top Depth Top Port 32 4098 (TVD) Ind OD Valve Latch Size TRO Run RPERF, Stn Top (ftKB) (ftKB) (°1 Make Model (in) Sery Type Type (in) (psi) Run Date Com... 9, 604 PER -, 1 2,922.3 2,405.8 53.42 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,230.0 1/15/2012 9,620 - 9,650 2 5,087.7 3,627.3 54.32 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 1/12/2012 C SAND FRAC, 1 9 3 6,858.2 4,657.1 54.55 CAMCO KBUG 1 GAS LIFT OV BK 0.188 0.0 6/18/2001 RPERF, 9.650 - 9,676 4 8,067.3 5,362.5 53.99 CAMCO KBUG 1 GAS LIFT DMY BK 0.000 0.0 10/12/2011 5 8,893.2 5,842.2 54.36 CAMCO MMG 1 1/2 GAS LIFT DMY RK 0.000 0.0 6/1/2001 1 1 LINER, 8,981 - 9,807 N , t TD, 9,850 1J -09A Proposed CTD Sidetrack Updated: 10- Jul -12 3 -1/2" Camco D nipple @ 523' RKB (ID = 2.875 ") 16" 62# H-40 shoe @ 115' MD 1111111 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface 3 -1/2" Camco KBUG gas lift mandrels @ 2922', 5088', 6858', 8067' RKB 3 -1/2" Camco MMG gas lift mandrels @ 8893' RKB 9 -5/8" 36# J -55 Stuck orifice valve in GLM #3 (6858'), typically covered by shoe @ 5639' MD retrievable patch. Patch will be re- installed post -CTD. 3 -1/2" Camco DS nipple © 8945' RKB (ID = 2.813 ") • ■ Baker 3 -1/2" GBH -22 seal assembly @ 8990' RKB (3" ID ?) Liner top Baker 5" x 7" ZXP liner top packer @ 8988' RKB Baker 5" x 7" Flexlock liner hanger @ 8995' RKB i„,„,„„„„ Baker 80-40 PBR (4" ID seal bore) @ 9008' RKB 7" 26# L -80 shoe 3 -1/2" HES 'XN' landing nipple @ 9066' RKB (2.75" min ID, will be milled @ 9198' RKB out to 2.80 ") 3 -1/2" monobore whipstock @ 9605' MD, cemented in KOP @ 9605' MD place 1J -09A C -sand • TD @ 12,700' MD NNE C -sand perfs — ,i (squeezed) 9604' / ' / — — -- - 9676' MD 3" openhole w/ 2 -3/8" slotted liner 3-1/2" 9.3# L -80 shoe @ 9807' RKB • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monda y , February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 f form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and / operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. -- 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accu racy. Thanks, Steve D. file: //F: \Dai1y_Document Record \Procedures_Instructions \FW INTENT PLUG for RE - DRI... 4/6/2012 • • Ferguson, Victoria L (DOA) From: Venhaus, Dan E [ Dan.Venhaus @conocophillips.com] Sent: Monday, July 16, 2012 3:28 PM To: Ferguson, Victoria L (DOA) Cc: Eller, J Gary Subject: RE: Well 1J -09 Plug for CTD Redrill Sundry (312 -253) Attachments: 1J -09 proposed CTD schematic.pdf Victoria, The drilling permit was submitted with the sundry application and has most of the additional information you requested. Answers to your questions: 1. See attached schematic 2. The current well makes approximately 300 bopd, 60 -80% water cut. The reason for plugging the wellbore is to isolate the fractured perforated interval helping mitigate losses which could be prevalent with the low bottom hole pressure. The proposed lateral will access C -sand reserves south of the existin• well on the field periphery. We plan to exi - - is - • w- I•"tT ii r • - _ = - • accessing the exis in. - ves wi e - - .I, of o 1 cO4 of ,' 3. om the drilling permit: Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The most recent static BHP measurement in well 1J -09 was taken in April 2011 recording a pressure of 2129 psi at 9590' MD, 6217' TVD for a 6.6 ppg gradient. We plan to obtain an updated static pressure survey prior to squeezing the C sand perfs. The proposed 1J -09A sidetrack will likely encounter slightly increasing formation pressure as the sidetrack is drilled, although C sand formation pressure in the area is down due to several offset injectors being shut -in for an extended period. Maximum potential formation pressure is based on the February 2010 pressure measurement from 1D -07 to the north, which had measured formation pressure of 2714 psi at 7988' MD, 6146' TVD for a gradient of 8.5 ppg. In 1J -09A this equates to a maximum potential formation pressure of 2749 psi (9605' MD, 6225' TVD) and a maximum potential surface pressure of 2124 psi assuming a gas gradient to surface. Let me know if you need anything else. Dan Venhaus Wells /CTD Engineer ConocoPhillips AK. Inc. 907 - 263 -4372 office 907 - 230 -0188 cell From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson@alaska.govl Sent: Monday, July 16, 2012 2:05 PM To: Venhaus, Dan E Subject: [EXTERNAL]FW: Well 13-09 Plug for CTD Redrill Sundry (312 -253) From: Ferguson, Victoria L (DOA) Sent: Monday, July 16, 2012 1:54 PM To: 'Eller, 3 Gary' Cc: Schwartz, Guy L (DOA) Subject: Well 13-09 Plug for CTD Redrill Sundry (312 -253) Gary, Please provide the following: 1 • • 1. Wellbore schematic of proposed completion 2. Information on current well production characteristics and reasons for plug and redrill 3. Reservoir pressure and maximum potential surface pressure Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a alaska.gov 2 • • Ferguson, Victoria L (DOA) From: Venhaus, Dan E [ Dan.Venhaus @conocophillips.com] Sent: Monday, July 16, 2012 3:28 PM To: Ferguson, Victoria L (DOA) Cc: Eller, J Gary Subject: RE: Well 1J -09 Plug for CTD Redrill Sundry (312 -253) Attachments: 1J -09 proposed CTD schematic.pdf Victoria, The drilling permit was submitted with the sundry application and has most of the additional information you requested. Answers to your questions: 1. See attached schematic 2. The current well makes approximately 300 bopd, 60 -80% water cut. The reason for plugging the wellbore is to isolate the fractured perforated interval helping mitigate losses which could be prevalent with the low bottom hole pressure. The proposed lateral will access C -sand reserves south of the existing well on the field periphery. We plan to exit the existing wellbore in the perforated interval thereby accessing the existing reserves with the lateral, too. 3. From the drilling permit: Reservoir Pressure and Maximum Downhole Pressure (Requirements of 20 AAC 25.005 (c)(4)(a)) The most recent static BHP measurement in well 1J -09 was taken in April 2011 recording a pressure of 2129 psi at 9590' MD, 6217' TVD for a 6.6 ppg gradient. We plan to obtain an updated static pressure survey prior to squeezing the C sand perfs. The proposed 1J -09A sidetrack will likely encounter slightly increasing formation pressure as the sidetrack is drilled, although C sand formation pressure in the area is down due to several offset injectors being shut -in for an extended period. Maximum potential formation pressure is based on the February 2010 pressure measurement from 1D -07 to the north, which had measured formation pressure of 2714 psi at 7988' MD, 6146' TVD for a gradient of 8.5 ppg. In 1J -09A this equates to a maximum potential formation pressure of 2749 psi (9605' MD, 6225' TVD) and a maximum potential surface pressure of 2124 psi assuming a gas gradient to surface. Let me know if you need anything else. Dan Venhaus Wells /CTD Engineer ConocoPhillips AK, Inc. 907 - 263 -4372 office 907 - 230 -0188 cell From: Ferguson, Victoria L (DOA) fmailto :victoria.ferguson @alaska.gov] Sent: Monday, July 16, 2012 2:05 PM To: Venhaus, Dan E Subject: [EXTERNAL]FW: Well 1J -09 Plug for CTD Redrill Sundry (312 -253) From: Ferguson, Victoria L (DOA) Sent: Monday, July 16, 2012 1:54 PM To: 'Eller, J Gary' Cc: Schwartz, Guy L (DOA) Subject: Well 1J -09 Plug for CTD Redrill Sundry (312 -253) Gary, Please provide the following: 1 • • 1. Wellbore schematic of proposed completion 2. Information on current well production characteristics and reasons for plug and redrill 3. Reservoir pressure and maximum potential surface pressure Thanx in advance, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferquson(a�alaska.gov 2 z\7 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 16, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Multifinger Imaging Tool (MIT) : 1J-09 Run Date: 7/13/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data (LAS), Digital Log file, Casing Inspection Report, 3D Viewer 1 CD Rom 50- 029 - 23006 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com / r_. Date: 1 �- Signed: / R r` • 2-0 - 2135`k WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. January 3, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 wit i t ogo A U Cl 1 3 't'. RE: Plug Setting Record: 1J -09 Run Date: 12/28/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23006 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood @halliburton.com Date: �} °� Signed: 34,04- Si.4-4 • • Iry ConocoPhillips Alaska P.O. BOX 100360 e ANCHORAGE, ALASKA 99510 -0360 ' '" lsks Vii/ January 18, 2012 4,^ r 18. Comm,. Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7 Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Seamount: Enclosed please find the 10 -404 Report of Sundry Well Operations for ConocoPhillips Alaska, Inc. well 1J-09 (PTD 201 -044) for a Weatherford retrievable tubing patch. Please call Kelly Lyons or myself with any questions. Sincerely, t2 ?. IL Brent Rogers Problem Well Supervisor STATE OF ALASKA r ALASK L AND GAS CONSERVATION COMMISON REPORT OF SUNDRY WELL OPERATIONS / , P 1. Operations Performed: Abandon r Repair w ell r Rug Perforations r Stimulate r Other j� f^� Alter Casing r Pull Tubing r Perforate New Fool r Waiver r Time Extension r Change Approved Program r Operat. Shutdown r Perforate r Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: _ ConocoPhillips Alaska, Inc. Development r Exploratory r — 201 - 044 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic r Service r 50 - 029 - 23006 - , — Q( ) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661 a' -- 1J-09 9. Field /Pool(s): • Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9850 feet Plugs (measured) None true vertical 6350 feet Junk (measured) None Effective Depth measured 0 feet Packer (measured) 8990 true vertical 0 feet (true vertucal) 5898 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115' 0 0 SURFACE 5604 12 5639 3949' 0 0 PRODUCTION 9166 10 9198 6011' 0 0 0 0 0 0 0 o ?Pr — o Perforation depth: Measured depth: 9604-9629, 9620 -9650, 9650 -9676 2 o ���, True Vertical Depth: 6224 -6236, 6232 -6247, 6247 -6261 ;r:, Tubing (size, grade, MD, and ND) 3.5, L -80, 8989 MD, 5897 TVD 3 1/2" Weatherford patch, 684 6876' Packers & SSSV (type, MD, and ND) SEAL ASSY - BAKER GBH -22 SEAL ASSEMBLY @ 8990 MD and 5898 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation N/A N/A N/A N/A N/A Subsequent to operation N/A N/A N/A N/A N/A 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development r ~ Service r Stratigraphic r X 15. Well Status after work: Oil yo Gas r VVDSPL r Daily Report of Well Operations GSTOR r WINJ r WAG r GINJ r SUSP r SPLUG r 16. 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 Brent Rogers /Kelly Lyons Printed Name Brent Rogers Title Problem Well Supervisor Signature ./441/4 Phone: 659 -7224 Date 01/18/12 RBDMS JAN 2 0 / Form 10-404 Revised 10/2010 Original Only • 1J-09 • DESCRIPTION OF WORK COMPLETED SUMMARY Date Event Summary 12/28/11 RUN WEATHERFORD ER PACKER (2.74" RUN OD). SET PACKER AT 6876' RKB. CORRELATED TO HES LDL LOG DATED 11 -25 -2011 12/29/11 SET ER TEST TOOL IN PKR @ 6876' RKB. COMBO MIT TXIA TO 1975 PSI, PASS. IN PROGRESS ** *CMIT pass: pre TIO= 200/450/160, Initial TIO= 1975/1975/320, 15 min TIO= 1950/1950/320, 30 min TIO= 1950/1950/320 12/30/11 SET 31' WEATHERFORD PATCH ASS'Y (ER PKR, SPACER & SNAP LATCH) @ 6844' RKB. ATTEMPT TO MITIA ( FAILED ). SET ER TEST TOOL IN UPPER ER PKR ( FAILED ), SET HOLEFINDER ON TOP OF UPPER PACKER AND TBG TESTED. SET NEW ER TEST TOOL IN UPPPER PACKER AND TBG TESTED. ATTEMPT TO MITIA AND ABLE TO OBTAIN 1.3 BBL PER MIN. RATE @ 1700 PSI. IN PROGRESS. * ** *MITT pass Pre TIO= 250/250/150, initial TIO= 2550/250/150, 15 min TIO= 2480/250/150, 30 min TIO= 2450/250/150. MITIA fail: 1.3 bpm @ 1700 psi, falls off rapidly when shut pump in. * ** 12/31/11 PULLED WEATHERFORD PATCH @ 6844' RKB. SNAP LATCH WAS NOT SHEARED, INDICATING STINGER WAS NOT IN LOWER PKR, 01/08/12 RAN ER PKR TEST TOOL TO PKR @ 6876' RKB. CMIT 1500 PSI, PASSED. PULLED TEST TOOL. READY FOR PATCH. ***CMIT pass: Pre TIO= 300/350/150, Initial TIO= 1525/1500/280, 15 min TI0= 1500/1500/280, 30 min TIO= 1500/1500/280. * ** 01/11/12 RAN 31.27' WEATHERFORD UPPER ER PKR PATCH ASSY'( 29.82' =OAL WHEN PULLING),SET @ 6876' RKB ( ZERO @ SNAPLATCH), RAN ER TEST TOOL TO 6814' SLM, MITT TO 1550 PSI;PASS, PRESSURE TBG TO 1500, T /I /0= 1550/800/114, AFTER 15 MINS. SAME PRESSURES, AFTER 30 MINS., SAME PRESSUREATTEMPT TO MITx IA TO 2500 PSI TO MUCH GAS ON IA 01/12/12 MITxIA TO 2500 PSI; PASS, PERFORM MIT x IA, TO 2500 PSI, T /I /0= 350/2500/390, AFTER 15 MINS T /I /0= 350/2440/390, AFTER 30 MINS, T /I /0 =350 2425/390 Summary Set 31.27' Weatherford retrievable ER Patch from 6845' - 6876'. MITIA following patch set passed confirming patch integrity. 2 o1 - ©' 4 1.49 %6 WELL LOG TRANSMITTAL G� To: Alaska Oil and Gas Conservation Comm. November 29, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 *chilistiED 1 °4 RE: Multifinger Imaging Tool (MIT) / Leak Detect Log: 1J-09 Run Date: 11/25/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data (LAS), Digital Log file, MIT report, 3D Viewer 1 CD Rom 50- 029- 23006 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com Date: \2/1( 1 k` Signed: Alego 6,4 STATE OF ALASKA ALASKA • AND GAS CONSERVATION COMMISSI. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Abandon r Repair w ell r Plug Perforations r Stimulate r Other r Alter Casing r Pull Tubing fl Perforate New Pool r Waiver r Time Extension r Change Approved Program r Operat. Shutdow n '"'` Perforate Fi Re -enter Suspended Well r 2. Operator Name: 4. Well Class Before Work: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development p Exploratory r - 201 - 044 3. Address: 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 Stratigraphic Service 50 C)c) 7. Property Designation (Lease Number): 8. Well Name and Number: ADL 25661 -• 1J-09 9. Field /Pool(s): Kuparuk River Field / Kuparuk River Oil Pool 10. Present Well Condition Summary: Total Depth measured 9850 feet Plugs (measured) None true vertical 6350 feet Junk (measured) None Effective Depth measured 9739 feet Packer (measured) 8989 true vertical 6293 feet (true vertucal) 5897 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 115 115 SURFACE 5604 9.625" 5639 3949 PRODUCTION 9166 7" 9198 6011 LINER 826 3.5" 9807 6328 APR 2 5 20Y RECEIVED Perforation depth: Measured depth: 9604' - 9676' True Vertical Depth: 6224' -6247' Alaska Gil & Gas Cogs. CORti ljSSion F t1G11Ar&e Tubing (size, grade, MD, and TVD) 3.5, L - 80, 9027 MD, 5897 TVD Packers & SSSV (type, MD, and TV)) PACKER - BAKER ZXP TOP PACKER @ 8988' MD and 5897' TVD NIPPLE - CAMCO DS NIPPLE w/ NO GO PROFILE @ 524 MD and 523 TVD 11. Stimulation or cement squeeze summary: Intervals treated (measured): not applicable Treatment descriptions including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil - Bbl Gas - Mcf Water - Bbl Casing Pressure Tubing Pressure Prior to well operation 182 1383 689 -- 175 Subsequent to operation 251 2096 762 -- 190 13. Attachments 14. Well Class after work: Copies of Logs and Surveys run Exploratory r Development p r Stratigraphic r 15. Well Status after work: Oil G as WDSPL r Daily Report of Well Operations XXXX GSTOR WIND I WAG I' GINJ r SUSP r SPLUG 16. 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: none Contact John Peirce @ 265 -6471 Printed Name John Peirce � Title Wells Engineer 41 Z � �� i Signature z. j........ Phone: 265 -6471 Date Form 10-404 Revised 10/2010 ®MS APR 25 20 5r -' .mit Original Only f/57 1J -09 Well Work Summary DATE SUMMARY 3/21/11 PERFORMED FILL CLEAN OUT Pi CT, COULD NOT ESTABLISH RETURWITH SD, CAME UPHOLE TILL RETURNS WERE DIESEL TRYING TO SWAP FLUID TO DECREASE HYDROSTATIC HEAD, COULD NOT GET RETURNS, WENT IN AND PERFORMED FLUFF AND STUFF, HARD TAG AT 9769 CTMD, FREEZE PROTECTED WELL, JOB COMPLETE, TURN OVER TO DSO 3/26/11 TAGGED @ 9707' SLM WITH 2.65" SWAGE & BAILER. RAN 25' x 2.63" DUMMY GUN TO 9707' SLM. READY FOR E /L. 3/27/11 PERFORATE C SAND INTERVALS: 9650' -9676' (26' ZONE) GUN RUN #1, 9604' -9629' (25' ZONE) GUN RUN #2. 2 -1/2" MILLENNIUM DP, 6SPF, 60 DEG PHASING. 4/19/11 MEASURED BHP @ 9590' RKB: 2130 PSI. COMPLETE. -0, e KUP C • 1J -09 a - ConocoPhdhps ? ( i Max Angle & MD TD Atu2�Ni1K Inc VM' "`TM Wellbore API /UWI Feld Name Well Status Inc! ( °) IMD (ftKB) Act Btm (ftKB) C;o1KKd'hillh'S `;1 500292300600 RIVER UNIT PROD _ 59.31 9,521.69 9,807 0 ... Ann do SLM p J ( 7 8) nd Dat 011 ( A n Reason: PERFORATIONS I 1 NS - ____ 05 nine Mod .. n Date 11 - Comment (ppm) Data A t t End Date KB-Grd ft Rig Release Date _ Well Config 1253, 3/28/2011 1.3124 PM Scriema, c Actual A not D • et, kK6 (End Dale Annotation Last Mod .. End D ate Casing Description S _.. _._ .. - __.. .. HANGER, 30 ': Cnsjog Strin String O String ID Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... Siring .. String Top Thrd S CONDUCTOR 16 15.250 35.4 1150 115.0 65.00 H WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 9 5/8 ' 8. 921 35.3 5,6390 3,948.9 3600 J - 55 BTC - MOD Description Casing Description String O._ String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String WI... String ... String Top Thrd - " - - - - - -- ` ' , . , - ' PRODUCTION 7 615 32.2 9,197.7 6,011.3 26.00 L BTC - MOD Casing Description String O... String ID ... Top (ftKB) Set Depth (T... Set Depth (TVD)... String Wt... String ... String Top Thrd LINER 3 1/2 2 -992 8,981.0 9,807.1 6,328.0 9.30 L-80 I SLHT Liner Details CONDUCTOR, "':' „p. Top Depth ' 35 -115 (TVD) Top Inc! T.. ftKB V f') Item Deseri• ;on Comment ID (in) 8,981.0 5,892.7 55 40 TIE BACK TIE BACK SLEEVE 5.250 NIPPLE, - PPLE,s2a- - - - -- I `5.48 8,986.3 5,896.9 PACKER BAKERZXPTOPPACKER 4.438 8,995.0 5,900.7 55.56 HANGER BAKER FLEX -LOCK LINER HANGER 5.000 9,007.8 5,9088 55.72 SBE BAKER 80-40 SBE 4.000 9,066.6 5,941.0 s7 60 NIPPLE XN NIPPLE w/ 2 75 NO GO 2.750 1 GAS UFT, TUBIND escr, tion String S 2 T 29.6 ` 2,922 Tubing Strings Tubing p g g op (ftKB) (Set Depth (f. ( Set Oepth (TVD) (String Wt...ISt ,rig String Top Thrd J 1 1 1 1 1 5,919 5 9 30 EUE8RDMOD d Completion Details Top Depth (TVD) Top that Nomm... GAS uEr, _... _..:. T• • ftKB (ftKB) (7 Hem Description Comment ID (in) 29.6 29.6 1.20 HANGER FMC GEN V TUBING HANGER 3.500 523.5 522.9 6.23 NIPPLE CAMCO DS NIPPLE w/ NO GO PROFILE 2.875 8,945.1 5,872.3 54.98 NIPPLE CAMCO DS NIPPLE W/ NO GO PROFILE 2.812 8,988.5 5A97 55.49 LOCATOR BAKER NO GO LOCATOR 3.000 I 8,989.8 5,897.7 55.50 SEAL ASSY i BAKER GBH -22 SEAL ASSEMBLY 3.0001 SURFACE, 35 -5.639 `. Perforations & Slots Shot Top (TVD) Btm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (eh... Type CmnnWet GAS LIFT. - - -_. - 6,858 I 9,604 9,629 6,224.0 6,236.3 C-4,1.1-09 3/27/2011 6.0 RPERF 2.5' gun, Alt DP, 60 deg. ph 9,620 9,650 6,231.6 6,247.3 C4, C3, C2, - 6/7/2001 6.0 IERF 2.5' gun, Alt. DP, 60 deg. ph 1J-09 ,_' - -- -- - 9,650 9,676 6,247.3 6,260.8 C3, C2, Ct, 3/2712011 6.0 RPERF 2.5' gun, AK. DP, 60 deg. ph 1J -09 GAS LIFT _ • ' * _. _._.._. 8,067 - - Stimulations & Treatments Bottom Min Top Max Bin Top Depth Depth Depth Depth (TVD) (TVD) (ftKB) (ftKB( (HKB) (ftKB) Type _Date Comment 9,620.0 9,650 3 6,231. 6,247.3 C SAND FRAC 6/13/2001 ,113M8 poppant beh rid pipe 9 2 ppa on Perfs GAS LIFT. 8,893 ,.- Notes: General & Safety End Date Annotat,on r -. 9/28/2010 NOTE: View Schematic w/ Alaska Schematic9. NIPPLE, 8,945 - LOCATOR, 8,989 .._. ..._..,`: :j PRODUCTION. 32 -9196 • Mandrel Details Top Depth Top Port 1 9,604 Stn (TVDI Inc! OD Valve Latch Size TRO Run RPERF," - - -.. (5661 ( mice Model (i n) Sery Ype Y e (in) (p Run Dale Com... ToP IRKBZ T T ] 0 SAND FRAC, 9,629 1 2,922.3 2 105. 53.42 CAMCO KBUG 1 GAS LIFT GLV BK 0.125 1,247.0 6/18/2001 !PEKE 9,620 - 9,650 2 5,087.7 027.3 54.32 CAMCO KBUG 1 GAS UFT GLV BK 0.188 1,306.0 6/18/2001 RPERF, , 3 6,858.2 4,0.57.1 54.55 CAMCO KBUG 1 GAS UFT OV BK 0.188 0.0 6/18/2001 9,650 - 9,676 - 4 8,067.3 5 : 302.5 53.99 CAMCO KBUG 1 GAS UFT DMY BK 0.000 0.0 4/2/2001 5 8,893.2 5,842.2 54.36 CAMCO MMG 1 1/2 GAS UFT DMY RK 0.000 0.0 6/1/2001 TD,9,807 LINER, , 8,961 -9,807 WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. March 30, 2011 Attn.: Christine Shartzer 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1J -09 Run Date: 3/27/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1J -09 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 23006 -00 .;.a0 APR I S PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 cg-6115-5 klinton.wood @halliburton.com c)01-06P Date: Signed: • COI'1 ~ . . ocoPh ~ I I i ps Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 August 31, 2009 Mr. Tom Mau.nder Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Dear Mr. Maunder: ~ ,'~, ' + 4 r~~~ ~ ~ ~ - ~ ~}"~-~' r ~~' ~ 1 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRU). Each of these wells was found to have a void in the conductor. These voids were filled with cement if needed and corrosion inhibitor, engineered to prevent water from entering the annular space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped August 15th and 23`d 2009, and the corrosion inhibitor/sealant was pumped August 27~', 28;~ and 29~' 2009. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, ~ G~ MJ Loveland • SEP 0 2 ZOpg Al~sk~ Oil ~ ~~~ ~on~..~a ~ss6on An~~O~~ ConocoPhillips Well Integrity Projects Supervisor • • t` ~ kr ~~~ ~ - ~ ~f ~~ ~ ~ ;;~ P ~~ ~~ 7_n~`.~ ConocoPhillips Alaska Inc. q"°.~P.ao_14~SE ~~"6 F-,a (.?.;~"0 ~q~.~~~, ~\l~PtlS.":~6f~~.?(;~ ~+184`,~st'xt^,,.s:a'p Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Dt a e 1J,3G,1A & 2Z Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ~ _ a~ - - 1J-03 50029230020000 2010240 22" N/A 22" N/A 4.1 8/29/2009 1J-09 50029230060000 2010440 28" N/A 28" N/A 6.2 8/29/2009 1J-10 50029230100000 2010710 12" N/A 12" N/A 2.3 8/29/2009 1J-133 50029233150000 2061060 3' N/A 3' N/A 23.8 8/30/2009 36-24 50103201450000 1901340 18" N/A 18" N/A 5.1 8/30/2009 1A-19 50029221110000 1901610 30" N/A 30" N/A 3.8 8/30/2009 2Z-04 50029209650000 1830860 19" N/A 19" N/A 3.5 8/30/2009 2Z-05 50029209560000 1830760 12" N/A 12" N/A 2.1 8/30/2009 2Z-07 50029209460000 1830640 9" N/A 9" N/A 8.5 8/30/2009 2Z-15 50029213620000 1851080 9" N/A 9" N/A 2.8 2Z-21 50029218770000 1881250 3' N/A 3' N/A 19.6 8/30/2009 PAD e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _Marker. doc Re: [Fwd: Kuparuk 1J Well Testing] ) ) Subject: Re: [Fwd: Kuparuk 1J Well Testing] From: John Hartz <jack_hartz@admin.state.ak.us> Date: Wed, 10 Aug 2005 13:10:58 -0800 To: Brian Seitz <Brian.Seitz@conocophillips.com> CC: Thomas E Maunder <tom_maunder@admin.state.ak.us> --- J-O \ -0 ~L\ If dO t - 0 ~ l-\ dO \ - 0'\ \ Brian, Your request appears to be an operational necessity for a short period until the 1J Pad facility is commissioned. Your proposal to test 1J-03 and test ~9 & 1J-10 if monitoring data indicate performance changes is acceptable. Notify ~f the schedule is significantly delayed beyond November 1. Thank you for the notification. Jack Hartz, P.E. Sr. Reservoir Engineer Alaska Oil & Gas Conservation Commission 333 W 7th Ave. Suite 100 Anchorage AK 99501 907-793-1232 Fax: 907-276-7542 SCIANNE.D AUG 11 2.005 Thomas Maunder wrote: Jack, For your reply. Tom -------- Original Message -------- Subject: Kuparuk 1J Well Testing Date: Wed, 10 Aug 2005 09:02:50 -0800 From: Seitz, Brian <Brian.Seitz@conocophillips.com> To: tom maunder@admin.state.ak.us CC :C"EïFl.......pi::·o·d......En:g·r···....~·r1:i..2..6..9(iº·ë:;·õï:1:õë.~·¿;p1:1i 11 ì.pf:.~ . com>, "Spenceley , Neil" .~.~.~:.t....~....:..}S..:...ª.P.§.~.S?~..~..~.y.~.~S?J].9...S?..?P...þ.t...~..~...~.p...§...:...S:..S?~..?:" II John stone, S am I' cSam.Johnstone@conocophillips.com> Tom- The three existing Kuparuk producing wells on 1J pad are currently tested monthly as twinned well tests using the test facility on 1D pad. In addition, we obtain single well tests every 6 months with a portable test separator to verify individual well production. In mid-September, these wells will be tied into the new 24" production line recently installed from 1J pad to CPF-1 and we will lose our ability to test the wells through the 1D pad facility. The new 1J pad separator is scheduled to be placed in service on November 1, 2005. CPAI requests a waiver from the monthly well testing requirement for wells 1J-03, IJ-09, and 1J-10 until the new 1J test facility is in service. We will be testing 1J-03 with a portable test separator following a coiled tubing sidetrack scheduled for August, and will retain the option of testing 1J-09 and 1J-10 should pressure and temperature trends indicate significant changes in well performance. Please let me know if this plan is acceptable, or give me a call if you wish to discuss it in further detail. Regards, Brian Seitz CPF-1 Lead Drillsite Petroleum Engineer 265-6961 8/1 0/2005 1: 17 PM Well l J-09 Sidewall Core Descriptions v-f'me sand -- 0.062-0.125, silt -- 0.004-0.062, clay = <0.004 Sample ID 32863A 32865 32866 32868 32869 32871 32872 32873 32874 32875 32876 32877 32878 32879 32880 32881 32882 32883 32884 32885 32886 Depth (~.) 4826 4838 4842 4907 4915 4926.5 4934 4938 4945 4952 4958 4976.5 4982 4987 4993 4998 5002 5008 5012 5032 5038 Zone D D D Description Color: med. brown; Grain Size: v. f'me sand with silt - one 3 mm black grain Color: grayish brown; Grain Size: silt with v. frae sand, no fizz Color: med. brown; Grain Size: silt with v. frae sand and clay, no f~zz 32887 ,5053 32888 5058 32889 5061 32890 5075 32891 5081 32892 5095 32893 5105 32894 5128 32895 5133 32896 5164 32897 5168 32898 5171.5 32899 5178 32900 5183 32901 5222 32902 5228 32903 5233 32904 5238 B B B · B B B B B Color: grayish brown; Grain Size: silt with clay; trace fmc-size black gms Color: grayish brown; Grain Size: clay and silt Color: med. brown; Grain Size: silt with clay Color: med. brown; Grain Size: silt Color: med. brown; Grain Size: silt with clay Color: med. brown; Grain Size: silt Color: grayish brown; Grain Size: clay · Color: gray; Grain Size: clay A4 Color: gray; Grain Size: clay A4 Color: grayish brown; Grain Size: clay: A4 Color: grayish brown; Grain Size: clay A4 Color: gray; Grain Size: clay A4 Color: gray; Grain Size: clay; mica (?) present A4 Color: gray; Grain Size: clay; mica (?) present A4 Color: gray; Grain Size: clay; mica (?) present A4 Color: grayish brown; Grain Size: silt with clay A4 Color: gray; Grain Size: clay A4 Color: gray; Grain Size: clay A3 Color: med. gray to light brown; Grain Size: silt with strands of hair-like substance A3 Color: med. gray to light brown; Grain Size: silt A3 Color:. light brown silt grains in a med. gray clay matrix A3 Color: light brown and gray; Grain Size: silt A3 Color: light brown and gray; Grain Size: silt in clay matrix A3 Color: dark gray clay with brown silt clasts A3 Color: light t° med. brown; Grain Size: very f'me A3 Color: light to med. brown; Grain Size: very f'me A3 Color: med. gray clay with brown silt particles A2 yellowish brown, very fine, black specs-silt size A2 Color: yellowish brown; Grain Size: very fine A2 Color: yellowish brown, very fine, white strands A2 Color: yellowish brown; Grain Size: very fmc, mica flakes A2 Color: white gray, clay, white strands A2 Color: gray clay with 20% light brown silt A2 Color: yellowish brown; Grain Size: very f'me A2 Color: yellowish brown; Grain Size: very frae A2 Color: gray; Grain Size: clay PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4135 Fax: (907) 265-6224 July 13, 2001 Commissioner Canuny Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1J-09 (201-044) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kuparuk well 1J-09. If you have any questions regarding this matter, please contact me at 263-4135 or Todd Mushovic at 265-6974. SincereJs~, Interim Drilling Engineering SupervisOr ?XI-D¥illih'~ TAB/skad RECECVED JUL O 3 2O03' Alaska Oit & O~s Cm~i, Commission ORIGINAL STATE OF ALASKA AL~ A OIL AND GAS CONSERVATION CO~ .~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status o! well Classification of Service Well Oil [] Gas E~ Suspended [~] Abandoned U Service [-1 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 201-044 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-23006-00 4. Location of well at sudace ~9. Unit or Lease Name 2152' FSL, 2574' FEL, Sec. 35, T11N, R10E, UM (ASP: 558635, 5945963) Kuparuk River Unit At Top Producing Interval 10. Well Number 1943' FNL, 683' FWL, Sec. 26, T11N, R10E, UM (ASP: 556554, 5952414) 1J-09 At Total Depth 11. Field and Pool 1724' FNL, 624' FWL, Sec. 26, T11N, R10E, UM (ASP: 556493, 5952632) Kuparuk River Field 5. Elevation In feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB29.6' feetI ADL25661 ALK471 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 8, 2001 March 23, 2001 March 26, 2001 I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD +' TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thicl~ess of Permafrost 9850' MD / 6350' TVD 9739' MD / 6293' TVD YES ~] No r~I N/A feet MD 1602' (approx) 22. Type Electric or Other Logs Run GR/Res/Neu Dens, CCL 23. CASING, LINER AND CEI~IENTING RECORD SETTING DEPTH MD CASING SIZE VVT. PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORDI AMOUNT PULLED 16" 62.58# H-40 Surface 115' 24" 460 sx AS 9.625' 36# J-55 Surface 5639' 12.25" 653 sx AS Lite & 340 sx LlteCRETE 7" 26# L-80 Surface 9198' 8.5" 184 sx Class G , 3.5" 9.3# L-80 8981' 9807' 6.125" 196 sx Class G 24. Perforations open to Production (MD + TVD o! Top and Bottom and 25.' TUBING RECORD Interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9026' 8988' 9620'-9650' MD 6232'-6248' TVD 6 spt 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9620'-9650' 113M# pmppant behind pipe, 9.2 ppa on peris, left 26M# In wellbore 27. PRODUCTION TEST .Date_Eirst_Emdu.cti.o.n~ .... . Me.t..hod qf Operation (Flowing gas...!i~.,..etc.) .............................................................................. Flowing Date of Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIC~ 6/26/2001 15 hrs Test Period > 873 6136 0 40I 7799 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (cort) press. 1950 psi N/A 24-Hour Rate > 1277 9957 0 24° 28. CORE DATA Bdef description of Iitholocjy, porosity, fractures, apparent dips and pmssence of o11, gas or water. Submit core chips. To be sent under separate cover JUL 0 3 7_00,3 Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE ORIGINAL Submit In duplicate 29. 30. GE OLOGIC MARKEI~~ ~' FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, end time o! each phase. Top C4 9586' 6215' Base Kuparuk C 9688' 6267' Base Kuparuk A 9850' 6350' JUL ~ i~ '~ ~,~ ~ ,' ,,.. Annulus left open - lreeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional~urvey Signed -.*--. Title Interim DrillJn,q En.qineertn,q Supervisor Date Tom Brockway Prepared by Sharon Allsup-Drake 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'l-6-an'd-24: 'If'this' we'lHs"completed'for..separate p rodu.cti.on-*f rom....more-t h.an.one-in{erv.al..(mUltiple· cOmpletion); -so-state. in item 16, and in item 24 show the producing intervals for the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interVal. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection,. Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ORIGI'NAL Operations Summary 1J-09 Rpt Date Comments 03/07/01 12:00 AM Prep. Rig for move, Jack up sub, Pull off well 1J-03, Lost drive press.& repair Drive sub around corner of location & spot over 1J-09, Lower cellar doors, Drive power module around corner & stage near sub, attach speader links to power module. 03/08/01 12:00 AM Movepower module and merry up w/sub, Roll down cellar doors,Button up cellar Accept rig, Nipple up diverter stack, Spot ball mill Rig up diverter lines, Install lines in stair tower Change Breaker in SCR f/GEN #1, Work on prespud check list Pick up BHA tools to floor Function test Diverter system as per AOGCC Held presud meetings w/all crews, Perform prespud walk aroUnd &Check list Make up BHA, Fill Condutor Condition Cmt Contaiminated mud Drill f/115' to 322' 03/09/01 12:00 AM Drill f/322' to 1308' AST=5.5 hrs ART=4.0 hrs Pump sweep & Circ. clean POOH, Break bit Make up new bit, L/D Restrictor sub, Orient motor Down Icad sperry sun tools Change BHA (Pick up Neutron sub, ect.) Cut drilling line 65', Service rig R IH to 1308' Circ. BTM's up Drill f/1308' to 1322' AST=.25 hrs 03/10/01 12:00 AM Drill f/1322' to 3390' ART-8 hrs. AST=8 hrs. Pump sweep, Circ. hole clean 03/11/01 12:00 AM Circ. hole clean Monitor well, Dry pipe, Wipe hole f/3390' to 856' -mild sWabbing f/2030' to 1800' (Pump out)-RIH, Work thru spot @ 2030'., RIH-OK Circ. thick mud Drill f/3390' to 4870' ART=10.5 Hrs AST--- 2.75 HRS 03/12/01 12:00 AM Drill f/'4870'.to 5649' ART-6.75 Hrs AST-3.5 Hrs Pump sweep, Circ. hole clean POOH (SLM-No correction)- Hole in good shape Set back BHA, PJSM, Remove RA Sourses, L/D LWD, MWD, Motor, Bit Make up 12.25" Holeopener, BHA,'RIH 03/13/01 12:00 AM R IH 'w/Holeopener to 5649'- Hole in good shape Circ. Btm's up, Pump sweep around, Cond. mud ........................................................... POOHw/-Holeopener ..................................................... : ........................................................................... : ........................... Rig up Schlumberger wireline and TBG. Conveyed Sidewall cores RIH w/Core guns to 5238' ShoOt 11 cores f/5238' to 5128' POOH w/Wireline L/D side entry sub, L/D 2 stands DP, .P/U side entry sub, RIH w/wireline f/2nd latch 03/14/01 12:00 AM RIH w/wireline, latch wet connect Shoot 24 cores f/5105' to 4922', POOH w/wireline, L/D 2 stds DP, RIH w/wireline, Shoot 10 cores f/4915' to 4797', POOH w/wireline, L/D sideentry sub Circ. Btm's up POOH (slow) w/sidewall cores 03/15/01 12:00 AM 03/16/01 12:00 AM 03/17/01 12:00 AM 03/18/01 12:00 AM 03/19/01 12:00 AM 03/20/01 12:00 AM Operations Summary 1J-09 Remove cores f/core guns (45 total- 6 misfires- recovered 39), Rig down Schlumberger Service rig Make up Holeopener, RIH to 4780' Circ. Btm's up- Wash & Ream f/4780' to 5649' Pump sweep- Condition mud f/csg. Monitor well, Pump dry job, POOH w/Holeopener PJSM, Rig & run 9.625" csg. Change out o-ring on GBR fill up tool Finish running 9.625" csg. to 5639' ( took wt. @ 1800' & 4800') Make up FMC hanger and landing jt. Circ. & cond. mud f/cmt, job L/D fill up tool, Rig up cmt. head Finish circ. f/cmt, job PJSM Pump 10 bbls CW100 Preflush Test lines to 3500 PSI 10 bbls CW100 Preflush Drop btm plug 50 bbls 10.5 ppg MudPUSH Mix & pump 514 bbls lead cmt.@ 10.7 ppg Followed by 145 bbls tail cmt. @ 12.0 ppg Drop btm. plug Displace cmt. w/10 bbls wash water Cont Clean out flow line & shakers,' L/D cmt. equip & Landing jt. Change bales & elevators, Wash out diverter stack Nipple down diverter stack & lines Nipple up well head & BOP, Test well head to 1000 PSI-OK Test BOP to 250 PSI Iow & 5000 PSI High Test waived by AOGCC Lou Grimaldi Install wear bushing, Make up BHA & Run BHA from derrick Pick up 5" DP & RIH Pick up 102 jts. 5" DP, RIH & Tag TOC @ 5534' Circ. Btm's up f/Csg. Test Thaw out Kill line, Rig & Test 9.625" Csg. to 2500 PSI f/30 min.-OK Drill out F.C.,Cmt,Shoe & New hole to 5684' Change over to New Mud Rig & Perform LOT=EMW 15.4 ppg Perform PWD Base line test Drill f/5684' to 6250' ART= 2.25hrs AST=.5hrs Change shaker screens Drill f/6250' to 7100' ART=6.25hrs AST=.75hrs Note: Total Fluids sent to 1R- ' .18=9705 bbls Drill f/7100' to 7703' ART= 4hrs AST= 1.25hrs Pump sweep, Circ. Btm's up 2X, Dry pipe, Monitor well Wipe hole to shoe- 10-20K Normal Drag Cut-~&:slip-ddllingflne;Ser,cice-dg RIHto 7703'- Hole in good shape Circ. Btm's up prior to drilling Drilling f/7703' to 8476' ART= 3.25hrs AST= 6hrs Drill f/8476' to 9205'. ART=4hrs AST- 5hrs Pump sweep, Circ. hole clean, Monitor well, Pump dry job Wipe hole to shoe @ 5639'- Hole in good shape Pump sweep, Circ. clean & cond. f/csg., Monitor well, Dry pipe POOH to BHA- Hole in good shape Stand back HWDP, DoWn load LWD, Lay down BHA Download MWD, Finish L/D BHA. Clear floor Pull wear ring R/U to run 7" casing. ~I"' Operations Summary i' 1J-09 M/U float equipment and check. Run 7" casing to shoe @ 5635'. Circ casing volume Run 7" casing. Brk circ @ 7800' M/U casing hanger and landing jr. Circ and condition mud L/D fillup tool and pickup cmt head Pump 10 bbl water. Test lines to 3500 psi. Pump 20 bbl CWl00 Drop bottom plug. Pump 30 bbl mud push. Mix and pump 38.1 bbl slurry @ 15.8 ppg Drop top plug. Wash up on top of plug w/10 bbl water. Displace w/338.6 bbl mud w/rig pump. 03/21/01 12:00 AM 03/22/01 12:00 AM 03/23/01 12:00 AM 03/24/01 12:00 AM R/D cement head and elevators. L/D landing jt and long bales Set 7" packoff and tes to 5000 psi Tighten Lockdown screws and test packoff to 5000 psi. Change lower PR's to 4" and change TDS to 4" L/D excess 5" out of derrick Change pipehandling equipment to 4" R/U to test BOPE Test BOPE ti 250/5000 psi Pull test plug, install wear ring, blowd°wn choke/kill lines. R/U and P/U 10 stands 4" d.p. and stand back in derrick M/U bha and orient. Load nuke'sources Hook up kelly hose P/U 4" d.p. from shed Circ and test MWD Continue P/U 4" d.p. and running in hole P/U 4" d.p. and RIH CBU R/U and perform casing test to 3500 psi Drill 14' of cmt, FC, 83' cmt, FS, 9' Old hole, 33' of new hole to 9238' Changeover to 11.9 ppg mud. Do LOT to 16.0 ppg EMW Do PWD baseline test Drill form 9238' to 9825' Drill from 9825' to 9850' Circ Sweep and condition mud POOH to shoe Cut and slip 90' drilling line Service rig and topdrive RIH w/no problems ........ Pump-sweeps-and--circ. and-conditionmud POOH to shoe. Monitor well. Pump dry job. Blow down. Drop rabbit. POOH. L/D BHA. Download nuke sources DownloadLWD. Clear floor and R/U casers. M/U float equipment and check floats. P/U liner and hanger assembly RIH w/liner on 4" d.p. Fill pipe every 10 stds'. Br:eak circ eVery 2000'. RIH w/liner on 4" d.p. CBU @ shoe M/U cementing head on single and stand in derrick RIH w/liner and M/U cement assembly, attach hose Circ and condition mud Operations Summary i" 1J-09 03/25/01 12:00 AM 03/26/01 12:00 AM 03/27/01 12:00 AM Pump 10 bbl water, PT to 4500 psi, Pump 20 bbl CW100, 20 bbl Mudpush, 42 bbl slurry and flush cement lines. Drop plug and displace w/100 bbl mud w/DS. Did not bump plug (.4 bbl over displacement). Atempt to mechanically set hanger and release runnin CBU. Circ 10 bbl cement to surface L/D cement head and 2 singles M/U top ddve--d.p, stuck. Circ Release running tool from TOL POOH L/D 2 jts d.p. and inspect liner running tool and L/D. Appears that hanger was set but Liner top packer was not set. All of running tool recovered M/U cleanout asssembly and RIH RIH tag TOL @ 8981' Circ hole clean and condition mud R/U and test csg/liner and lap to 3000 psi for 5 min-OK POOH and L/D 4" d.p. L/D bha. Note performed LOT for injectivity on 1J-09 RIH w/8 stands d.p. from derrick L/D 8 stands d.p. R/U casers pull wearring and hold safety meeting. Run 3-1/2" completion. Finish running 282 jts 3-1/2" tubing. Circ tubing volume Test casing, liner and liner lap to 3500 psi for 30 min.-)K Displace well w/seawater. Space out tubing. M/U pups and hanger and land tubing Run in Iockdown screws Test tubing to 3000 psi-15 min. OK. Test 7" x 3-1/2" annulus to 3000 pSi-15 w/500 psi on tubing OK. Open shear valve in bottom GLM Freeze protect well w/60 bbl diesel down annulUs and let U-tube back to tubing Blow down lines L/D landing jt. Install BPV and L/D tubing tongs Pull strip-o-matic off hole..Blow down choke/kill lines and pumps Change bottom PR's from 4" to 4-1/2" x 7" VBR's. Change TDS over to 5" N/D BOPE and P/U tree. N/U Xmas tree and test packoff Attempt to pull BPV. Finish freeze protecting injection well. Wait on lubricator P/U and install lubricator. Pull BPV. Bled pressure off. Put tubing and annulus in communication. Install lubricator and install 2-way check. Test tree to 5000 psi. PUll .......... .--2~way .check--and .instalI-BPV...... haydown.-lubricator.and-secure.well;--Releaserig @ 08:30 hrs 3-27-01 DEFINITIVE Kuparuk River Unit North Slope, Alaska Kuparuk 1J Pad, Slot 1J-09 1J-09 Job No. AKZZfO090, Sun, eyed: 23 April, 2001 SURVEY REPORT 9.April, 200f '! Your Ref: APl 500292300600 Surfac~ Coordinates: 5945963.35 N, 558634.61 E (70° fS' 46.5826" N, 149° 3f' 33.5526" W) Kelly Bushing: f f 5.05ft above Mean Sea Level I~IRIL. L.I N (~' SEFlulCE~ A HIIIIburlon company Survey Ref: svy9413 Kuparuk River Unit Measured Depth Incl. 0.00 0.000 196.10 1.040 288.15 0.950 376.10 2.500. 464.72 5.250 Azim. 0.000 247.270 292.590 328.960 339.740 560.13 6.840 343.180 655.68 -8.430 345.930 748.57 10:140 347.310 841.12 12.970 348.030 935.15 14.300 347.300 1028.33 15.430 1121.59 18.030- 1222.58 19.550 1333.21 21.550 1428.14 24.780 345.910 343.730 342.660 340.810 341,150 1522.99 28.260 342.750 1621.05 31.220 342.470 1712.98 36.430 344.290 1806. il- 41.410 345.050 1899.09 44.710 346.170 1991.95 '- 47.490 345.090 2083.39 49.660 344.450 2176.41 52.690 342.410 2271.01 54.590 342,660 2363.16 55.570 343.070' 2455.20- 53.880 341.650 2554.28 53.530 341.620 26;46.63 52.460 341.990 2740.39 53.050 341.220 2836.03 52.820 340.720 Sub-S~a Dept~ (fi) -115.05 81.04 173.08 260.~9 349.z'D 444.;7 538.87 630.64 721.31 812.69 902.75 992.05 1087.~6 1278.51 1363.~7 1448.50 1524.85 1597.28 1665.21 1729.59' 179o.~9 1848,40 1904.~9 1957.23 2010.89 2069.04 2124.~2 2181,37 2239.bl Sperry-Sun Drilling Services surVey Report for f J-09 Your Ref: APl 500292300600 J°b No. AKZZfO090, Surveyed: 23 Aprfl, 200f Vertical Depth (ft) 0.00 196.09 288.13 376.04 464.45 559.32 654.02 745.69 836.36 927.74 1017.80 1107.10 1202.71 1306.29 1393.56 1478.42 1563.55 1639.90 .1712.33 1780.26 1844,64 1905.14 1963.45 7o19.54 2072.28 2125.44 2184.09 2239.67 2296.42 2354.06 Local Coordinates Northings. (ft) . - 0.00 N 0.69 S 0.72 S 1.21 N 6.67 N Global Coordinates Eastings Northings Eastings (ft) ' (ft) (ft) 0.00 E 5945963.35 N 558634.61. E 1.64W 5945962.65 N 558632.97 E 3.12W 5945962.61 N 558631.50 E 4.78W 5945964.52 N 558629.82 E 7.18W 5945969.96 N 558627.38 E 16.20 28.44 43.03 61.14 82.79 10.34W 5945979.47 N 558624.15 E 13.69W 5945991.68 N 558620.70 E 17.14W 5946006.24 N -558617.14 E 21.08W 5946024.32 N 558613.05 E 25.82W 5946045.94N 558608,14 E 106,04 131.93 163.07 199.93 235.23 31.37 W 38.44 W 47.85 W 60.05 W 72.21 W 275.5O 321.91 370.94 427.35 488.84 85.29W 99.84W 114.41W 129.86W 145.61W 553.65 N 619.80 N 689.23 N 761.90 N 834.!0 N 905.71N 981,50 N 1051.56 N 1122.38 N 1194.52 N 162.23 W 180,25 W 200.94 W 223.80 W 246.06 W 268.82 W 293.98 W 317.01 W 340.56 W 365.44 W 5946069.14 N 558602.41 E 5946094.98 N 558595,15 E 5946126.04 N 558585.49 E 5946162.80 N 558573.01 E 5946198.01 N 558560.57 E 5946238.18 N 558647.17 E 5946284.48 N 558532.27 E 5946333.39 N 558517.31E 5946389.68 N 558501.43E 5946451.04 N 558485.20 E 5946515.72 N 558468.07 E 5946581.72 N 558449.54 E 5946651.00N 558428.31E 5946723.48 N 558404.89 E 5946795.51N 558382.07 E 5946866.94N' 558358.75 E 5946942.53 N 558333.00E 5947012.41N 558309,43 E 5947083.04 N 558285.32 E 5947154.99 N '558259.88 E DEFINITIVE North Slope, Alaska Kuparuk 1J Pad Dogleg Rate ('/'f00ft) 0.53 0.84 2.07 3.20 Vertical Section 0.00 -0.17 0.24 2.57 8.49 Comment AK-6 BP IFR-AK 1.71 1.71 1.86 3.06 1,43 1.27 2.87 1.54 1.90 3.41 3.75 3.02 5.77 5.37 3.64 3.11 2.43 3.68 2.02 1.12 2.23 0.35 1.20 0.91 0.48 18.54 31.22 46.17 64.64 86.72 110.57 137.40 169.92 208.74 246.06 288.40 337.04 388.19 446.64 510.03 576.85 645.37 717.82 794.00 869.56 944.69 1024.53 1098.27 1172.89 1249.17 9 April, 200f - 9:3f Page 2 of 6 DrillOuest 2.00.08.005 Kuparuk River Unit . Measured Depth Incl. (ft) Azim. 2930.31 53.620 341.990 3024.37 56.000 340.650 3117.32 57.800 340.710 3212.25 57.190 340.760 3302.43 57.290 341.190 3401.72 57.160 3493.38 56.310 3585.70 55.620 3678.98 .56.940 3772.57 57.330 341.160 340.850 341,810 344.430 344.520 3867.30 56.410 343.730 3961.27 56.210 344.470 4055.66 '56.080 344,400 4151.39 55.840 344.460 4243.50 55.830 344.560 4337.53 55.330 345.190 4432.49 54.970 344.770 4527.26 54.400 345.980 4620.02 53.870 345.200 4714.77 53.660 344.810 4810.09 4902.33 4997.27 5091.91 5184.34 53.610 345.080 53.950 344.390 54.310 343.270 :54.320 342.570 54.360 341.600 5279.30 55.040 341.660 5373.81 54.830 339.630 5467.93 53.980 339.900 5567.81 53.770 339,660 5728.58 53.580 339.130 Sub-Sea Depth, 2400,42 2451.4~ 2500.~3 2553.9'8 2604.2~6 2655.~3 2707.92 2758.5;1 2810.2,18 2862.41 2914.~9 2968.~8 3020:31 3073.46 3127.72. 3182.50 3236.85 3292-i6 3349.38 3403.88 3459.,~1 3514.,72 3568-i0 3623 8 'i 3677.78 ' '3732.56 3791.44 3886.68 Vertical Depth (ft) 2410.51 2464.72 2515.47 2566.49 2615.28 2669.03 2719.31 2770.98 2822.77 2873.56 2925.33 2977.46 3030.04 3083.63 3135.36 3188.51 3242.77 3297.55 3351.90 3407.91 3464.43 3518.93 3574.56 -3629.77 3683.65 3738.53 3792.83 3847.61 3906.49- 4001.73 Sperry-Sun Drilling Services Survey Report for 1J.0'9 Your Ref: APl 500292300600 Job No. AKZZlO090, Surveyed: 23 April, 2001 Local Coordinates Global Coordinates Northings - Easfings Northings Eastings (ft) (ft) (ft) (ft) !266.07 N 1338.88 N -i412.36 N 1487.93 N 1559.63 N 389.58W 5947226.35 N 558235.18 E 414.21W 5947298.96 N 558209.99 E 439.97W 5947372.24N 558183.66 E 466.38W 5947447.61N 558156.65 E 491.11W 5947519.11N 558131.37 E 1638.65 N · 1711.11 N 1783.59 N 1857.82 N 1933.57 N. 2009.87 N 2085.07 N 2160.58 N 2236.99 N 2310.44 N 2385.32 N 2460.58 N 2535.41 N 2608.21 N 2682.04 N 2756.16 N 2827.95 N 2901.83 N 2975.31 N 3046.77 N 518.04W 5947597.91N 558103.82 E 542.99W 5947670.18 N 558078.31E 567.48W 5947742.47 N 558053.26 E 589.99W 5947816.52 N 558030.17 E 611.03W 5947892.10 N 558008.54E 632.73W 5947968.23 N 557986.25 E 654.15W 5948043.26 N 557964.24 E 675.18W 5948118.60 N 557942.62 E 696.48W 5948194.85 N 557920.74E 716.83W 5948268.14 N 557899.81E 737.07 W 5948342.86 N 757.27 W' 5948417.96 N 776.79 W 5948492.63 N 795.50 W ' 5948565.29 N 815.27 W 5948638.96 N 835.21W 5948712.92 N 854.80W 5948784.55 N 876.23W 5948858.27 N* 898.81W 5948931.57 N 921.91W 5949002.85 N 3120.32 N 3193.30 N 3265.11N 3340.81N 3462.05 N 946.33W 5949076.21N 971.96W 5949148.98 N 998.44W 5949220.58 N 1026.32W 5949296.07 N' 1071.90W 5949416.95 N 557878.99 E 557858.21E 557838.10 E 557818.83 E 557798.48 E .. 557777.96E 557757.81E 557735.81E 557712.68E 557689.01E 557664.01E 557637.81E 557610.78 E 557582.31E 557535.78 E Dogleg Rate {°llOOft) 1.37 2.79 1.94 0.64 0.42 0.13 0.97 1.14 2.73 0.42 1.20 0.69 0.15 0.26 0.09 0.77 0.52 1.20 0.89 0.40 · 0.23 0.71 1.03 0.60 0.85 0.72 1.77 0.93 0~29 0.29 North Slope, Alaska KuparUk 1J Pad Vertical Section Comment 1324.65 1401.49 1479.30 1559.31 1635.11 1718.56 1795.16 1871.64 1949.21 2027.79 2107.09 2185.26 2263.61 2342.91 2419.09 2496.60 2574.47 2651,72 2726.80 2803,17 2879.87 2954.24 3031.16 3108.03 3183.12 3260.60 3337.90 3414.33 3494.89 3624.19 9 April, 2001 - 9:31 .Page 3 of 6 DrillQuest 2.00.08.005 - Kuparuk River Unit .. Measured Depth Incl. Azim. 5818.78 53.260 338.970 ' 5915.29 54.520 341.120 6010.78 54.250 341.750 6105.19 54.570 342.790 6197.91 54.400 342.330 6291.57 55.640 343.620 6386.32 55.270 343.700.. 6480.06 54.980 343.550 6574.68 54.790 343.700 . 6665.90 54.440 343.210 6761.10 54.230 343.510 6857.55 54.550--344.980 6946.57 54.080 344.790 '7003.72 53.550 344.900 7141.26 53.410 344.800 7233.75 54.990 345.640 7326.48 54.640 345.020- 7420.95 55.310 345.760 7514.83' 54.820 345.040 7610.57 54.670 345.180 7700.23 54.230 7795.92 54.080 7891.59 54.300 7985.79 53.620 8078.04 54.040 8171.73 8265169 8359.93 8455.67' · 8547.39 53.030' 52.980 53.360 54.370 56.270 346.310 345.900 342.580 342.240 340.560 340.390 339.120 337.680 336.900 336.740 9 April, 2001 - 9;31 Sub-Sea Depth! (fi) i 3940.43 3997.3i 4052.92 4107.8~ 4161,77 .I 4215,42 4269.1~ 4322.75 4377.1~ 4430.03 4485.51 4541.{7 4593.{9 4650.(:5 4709.(0 4763.~0 4816.53 4870.~5 4924,~1 4979.18 5o31.91 5087,94 5143,93 5199.85 5253,8O 5309.i8 5366.02 5422.51 5478.97 5531.16 Vertical Depth' (ft) 4055.48 4112.36 4167.97 4222.91 4276.78 4330.47 4384.20 4437.80 4492.23 4545.05 4600.56 4656.72 4708.64 4766.00 4824.05 4878.15 4931.58 4985.80 5039.56 5094.83 5146.96 5202.99 5258.98 5314.40 5368.85 5424.53 5481.07 5537.56 5594.02 5646.21 Sperry. Sun Drilling Services Survey Report for IJ.09 Your Ref: AP1500292300600 Job No. AKZZfO090, Surveyed: 23 April, 200f Local Coordinates Northings (ft) 3529.70 N 3602.98 N 3676.57 N 3749.70 N 3821.70 N GlObal Coordinates Easfings Northings Easflngs (ft) (ft) (ft) 1097.80 W 5949484.39 N 557509.36 E 1124.40 W 5949557.47 N 557482.19 E 1149.11 W 5949630.86 N 557456.90 E 1172.49 W 5949703.80 N 557432.96 E 1195.11 W 5949775.62 N 557409.78 E 3895.07 3969.96 4043.75 4118.01 4189.30 1217,57W 1239,53W 1261,21W 1283,03W 1304,21W 4263.40 4338.87 4408.67 4464.36 4560.02 1326.35 W 1347.64 W 1366.50 W 1387.00 W 1407.48 W 4632.55 4705.87 4780.73 4855.20 4930.76 5001.46 5076.76 5151.40 5224.01 5294.59 5365.60 5436,01 5506.14 5577.46 .5646.80 N. N N N N 1426.61 W 1445.80 W 1465.32 W 1484.71 W 1504.80 W 1522.77 W 1541.39 W 1562.47 W t585.48 W 1609.24 W 1634.42 W- 1660.39-W 1688.16 W 1718.01 W 1747.70 W 5949848.82 N 5949923.54N 5949997.16 N 5950071,24N 5950142.37 N 5950216.30 N 5950291.59 N 5950361.25 N 5950436.77N 5950512.27 N . 5950564.65 N 5950657.82 N 5950732.52 N 5950806.85 N 5950882.24 N 5950952.80 N 5951027.95 N 5951102.43 N- 5951174.86 N 5951245.25 N 5951316.06N- 5951386.27 N 5951456.18 N -5951-527.27 N 5951596.37 N 557386.75 E 557364.21E 557341.95 E 557319.55E 557297.82 E 557275.10 E 557253.22 E 557233.83E 557212.74 E 557191.66 E 557171.97 E 557152.20 E 557132.11E 557112.13 E 557091.46E 557072.94E 557053.73 E 557032.08 E 557008.50 E 556984.19 E 556958.46 E 556931.94 E 556903.63 E 556873.22 E 556842.99 E Page 4 of 6 North Slope, Alaska Kuparuk 1J Pad Dogleg Vertical Rate Section Comment (°llOOft) 0.38 3696.47 2.22 3774.35 0.61 3851.95 0.96 3928.72 0.44 4004.19 1.74 0.40 0.34 0.24 0.58 0.34 1.28 0.56 0.55 0.17 1.86 0.66 0.96 0.82 0.20 1.14 0.38 2.82 0.78 1.54 1.09 1.08 1.29 1.24 2.08 4080.93 4158.96 4235,86 4313.25 4387,61 4464.95 4543.34 4615.59 4693.95 4772.29 4847.23 4922.94 5000.22 5077.10 5155.22 5228,07 5305.50 5383.04 5459.21 5533.66 5608.94 5683.88 5759.09 5836.05 5911.07 DrillQl~est 2.00.08.005 Sperry-Sun Dr#ling Services Survey Report for f J.09 Your Ref: AP1500292300600 Job No. AKZZfO090, Surveyed: 23 April, 200f Kuparuk RiVer Unit Measured Sub-Sea Vertical Depth Incl. Azim. Depth i Depth (ft) (ft) (ft) 8641.66 55.620 336.460 5583.95 5699.00 8734.27 55.120 336.600 5636.5'~ 5751.62 8829.54 55.280 337.570 5690.9~ 5806.00 8924.29 54.730 338.290 5745.29 5860.34 '9016.71 55.820 341.070 5797.9~ 5912.99 · ~ 9111.12 57.560 343.100 5849.79 5964.84 9234.90 57.450 344.020 5916.29 6031.34 9334.88 57.910 343.980 5969.7~4 6084.79 9430.05 -58.730 344.540 6019.72 61 34.77 9521.69 59.310 343.910 .6066.8~) 6181.94 / 9619.45 59.150 344.990 6116.9'1 9716.49 59.140 344.720- 6166.6~8 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 5718.48 N 1778.72 W 5951667.80 N 556811.42 E 5788.37 N 1809.06 W 5951737.46 N 556780.53 E 5860.43 N 1839.52 W 5951809.28 N 556749.51 E 5932.36 N 1868.69 W 5951880.98 N 556719.78 E 6003.58 N 1895.05 W 5951952.00 N 556692.87 E 6078.65 N 1919.31 W 5952026.87 N 556668.03 E 6178.78 N 1948.85 W 5952126.77 N 556637.70 E 6260.00 N 1972.14 W 5952207.80 N 556613.78 E 6337.95 N 1994.11 W 5952285.58 N 556591.21 E 6413.56 N 2015.47 W 5952361.02 N 556569.26 E 6231.96 6281.73 6298.79 6349.95 6685.61N Directions and coordinates 9749.83 59.290 344.740 6183.~4 9850.00 59.290 344.740 6234.g0 All data is in Feet unless otherwise state!. Vertical depths are relatiVe to .Well. Nor~hings and Eastings are relative t° Well. - Magnetic Declination at Surface is 26.24~° (08-Mar-01) The Dogleg Severity is in Degrees per 1~)0 feet. Vertical Section is from Well and calculaied along an Azimuth of 342.770° (True). Based upon MinimUm Curvature type caiculations, at a Measured Depth of 9850.00ft.,' The Bottom Hole Displacement is 7004.~7ft., in the Direction of 342.640° (True). ' .i 6494.48 N 2037.99W 5952441.76 N 556546.11E 6574.89 N - 2059.75W 5952522.01N 556523.72 E 6602.52 N 2067.30W 5952549.58 N 556515.96E 2089.96W 5952632.48 N 556492.65 E are relative to True North. Dogleg Rate (°~lOOft) 0.73 0.55 0.85 0,85 2.74 2.57 0.63 0.46 1.00 0.86 0.96 0.24 0.45 0.00 North Slope, Alaska Kuparuk 1J ·Pad Vertical Section Comment 5988.72 6064.47 6142.32 6219.66 6295.49 6374.38 6478.77 6563.24 6644.20 6722.74 6806.70 6889.95 6918.58 7004.65 Projected Survey DrillQuest 2.00.08.005 9 April; 200f - 9:3f Page 5of6 Sperry-Sun Drilling Services Survey Report for f J.09 Your Ref: AP1500292300600 Job No. AKZZf~90, Surveyed: 23 April, 2001 Kuparuk River Unit Comments ~ ' Measured StatiOn Co!ordinates Depth TVD Northin~ls Easfings (ft)' (ft) (ft) r (ft) · 9850.00 6349.95 . 6685.6,! N 2089.96 W . Comment Projected Survey Survey tool program for f J-09 . From MeasUred Vertical Measured Vertical Depth Depth Depth Depth (ft) (ft) -(ft) (ft) 0.00 0.00 9850.00 Survey Tool Description 6349.95 AK-6 BP_IFR-AK North Slope, AlaSka Kuparuk 1J Pad -. 9 April, 2001 - 9:3~ Page 6 of 6 DrillOuest 2.00.08.005 Permit to Drill 2010440 MD 9850''-'~ TVD DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. KUPARUK RIV UNIT 1J-09 Operator CONOCOPHILLIPS ALASKA INC 6350 ~'~Completion Dat 6/7/2001--~ Completion Statu 1-OIL Current Status 1-OIL APl No. 50-029-23006-00-00 UIC N REQUIRED INFORMATION Mud Log N._~o Sample N__~o Directional Survey No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Data Digital Digital Type Me~r Fmt (data taken from Logs Portion of Master Well Data Maint) Interval Log Log Run OH / Dataset Name Scale Media No Start Stop CH Received Number Comments 67 9766 Case 5/1/2001 ',~)'t~21 67-9766 _~TOj21 FINAL 67 9766 OH 5/1/2001 ~'t21 67-9766 Digital Data LIS Verification FINAL CH 5/1/2001 LIS Verification ~D GPJ BAT 2/5 FINAL 120 9850 OH 6/11/2001 120-9850 BL, Sepia --~IE~ GPJ BAT 2/5 FINAL 120 9850 OH 6/11/2001 120-9850 BL, Sepia .-~GR/NEU/DEN 2/5 FINAL 120 9850 OH 6/11/2001 120-9850 ~ GR/RES 2/5 FINAL 120 9850 OH 6/11/2001 120-9850 BL, Sepia ~7t~) GPJ NEU/DEN 2/5 FINAL 120 9850 OH 6/11/2001 120-9850 BL, Sepia Cement BOnd Log/ 5 FINAL 8840 9728 CH 7/13/2001 8840-9728 Color Print SCMT-N PSP Well Cores/Samples Information: Name Interval Dataset Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? ~/N ~ ~'__JJ ~' ~"~-~% Analysis ~Y~N .~J~.-~?' ~.~.~j/~.~ Daily History Received? ~ Formation Tops (~ N Comments: Permit to Drill 2010440 DATA SUBMITTAL COMPLIANCE REPORT 61412003 Well Name/No. KUPARUK RIV UNIT 1J-09 Operator CONOCOPHILLIPS ALASKA INC APl No. 50-029-23006-00-00 MD 9850 'i'VD 6350 Completion Dat 6/7/2001 Completion Statu 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Annular Dis ~osaI durin the second quarter o ~ 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date / 1C-17 33139 100 0 33239 0 33239 May 01 Jun 01 1C-133, lC-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar 01 May 01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May 01 Jun 01 CD2-24 1C-27 3533 -100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli for which Dis ~osal Authorization Expired during the second quarter 2001' ~ ' Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus ~ 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 ' 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- ~/ 2000 35, CD1-32, CD1-24, CD 1-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD 1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only - CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD 1-NQ1 Annular Disposal during the second quarter of 2002: h(1) h(2) h(3) Total for Freeze Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Protect Total Total Date Date Volumes CD2-15 10176 100 0 10276 371 10446 21093 March April CD2-25, CD2-50 2002 2002 2P-420 9479 100 0 9579 150 0 9729 April May 2002 2P-427, Heavenly 2002 2P-415A 26238 100 0 26338 52 4943 31333 March April 2P-431, 2P-422A, 2P-427, 2002 2002 Heavenly, Grizzly, 2P-441 CD2-49 27474 100 0 27574 386 0 27960 April May 2002 CD2-46, CD2-22, CD2-50 2002 CD2-17 14962 100 0 15062 372 0 15434 May 2002 June 20O2 CD2-48, CD2-46 1D-11 32102 100 0 32202 235 0 32437 May 2002 June 2002 1D-103 CD2-32 18536 100 0 18636 379 0 19015 June 2002 June 2002 CD2-19, CD2-41 1C-18 4176 100 0 4276 379 0 4655 June 2002 June 2002 1C-104 Total Volumes into Annuli for which Disposal Authorization Expired during the second quarter 2002: Freeze P~otect To~al Volume " Start End Source Wells Total h(1) Total h(2) Total h(3) Fluids Injected- Date Date Well Name Volume Volume Volume Volume Status of Annulus 1J-09 24202 100 0 330 24632 Open, Freeze Protected May 2001 May 2001 1J-10 1C-17 33139 100 0 160 33399 Open, Freeze Protected May 2001 June 2001 1C-133, 1C-121, 1C- 123, 1C-127 CD2-42 33507 100 0 385 33992 Open, Freeze Protected June 2001 October CD2-24, CD2-33, ~CD2- 2001 15 2P-417 30965 100 0 887 31952 Open, Freeze Protected October March 2P-422, Grizzly, 2P-451, 2001 2002 2P-441, 2P-448, 2P- 422A, 2P-420 1C-27 31766 100 0 153 32019 Open, Freeze Protected June 2001 July 2001 1C-127, lC-117, 1C- 111, 1C-123 Well 1J-09 Sidewall Core Descriptions Sample ID 32863A 32865 32866 32868 32869 32871 32872 32873 32874 32875 32876 Depfll (~.) 4826 4838 4842 4907 4915 4926.5 4934 4938 4945 4952 4958 B v-frae sand = 0.062-0.125, silt = 0.004-0.062, clay = <0.004 Zone D D D 32877 4976.5 A4 32878 4982 A4 32879 4987 A4 32880 4993 A4 32881 4998 A4 32882 5002 A4 32883 5008 A4 32884 5012 A4 32885 5032 A4 32886 5038 A4 32887 32888 32889 32890 32891 32892 32893 32894 32895 5053 5058 5061 5075 5081 5095 5105 5128 5133 5164 5168 5171.5 5178 5183 5222 5228 5233 5238 32896 32897 32898 32899 32900 32901 32902 32903 32904 Description Color: med. brown; Grain Size: v. frae sand with silt - one 3 mm black gram Color: grayish brown; Grain Size: silt with v. fine sand, no fizz Color: med. brown; Grain Size: silt with v. fine sand and clay, no fizz Color: grayish brown; Grain Size: silt with clay; trace fine-size black gms Color: grayish brown; Grain Size: clay and silt Color: med. brown; Grain Size: silt with clay Color: med. brown; Grain Size: silt Color: med. brown; Grain Size: silt with clay B Color: med. brown; Grain Size: silt B Color: grayish brown; Grain Size: clay. Color: gray; Grain Size: clay Color: gray; Grain Size: clay Color: grayish brown; Grain Size: clay: Color: grayish brown; Grain Size: clay Color: gray; Grain Size: clay Color: gray; Grain Size: clay; mica (?) present Color: gray; Grain Size: clay; mica (?) present Color: gray; Grain Size: clay; mica (?) present Color: grayish brown; Grain Size: silt with clay Color: gray; Grain Size: clay Color: gray; Grain Size: clay A3 Color: med. gray to light brown; Grain Size: silt with strands of hair-like substance A3 Color: med. gray to light brown; Grain Size: silt A3 Color: light brown silt grains in a med. gray clay matrix A3 Color: light brown and gray; Grain Size: silt A3 Color: light brown and gray; Grain Size: silt in clay matrix A3 Color: dark gray clay with brown silt clasts A3 Color: light to med. brown; Grain Size: very f'me A3 Color: light to med. brown; Grain Size: very fine A3 Color: med. gray clay with brown silt particles A2 yellowish brown, very fine, black specs-silt size A2 A2 A2 A2 A2 A2 A2 A2 Color: yellowish brown; Grain Size: very fine Color: yellowish brown, very fine, white strands Color: yellowish brown; Grain Size: very fine, mica flakes Color: white gray, clay, white strands Color: gray clay with 20% light brown silt Color: yellowish brown; Grain Size: very f'me Color: yellowish brown; Grain Size: very fine Color: gray; Grain Size: clay PH,..LIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 C. R. Mallary Phone (907) 265-6434 Fax: (907) 265-6224 October 15, 2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7t~ Avenue Suite 100 c~.~\ Alaska Anchorage, 99501 Subject: Core Descriptions for Wells 1I'03, 1J-09 and 1D-107 Dear Commissioner: Phillips Alaska, Inc. submits the attached core descriptions for the Kuparuk wells 1J-03, 1J-09 and the West Sak well 1D-107. These repons follow the completion reports which we submitted earlier this year. If there are any questions, please contact Sharon Allsup-Drake at 263-4612. Sincerely, C. R. Mallary Drilling Engineering Supervisor Phillips Drilling CRM/skad RECEIVED O~T 1 6 ~001 Alaska 0it & Gas C0ns' Commisai°n A~ch~age PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 31, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 o) 2oo! Alasl~a 0i/~ gas Cons. Anchorage C°rnroisSioo Re: Kupamk Area Annular Disposal, Second Quarter, 2001 - REVISED Dear Ms. Mahan: Please find attached the revised report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. We have revised the amount for CD2-42 because the original manifest incorrectly reported the CD2-24 annulus used for the disposal. Please call me at 263-4603 should you have any questions. Sincerely, : Paul Mazzolini Drilling Team Leader PM/skad CC'. Marry Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Annular Disposal durin the second quarter °f 2001: h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun01 1c-133, 1c-121, 1c-i23, 1c-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-3021 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, U-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 18034 100 0 18134 0 18134 May01 Jun 01 CD2-24 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Zoo Total Volumes into Annuli for which DiSPosal Authorization Expired during the second quarter 2001: Total Voiume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume VOlume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD 1-32, CD 1-24, CDI-22A, CD1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 IT! PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 P. Mazzolini Phone (907) 263-4603 Fax: (907) 265-6224 July 17, 2001 Ms. Wendy Mahan Natural Resource Manager Alaska Oil and Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Re: Kupamk Area Annular Disposal, Second Quarter, 2001 Dear Ms. Mahan: Please find attached the report with the volumes disposed into surface casing by production casing annuli during the second quarter of 2001, as well as total volumes disposed into annuli for which disposal authorization expired during the second quarter of 2001. Please call me at 263-4603 should you have any questions. Sincerely, Paul Mazzolini Drilling Team Leader PM/skad CC: Marty Lemon Mike Mooney Paul Mazzolini Randy Thomas Chip Alvord Scott Reynolds Kuparuk Environmental: Engel / Snodgrass B. Morrison and M. Cunningham Sharon Allsup-Drake Well Files RECEIVED JUL 1 9 2001 Alaska Oil & Gas Cons. Commission Anchorage Dis 9osal durin yhe second ,uarter r 2001' h(1) h(2) h(3) Total for Previous New Start End Source Wells Well Name Volume Volume Volume Quarter Total Total Date Date 1C-17 33139 100 0 33239 0 33239 May01 Jun 01 1C-133, 1C-121, 1C-123, 1C-127 2N-318 2883 100 0 2983 13995 16978 Dec 00 Jun 01 2N-302, 2N-314, 1J-03 16904 100 0 17004 13120 30124 Mar01 May01 1J-09, 1J-14, 1J-10 1J-09 24202 100 0 24302 330 24632 May 01 May 01 1J-10 CD2-42 16902 100 0 17002 0 17002 May 01 Jun 01 CD2-24 ,_ 1C-27 3533 100 0 3633 0 3633 Jun 01 Jun 01 1C-127 Total Volumes into Annuli ~or ~hich Dis ~osal Authorization Ex 9ired during the second quarter 2001' Total Volume Start End Source Wells Total h(1) Total h(2) Total h(3) Injected Date Date Well Name Volume Volume Volume Status of Annulus 1D-11 135 100 0 235 Open, Freeze Protected June 2000 June 2000 1D-38 1D-14 35404 100 0 35504 Open, Freeze Protected June 2000 July 2000 1D-38, 1D-30 CD1-25 33487 100 0 33587 Open, Freeze Protected June 2000 August CD1-06, CD1-40, CD1- 2000 35, CD1-32, CD1-24, CD 1-22A, CD 1-43 CD1-41 280 100 0 380 Open, Freeze Protected March 2000 March Freeze protected down 2000 CD1-41 only CD1-34 278 100 0 378 Open, Freeze Protected May 2000 May 2000 Freeze protected down~_~ CD1-34 only CD1-44 31828 100 0 31928 Open, Freeze Protected Dec 2000 Jan 2001 CDI-10, CD1-28, CD1- 33, CD1-NQ1 PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4135 Fax: (907) 265-6224 July 19, 2001 Mr. Steve Davies State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1J-09 (201-044) Dear Mr. Davies: Please find attached the additional information you requested for the perforation operations for Kupamk well 1J-09. If you have any questions regarding this matter, please contact me at 263-4135 or Brian Noel at 265- 6979. S incere~ ... /~) Interim Drilling Engineering Supervisor PA1 Drilling TAB/skad JUL ~ ~ 20o~ Alaska Oil & Gas Cons, Anchorage Commission Date 06/07/01 Well Na 1J-09 Service Type ELECTRIC LINE Desc of Work PERF Supervisor RIEDEL Complet ~ Accident r Injury F Spill F Summary Upcoming F Job Num 0428011324.1 Unit SWS 2145 AFC AK0149 0 Prop 230DS10J Uploaded to Ser Contractor Key Perso SWS-GARCIA Successful r~ Initial Tbg Press 2200 Initial Int Csg Press 550 Initial Out Csg Press 800 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PERF 9620-9650 WITH 2 1/5" GUN, 6SPF, 60 DEG PHASED, ALTERNATING DP (PENT:17.3",HOLE DIA:0.62") AND BH (PENT 5.8", H DIA:0.62") CHARGES. RECEIVED JUL 1 9 Z00 Alaska Oil 8, Gas Cons. Commission Anchorage Date printed: 07/19/01 at: 08:32:27 SENT BY' , Phone: 263-4612 77,18- 1 ' 8'40~k~1 ' PHILLIPS AK INC~ 907 276 7542'g 1/ 2 Fal To: Mr. ,Steve Davies From: Sharon AIIsup-Dmke Fax= 9-907-276-7542 Date: July 19, 2001 Phon~ 793-1224 Pages: 1 Re: 1J-09 completion report [] Urgent D For Review I~ [] Please Cemmmlt' [] Pleaae Reply [] Please Recycle ... :l' -Comments: ) Mr. Davies Here is the additional information you requested for 1J-09..If you have any questions, please feel free to call me at 263-4612, Thanks, Sharon RECEIVED JUL 1 9 200 Oil & Gas Cons. t;orqm~smo~ .4nchorage SENT BY' Data O6/07/01 · Well Nc] 1J-09 $orvloo Type ELECTRIC LINE De$¢ of Work PERF SupenAsor RIEDEL Campier r~ Accident r- Injury J- spin r- Summary 7-19- 1 ' 8:40A~1 ' PHILLIPS AK INC--,- U¢comino I"- Job Num 0428011324.1 AFC AK0149 Unit SWS 2145 0 907 276 7542'# 2/ 2 Prop 230DS10J* Uploaded to Sen Contractor Key Perso SWS-GARCIA Successful r~ initial Tbg Press 2200 Initial Inf Csg Press 550 Initial Out Csg Press 800 Final Tbg Press 0 Final Int Csg Press 0 Final Out Csg Press 0 PERF 9620-9650 WITH 2 1/5" GUN, 6SPF, 60 DEG PHASED, ALTERNATING,DP (PENT:I 7.3",HOLE DIA:0.62") AND BH (PENT 5,8", Hi DIA:0,62") CHARGES, Date printed: 07/19/01 at: 08:32:27 , PHILLIPS Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 T. Brockway Phone (907) 263-4135 Fax: (907) 265-6224 July 13,2001 Commissioner Cammy Oechsli Taylor State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Completion Report for 1J-09 (201-044) Dear Ms. Commissioner: Phillips Alaska, Inc. submits the attached Completion Report for the drilling operations on the Kupamk well 1J-09. If you have any questions regarding this matter, please contact me at 263-4135 or Todd Mushovic at 265-6974. Interim Drilling Engineering Supervisor PAI Drilling TAB/skad RECEIVED JUL 1 6 ~001 Alaska Oil & Gas Cons. Commission Anchorage ( STATE OF ALASKA ~, ALASr,,A OIL AND GAS CONSERVATION COM ,aSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of well Classification of Service Well Oil ['~ Gas E~ Suspended 2. Name of Operator 7. Permit Number Phillips Alaska, Inc. 201-044 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510-0360 50-029-23006-00 4. Location of well at sudace 2152, FSL, 2574, FEL, Soc. 35, T11N, R1OE, UM (ASP:558635,5945963)~ iY"l"":P~r'F;'q'~J [ [,O~TT~~i'Unit°rLeaseName ..... Kuparuk River Unit At Top Producing Interval ~ ,_~.'_z_- .~./.E--P / O. Well Number 1943' FNL, 683' FWL, Sec. 26, T11N, R10E, UM (ASP: 556554, 5952414) :~ V~ :.~ ~! lO-09 At Total Depth ~ ..... 1. Field and Pool 1724' FNL, 624' FWL, Sec. 26, T11N, R10E, UM (ASP: 556493, 5952632) ~, ........ Kuparuk River Field 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Kuparuk River Pool RKB29.6' feetI ADL25661 ALK 471 12. Date Spudded 13. Date T.D. Reached .14. Date Comp., Susp. Or Aband. 115. Water Depth, if offshore 16. No. of Completions March 8, 2001 March 23, 2001 "J~~2001/J"~'A' ,,~ 7z I N/A feet MSL 1 17. Total Depth (MD + TVD) 18. Plug Back Depth (MD + TVD) 19. Directional Survey 120. Depth where SSSV set 21. Thickness of Permafrost 9850' MD / 6350' TVD 9739' MD / 6293' TVD YES ~] No r~'1 N/A feet MD 1602' (approx) 22. Type Electric or Other Logs Run GR/Res/Neu Dens, CCL 23. CASING, LINER AND cEMENTING RECORD SETTING DEPTH MD i CASINGSlZE VVT. PERFT. GRADE TOP BOTTOM HOLE SIZE CEMENTINGREOORDi AMOUNT PULLED 16" 62.58# H-40 Surface 115' 24" 460 sx AS I 9.625" 36# J-55 Surface 5639' 12.25" 653 sx AS Lite & 340 sx LiteCRETE 7" 26# L-80 Surface 9198' 8.5" 184 sx Class G 3.5" 9.3# L-80 8981' 9807' 6.125" 196 sx Class G 24. Per/orations open to Production (MD + TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5" 9026' 8988' 9620'-9650' MD 6232'-6248' TVD 6 spf 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 9620'-9650' 113M# proppant behind pipe, 9.2 ppa on per/s, left 26M# in wellbore 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) Flowing Date ot Test Hours Tested Production for OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-O!L RATIO 6/26/2001 15 hrs Test Period > 873 6136 0 40I 7799 Flow Tubing Casing Pressure Calculated OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY - APl (corr) ~ress. 1950 psi N/A 24-Hour Rate > 1277 9957 0 24° 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and pressence of oil, gas or water. Submit core chips. RECEIVED To be sent under separate cover JUL 1 6 2001 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 7-1-80 CONTINUED ON REVERSE SIDE Submit in duplicate · ,, , GEOLOGIC MARKER . FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity. MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top 04 9586' 6215' Base Kuparuk C 9688' 6267' Top Kuparuk A 9850' 6350' Base Kuparuk A 9850' 6350' Annulus left open - freeze protected with diesel. 31. LIST OF ATTACHMENTS Summary of Daily Operations, Directional,.~urvey 32. I hereby ce~"~t/Ifat the follow,ng Is tme/a~d/~orrect to the best of my knowledge. Questions? Todd Mushovic 265-6974 Signed /'~'*~:""~;~'~."~ /~'"'~Y~~. Title Interim Drlllln,qErl,qnoedn.qSuporvlsor Date / Torn Brockway Prepared by Sharon Al/sup-Drake 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 the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 27.' Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, Other-explain. RECEIVED Item 28.' If no cores taken, indicate "none". Form 10-407 JUL Z Alaska 0il & Gas Cons. Commission Anchorage ~"' Operations Summary i~"' 1J-09 Rpt Date 03/07/01 12:00 AM 03/08/01 12:00 AM 03/09/01 12:00 AM 03/10/01 12:00 AM 03/11/01 12:00 AM 03/12/01 12:00 AM 03/13/01 12:00 AM Comments Prep. Rig for move, Jack up sub, Pull off well 1J-03, Lost drive press.& repair Drive sub around corner of location & spot over 1J-09, Lower cellar doors, Drive power module around corner & stage near sub, attach speader links to power module. Movepower module and merry up w/sub, Roll down cellar doors,Button up cellar Accept rig, Nipple up diverter stack, Spot ball mill Rig up diverter lines, Install lines in stair tower Change Breaker in SCR f/GEN #1, Work on prespud check list Pick up BHA tools to floor Function test Diverter system as per AOGCC Held presud meetings w/all crews, Perform prespud walk around &Check list Make up BHA, Fill Condutor Condition Cmt Contaiminated mud Drill f/115' to 322' o Drill f/322' to 1308' AST=5.5 hrs ART-4.0 hrs Pump sweep & Circ. clean POOH, Break bit Make up new bit, L/D Restrictor sub, Orient motor Down load sperry sun tools Change BHA (Pick up Neutron sub, ect.) Cut drilling line 65', Service rig R IH to 1308' Circ. BTM's up Drill f/1308' to 1322' AST=.25 hrs Drill f/1322' to 3390' ART=8 hrs. AST=8 hrs. Pump sweep, Circ. hole clean Circ. hole clean Monitor well, Dry pipe, Wipe hole f/3390' to 856' -mild swabbing f/2030' to 1800' (Pump out)-RIH, Work thru spot @ 2030', RIH-OK Circ. thick mud Drill f/3390' to 4870' ART-10.5 Hrs AST- 2.75 HRS Drill f/4870' to 5649' ART-6.75 Hrs AST--3.5 Hrs Pump sweep, Circ. hole clean POOH (SLM-No correction)- Hole in good shape Set back BHA, PJSM, Remove RA Sourses, L/D LWD, MWD, Motor, Bit Make up 12.25" Holeopener, BHA, RIH RIH w/Holeopener to 5649'- Hole in good shape Circ. Btm's up, Pump sweep around, Cond. mud POOH w/Holeopener Rig up Schlumberger wireline and TBG. Conveyed Sidewall cores RIH w/Core guns to 5238' Shoot 11 cores f/5238' to 5128' POOH w/Wireline L/D side entry sub, L/D 2 stands DP, ,P/U side entry sub, RIH w/wireline f/2nd latch 03/14/01 12:00 AM RIH w/wireline, latch wet connect Shoot 24 cores f/5105' to 4922', POOH w/wireline, L/D 2 stds DP, RIH w/wireline, Shoot 10 cores f/4915' to 4797', POOH w/wireline, L/D side entry sub Circ. Btm's up POOH (slow) w/sidewall cores Operations Summary 1J-09 03/15/01 12:00 AM 03/16/01 12:00 AM 03/17/01 12:00 AM 03/18/01 12:00 AM 03/19/01 12:00 AM 03/20/01 12:00 AM Remove cores f/core guns (45 total- 6 misfires- recovered 39), Rig down Schlumberger Service rig Make up Holeopener, RIH to 4780' Circ. Btm's up- Wash & Ream f/4780' to 5649' Pump sweep- Condition mud f/csg. Monitor well, Pump dry job, POOH w/Holeopener PJSM, Rig & run 9.625" csg. Change out o-ring on GBR fill up tool Finish running 9.625" csg. to 5639' ( took wt. @ 1800' & 4800') Make up FMC hanger and landing jr. Circ. & cond. mud f/cmt, job L/D fill up tool, Rig up cmt. head Finish circ. f/cmt, job PJSM Pump 10 bbls CWl00 Preflush Test lines to 3500 PSI 10 bbls CWl00 Preflush Drop btm plug 50 bbls 10.5 ppg MudPUSH Mix & pump 514 bbls lead cmt. @ 10.7 ppg Followed by 145 bbls tail cmt. @ 12.0 ppg Drop btm. plug Displace cmt. w/10 bbls wash water Cont Clean out flow line & shakers, L/D cmt. equip & Landing jr. Change bales & elevators, Wash out diverter stack Nipple down diverter stack & lines Nipple up well head & BOP, Test well head to 1000 PSI-OK Test BOP to 250 PSI Iow & 5000 PSI High Test waived by AOGCC Lou Grimaldi Install wear bushing, Make up BHA & Run BHA from derrick Pick up 5" DP & RIH Pick up 102 jts. 5" DP, RIH & Tag TOC @ 5534' Circ. Btm's up f/Csg. Test Thaw out Kill line, Rig & Test 9.625" Csg. to 2500 PSI f/30 min.-OK Drill out F.C.,Cmt,Shoe & New hole to 5684' Change over to New Mud Rig & Perform LOT=EMW 15.4 ppg Perform PWD Base line test Drill f/5684' to 6250' ART= 2.25hrs AST-.5hrs Change shaker screens Drill f/6250' to 7100' ART=6.25hrs AST=.75hrs Note: Total Fluids sent to 1R- 18=9705 bbls Drill f/7100' to 7703' ART- 4hrs AST- 1.25hrs Pump sweep, Circ. Btm's up 2X, Dry pipe, Monitor well Wipe hole to shoe- 10-20K Normal Drag Cut & slip drilling line, Service rig RIH to 7703'- Hole in good shape Circ. Btm's up prior to drilling Drilling f/7703' to 8476' ART= 3.25hrs AST-- 6hrs Drill f/8476' to 9205' ART=4hrs AST= 5hrs Pump sweep, Circ. hole clean, Monitor well, Pump dry job Wipe hole to shoe @ 5639'- Hole in good shape Pump sweep, Circ. clean & cond. fl csg., Monitor well, Dry pipe POOH to BHA- Hole in good shape Stand back HWDP, Down load LWD, Lay down BHA Download MWD, Finish L/D BHA. Clear floor Pull wear ring R/U to run 7" casing. Operations Summary 1J-09 M/U float equipment and check. Run 7" casing to shoe @ 5635'. Circ casing volume Run 7" casing. Brk circ @ 7800' M/U casing hanger and landing jt. Circ and condition mud L/D fillup tool and pickup cmt head Pump 10 bbl water. Test lines to 3500 psi. Pump 20 bbl CWl00 Drop bottom plug. Pump 30 bbl mud push. Mix and pump 38.1 bbl slurry @ 15.8 ppg Drop top plug. Wash up on top of plug w/10 bbl water. Displace w/338.6 bbl mud w/rig pump. 03/21/01 12:00 AM 03/22/01 12:00 AM 03/23/01 12:00 AM 03/24/01 12:00 AM R/D cement head and elevators. L/D landing jt and long bales Set 7" packoff and tes to 5000 psi Tighten Lockdown screws and test packoff to 5000 psi. Change lower PR's to 4" and change TDS to 4" L/D excess 5" out of derrick Change pipehandling equipment to 4" R/U to test BOPE Test BOPE ti 250/5000 psi Pull test plug, install wear ring, blowdown choke/kill lines. R/U and P/U 10 stands 4" d.p. and stand back in derrick M/U bha and orient. Load nuke sources Hook up kelly hose P/U 4" d.p. from shed Circ and test MWD Continue P/U 4" d.p. and running in hole P/U 4" d.p. and RIH CBU R/U and perform casing test to 3500 psi Drill 14' of cmt, FC, 83' cmt, FS, 9' old hole, 33' of new hole to 9238' Changeover to 11.9 ppg mud. Do LOT to 16.0 ppg EMW Do PWD baseline test Drill form 9238' to 9825' Drill from 9825' to 9850' Circ sweep and condition mud POOH to shoe Cut and slip 90' drilling line Service rig and topdrive RIH w/no problems Pump sweeps and circ and condition mud POOH to shoe. Monitor well. Pump dry job. Blow down. Drop rabbit. POOH. L/D BHA. Download nuke sources DownloadLWD. Clear floor and R/U casers. M/U float equipment and check floats. P/U liner and hanger assembly RIH w/liner on 4" d.p. Fill pipe every 10 stds. Break circ every 2000'. RIH w/liner on 4" d.p. CBU @ shoe M/U cementing head on single and stand in derrick RIH w/liner and M/U cement assembly, attach hose Circ and condition mud Operations Summary 1J-09 03/25/01 12:00 AM 03/26/01 12:00 AM 03/27/01 12:00 AM Pump 10 bbl water, PT to 4500 psi, Pump 20 bbl CWl00, 20 bbl Mudpush, 42 bbl slurry and flush cement lines. Drop plug and displace w/100 bbl mud w/DS. Did not bump plug (.4 bbl over displacement). Atempt to mechanically set hanger and release runnin CBU. Circ 10 bbl cement to surface L/D cement head and 2 singles M/U top drive--d.p, stuck. Circ Release running tool from TOL POOH L/D 2 jts d.p. and inspect liner running tool and L/D. Appears that hanger was set but Liner top packer was not set. All of running tool recovered M/U cleanout asssembly and RIH RIH tag TOL @ 8981' Circ hole clean and condition mud R/U and test csg/liner and lap to 3000 psi for 5 min-OK POOH and L/D 4" d.p. L/D bha. Note performed LOT for injectivity on 1J-09 RIH w/8 stands d.p. from derrick L/D 8 stands d.p. R/U casers pull wearring and hold safety meeting. Run 3-1/2" completion. Finish running 282 jts 3-1/2" tubing. Circ tubing volume Test casing, liner and liner lap to 3500 psi for 30 min.-)K Displace well w/seawater. Space out tubing. M/U pups and hanger and land tubing Run in Iockdown screws Test tubing to 3000 psi-15 min. OK. Test 7" x 3-1/2" annulus to 3000 psi-15 w/500 psi on tubing OK. Open shear valve in bottom GLM Freeze protect well w/60 bbl diesel down annulus and let U-tube back to tubing Blow down lines L/D landing jt. Install BPV and L/D tubing tongs Pull strip-o-matic off hole. Blow down choke/kill lines and pumps Change bottom PR's from 4" to 4-1/2" x 7" VBR's. Change TDS over to 5" N/D BOPE and P/U tree. N/U Xmas tree and test packoff Attempt to pull BPV. Finish freeze protecting injection well. Wait on lubricator P/U and install lubricator. Pull BPV. Bled pressure off. Put tubing and annulus in communication. Install lubricator and install 2-way check. Test tree to 5000 psi. Pull 2-way check and install BPV. Laydown lubricator and secure well. Release rig @ 08:30 hrs 3-27-01 Kuparuk River Unit North Slope, Alaska Kuparuk fJ Pad, Slot fJ-09 1J-09 Job No. AKZZfO090, Surveyed: 23 April, 200~ DEFINITIVE S UR VEY REPORT 9.April, 200f Your Ref: AP1500292300600 Surface Coordinates: 5945963.35 N, 558634.61 E (70° 15'46.5826"N, Kelly Bushing: 115.05fl above Mean Sea Level 149' 31' 33.5526" W) DRiLLiNG S[i~ RvIr' E5 A Halliburton Company Survey Ref: svy9413 KUparuk River Unit Measured Depth (ft) Incl. 0.00 0.000 196.10 1.040 288.15 0.950 376.10 2.500 464.72 5.250 Azim. 0.000 247.270 292.590 328.960 339.74O Sub-Sea Depth (ft) -115.05 81.04 173.08 260.99 349.40 Vertical Depth (ft) 0.00 196.09 288.13 376.04 464.45 560.13 6.840 343.180 444.27 559.32 655.68 8.430 345.930 538.97 654.02 748.57 10.140 347.310 630.64 745.69 841.12 12.970 348.030 721.31 836.36 935.15 14.300 347.300 812.69 927.74 902.75 992.05 1087.66 1191.24 1278.51 1028.33 15.430 1121.59 18.030 1222.58 19.550 1333.21 21.550 1428.14 24.780 345.910 343.730 342.660 340.810 341.150 1017.80 1107.10 1202.71 1306.29 1393.56 1522.99 28.260 342.750 1363.37 1478.42 1621.05 31.220 342.470 1448.50 1563.55 1712.98 36.430 344.290 1524.85 1639.90 1806.11- 41.410 345.050 1597.28 .1712.33 1899.09 44.710 346.170 1665.21 1780.26 Sperry-Sun Drilling Services Survey Report for 1J.09 Your Ref: APl 500292300600 Job No. AKZZfO090, Surveyed: 23 April, 2001 1729.59 1790.09 1848.40 1904.49 1957.23 1991.95 47.490 345.090 2083.39 49.660 344.450 2176.41 52.690 342.410 2271.01 54.590 342.660 2363.16 55.570 343.070 1844.84 1905.14 1963.45 7o19.54 2072.28 2455.20 53.880 341.650 2010.39 2125.44 2554.28 53.530 341.620 2089.04 2184.09 2646.63 52.460 341.990 2124.62 2239.67 2740.39 53.050 341.220 2181.37 2296.42 2836.03 52.820 340.720 2239.01 2354.06 Local Coordinates Global Coordinates Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) 0.00 N 0.00 E 0.69 S 1.64 W 0.72 S 3.12 W 1.21 N 4.78 W 6.67 N 7.18 W 16.20 N 28.44 N 43.03 N 61.14 N 82.79 N 10.34 W 13.69 W 17.14W 21.08 W 25.82 W 106.04 131.93 163.07 199.93 235.23 275.50 321.91 370.94 427.35 488.84 31.37 W 38.44 W 47.85 W 60.05 W 72.21 W 85.29W 99.84W 114.41W 129.86W 145.61W 553.65 619.80 689.23 761.90 834.10 905.71 981.50 1051.56 1122.38 1194.52 162.23 W 180.25 W 200.94 W 223.80 W · 246.06 W 268.82 W 293.98 W 317.01 W 340.56 W 365.44 W 5945963.35 N 558634.61- 5945962.65 N 558632.97 5945962.61 N 558631.50 5945964.52 N 558629.82 5945969.96 N 558627.38 5945979.47 N 558624.15 5945991.68 N 558620.70 5946006.24 N 558617.14 5946024.32 N 558613.05 5946045.94N 558608.14 5946069.14 N 558602,41 5946094.98 N 558595.15 5946126.04N 558585.49 5946162.80 N 558573.01 5946198.01N 558560.57 5946238.18 N 558547.17 5946284.48 N 558532.27 5946333.39 N 558517.31 5946389.68 N 558501.43 5948451.04 N 558485.20 5946515.72 N 558468.07 5946581.72 N 558449.54 5946651.00 N 558428.31 5946723.48 N 558404.89 5946795.51 N 558382.07 5946866.94 N' 558358.75 5946942.53 N 558333.00 5947012.41N 558309.43 5947083.04 N 558285.32 5947154.99 N 558259.88 DEFINITIVE North Slope, Alaska Kuparuk 1J Pad Dogleg Rate (°/100ft) 0.53 0.84 2.07 3.2o 1.71 1.71 1.86 3.06 1.43 1.27 2.87 1.54 1.90 3.41 3.75 3.02 5.77 5.37 3.64 3.11 2.43 3.68 2.02 1.12 2.23 0.35 1.20 0.91 0.48 Vertical Section 0.0o -0,17 0.24 2.57 8.49 18.54 31.22 46.17 64.64 86.72 110.57 137.40 169.92 208.74 246.06 288.40 337.04 388.19 446.64 510.03 576.85 645.37 717.82 794.00 869.56 944.69 1024.53 1098.27 1172.89 1249.17 Comment AK-6 BP IFR-AK 9 April, 2001 - 9:31 Page 2 of 6 DrillQuest 2.00.08.005 Sperry. Sun Drilling Services Survey Report for 1J-09 Your Ref: APl 500292300600 Job No. AKZZlO090, Surveyed: 23 April, 2001 Kuparuk River Unit Measured Depth (ft) 2930.31 3024.37 3117.32 3212.25 3302.43 3401.72 3493.38 3585.70 3678.98 3772.57 3867.30 3961.27 4055.66 4151.39 4243.50 4337.53 4432.49 4527.26 4620.02 4714.77 4810.09 4902.33 4997.27 5091.91 5184.34 5279.30 5373.81 5467.93 5567.81 5728.58 Incl. 53.620 56.000 57.800 57.190 57.290 57.160 56.310 55,620 56.940 57.330 56.410 56.210 56.080 55.840 55.830 55.330 54.970 54.400 53.870 53.660 53.610 53.950 54.310 154.320 54.360 55.040 54.830 53.980 53.770 53.580 Azim. 341.990 340.650 340.710 34O.76O 341.190 341.160 340.850 341.810 344.430 344.520 343.730 344.470 344.400 344.460 344.560 345.190 344.770 345.980 345.200 344.810 345,080 344.390 343.270 342.570 341.600 341.660 339.630 339.900 339.660 339.130 Sub-Sea Depth (ft) 2295.46 2349.67 2400.42 2451.44 2500.23 2553.98 2604.26 2655.93 2707,72 2758,51 2810.28 2862.41 2914.99 2968.58 3020:31 3073.46 3127.72 3182.50 3236.85 3292.86 3349.38 3403.88 3459.51 3514.72 3568.60 3623.48 3677.78 '3732.56 3791.44 3886.68 Vertical Depth (ft) 2410.51 2464.72 2515.47 2566.49 2615.28 2669.03 2719.31 2770.98 2822.77 2873.56 2925.33 2977.46 3030.04 3083.63 3135.36 3188.51 3242.77 3297.55 3351.90 3407.91 3464.43 3518.93 3574.56 3629.77 3683,65 3738.53 3792.83 3847.61 39O6.49 4001.73 Local Coordinates Northings (fi) 1266.07 N 1338.88 N i412.36 N 1487.93 N 1559.63 N Global Coordinates Eastings Northings Eastings (ft) (ft) (ft) 389.58W 5947226.35 N 558235.18 E 414.21W 5947298.96 N 558209.99 E 439.97W 5947372.24 N 558183.66E 466.38W 5947447.61 N 558156.65 E 491.11W 5947519.11N 558131.37 E 1638.65 N · 1711.11N 1783.59 N 1857.82 N 1933.57 N 518.04W 5947597.91N 558103.82 E 542.99W 5947670.18 N 558078.31E 567.48W 5947742.47 N 558053.26 E 589.99W 5947816.52 N 558030.17 E 611.03W 5947892.10 N 558008.54E 2009.87 N 2085.07 N 2160.58 N 2236.99 N 2310.44 N 2385.32 N 2460.58 N 2535.41 N 2608.21 N 2682.04 N 632.73W 5947968.23 N 557986.25 E 654.15W 5948043.26 N 557964.24 E 675.18W 5948118.60 N 557942.62 E 696.48W 5948194.85 N 557920.74 E 716.83W 5948268.14 N 557899.81E 737.07W 5948342.86 N 557878.99 E 757.27W 5948417.96 N 557858.21 E 776.79W 5948492.63 N 557838.10 E 795.50W 5948565.29 N 557818.83 E 815.27W 5948638.96 N 557798.48 E 2756.16 N 2827.95 N 2901.83 N 2975.31N 3046.77 N 835.21W 5948712.92 N 557777.96E 854.80W 5948784.55 N 557757.81E 876.23W 5948858.27 N 557735.81E 898.81W 5948931.57 N 557712.66E 921.91W 5949002.85 N 557689.01E 3120.32 N 3193.30 N 3265.11N 3340.81N 3462.05 N 946,33W 5949076.21N 557664.01E 971.96W 5949148.98 N 557637.81E 998.44W 5949220.58 N 557610.78 E 1026.32W 5949296.07 N 557582.31 E 1071.90W 5949416.95 N 557535.78 E Dogleg Rate (°ll00ft) 1.37 2.79 1.94 0.64 0,42 0.13 0.97 1.14 2.73 0.42 1.20 0.69 0.15 0.26 0.09 0.77 0.52 1.20 0.89 0.40 0.23 0.71 1.03 0.60 0.85 0.72 1.77 0.93 0.29 O.29 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 1324.65 1401.49 1479.30 1559.31 1635.11 1718.56 1795.16 1871.64 1949.21 2027.79 2107.09 2185.26 2263.61 2342.91 2419.09 2496.60 2574.47 2651.72 2726.80 2803.17 2879.87 2954.24 3031.16 3108.03 3183.12 3260.60 3337.90 3414.33 3494.89 3624.19 9 April, 2001 - 9:31 Page 3 of 6 DrillOuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J-09 Your Ref: APl 500292300600 Job No. AKZZIO090, Surveyed: 23 April, 2001 Kuparuk River Unit Measured Depth (ft) Incl. Azim. 5818.78 53.260 338.970 5915.29 54.520 341.120 6010.78 54.250 341.750 6105.19 54.570' 342.790 6197.91 54.400 342.330 6291.57 6386.32 6480.06 6574.68 6665.90 Sub-Sea Depth (ft) 3940.43 3997.31 4052.92 4107.86 4161.73 Vertical Depth (ft) 4O55.48 4112.36 4167.97 4222.91 4276.78 55.640 343.620 4215.42 4330.47 55.270 343.700. 4269.15 4384.20 54.980 343,550 4322.75 4437.80 54.790 343.700 4377.18 4492.23 54.440 343.210 4430.00 4545.05 4485,51 4541.67 4593.59 4650.95 4709.00 6761.10 54.230 343.510 6857.55 54.550 344.980 6946.57 54.080 344.790 7043.72 53.550 344.900 7141.26 53.410 344.800 7233.75 7326.48 7420.95 7514.83 7610.57 4600.56 4656.72 4708.64 4766.00 4824.05 54.990 345.640 4763.10 4878.15 54.640 345.020. 4816.53 4931.58 55.310 345.760 4870.75 4985.80 54.820 345.040 4924.51 5039.56 54.670 345.180 4979.78 5094.83 7700.23 54.230 346.310 5031.91 5146.96 7795.92 54.080 345.900 5087.94 5202.99 7891.59 54.300 342.580 5143.93 5258.98 7985.79 53.620 342.240 5199.35 5314.40 8078.04 54.040 340.560 5253.80 5368.85 8171.73 8265.69 8359.93 8455.67 8547.39 53.030 340.390 5309.48 5424.53 52.980 339.120 5366.02 5481.07 53.360 337.680 5422.51 5537.56 54.370 336.900 5478.97 5594.02 56.270 336.740 5531.16 5646.21 Local Coordinates Northings Eastings (ft) (ft) 3529.70 N 3602.98 N 3676.57 N 3749.70 N 3821.70 N 1097.80W 1124.40W 1149.11W 1172.49W 1195.11W 3895.07 3969,96 4043.75 4118.01 4189.30 1217.57W 1239.53W 1261.21W 1283.03W 1304.21W 4263.40 4338.87 4408.67 4484.36 4560.02 1326.35W 1347.64W 1366.50W 1387.00W 1407.48W 4632.55 4705.87 4780.73 4855.20 4930.76 1426.61 W 1445.80 W 1465.32 W 1484.71 W 1504.80 W 5001.46 5076.76 5151.40 5224.01 5294.59 1522.77 W 1541.39 W 1562.47 W 1585.48 W 1609.24 W 5365.60 5436,01 5506.14 5577.46 5646.80 Global Coordinates Northings Eastings (ft) (ft) 5949484.39 N 557509.36 E 5949557.47 N 557482.19 E 5949630.86 N 557456.90 E 5949703.80 N 557432.96 E 5949775.62 N 557409.78 E 5949848.82 N 557386.75 E 5949923.54N 557364.21E 5949997.16 N 557341.95 E 5950071.24 N 557319.55 E 5950142.37 N 557297.82 E 5950216.30 N 557275.10 E 5950291.59 N 557253.22 E 5950361.25 N 557233.83 E 5950436.77 N 557212.74 E 5950512.27 N 557191.66 E 5950584.65 N 557171.97 E 5950657.82 N 557152.20 E 5950732.52 N 557132.11E 5950806.85 N 557112.13 E 5950882.24 N 557091.46E 5950952.80 N 557072.94E 5951027.95 N 557053.73 E 5951102.43 N - 557032.08 E 5951174.86 N 557008.50 E 5951245.25 N 556984.19 E 1634.42W 5951316.06 N 556958.46 E 1660.39W 5951386.27 N 556931.94 E 1688.16W 5951456.18 N 556903.63 E 1718.01W 5951527.27 N 556873.22 E 1747.70W 5951596.37 N 556842.99 E Dogleg Rate (°/lOOft) 0.38 2.22 0.61 0.96 0.44 1.74 0.40 0.34 0.24 0.58 0.34 1.28 0,56 0.55 0.17 1.86 0.66 O.96 0.82 0.20 1.14 0.38 2.82 0.78 1.54 1.09 1.08 1.29 1.24 2.08 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 3696.47 3774.35 3851.95 3928.72 4004.19 4080.93 4158.96 4235.86 4313.25 4387.61 4464.95 4543.34 4615.59 4693.95 4772.29 4847.23 4922.94 5000.22 5077.10 5155.22 5228.07 5305.50 5383.04 5459.21 5533.66 5608.94 5683.88 5759.09 5836.05 5911.07 9 April, 2001 - 9:31 Page 4 of 6 DrillOuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for 1J.09 Your Ref: AP1500292300600 Job No. AKZZIO090, Surveyed: 23 April, 2001 Kuparuk River Unit Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 8641.66 55.620 336.460 5583.95 5699.00 5718.4e N 1778.72 W 5951667.80 N 556811.42 E 8734.27 55.120 336.600 5636.57 5751.62 5788.37 N 1809.06 W 5951737.46 N 556780.53 E 8829.54 55.280 337.570 5690.95 5806.00 5860.43 N 1839.52 W 5951809.28 N 556749.51 E 8924.29 54.730 338.290 5745.29 5860.34 5932.36 N 1868.69 W 5951880.98 N 556719.78 E 9016.71 55.820 341.070 5797.94 5912.99 6003.58 N 1895.05 VV 5951952.00 N 556692.87 E 9111.12 57.560 343.100 5849.79 5964.84 6078.65 N 1919.31 W 5952026.87 N 556668.03 E 9234.90 57.450 344.020 5916.29 6031.34 6178.78 N 1948.85 W 5952126.77 N 556637.70 E 9334.88 57.910 343.980 5969.74 6084.79 6260.00 N 1972.14 W 5952207.80 N 556613.78 E 9430.05 58.730 344.540 6019.72 6134.77 6337.95 N 1994.11 W 5952285.58 N 556591.21 E 9521.69 59.310 343.910 6066.89 6181.94 6413.56 N 2015.47 W 5952361.02 N 556569.26 E 9619.45 59.150 344.990 6116.91 6231.96 6494.48 N 2037.99 W 5952441.76 N 556546.11 E 9716.49 59.140 344.720 6166.68 6281.73 6574.89 N 2059.75 W 5952522.01 N 556523.72 E 9749.83 59.290 344.740 6183.74 6298.79 6602.52 N 2067.30 W 5952549.58 N 556515.96 E 9850.00 59.290 344.740 6234.90 6349.95 6685.61 N 2089.96 W 5952632.48 N 556492.65 E All data is in Feet unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well. Northings and Eastings are relative t° Well. Magnetic Declination at Surface is 26.244° (08-Mar-01) The Dogleg Severity is in Degrees per 100 feet. Vertical Section is from Well and calculated along an Azimuth of 342.770° (True). Based upon Minimum Curvature type calculations, at a Measured Depth of 9850.00ff., The Bottom Hole Displacement is 7004.67ft., in the Direction of 342.640° (True). Dogleg Rate (°ll00ft) 0.73 0.55 0.85 0.85 2.74 2.57 0.63 0.46 1.00 0.86 0.96 0.24 0.45 0.00 North Slope, Alaska Kuparuk 1J Pad Vertical Section Comment 5988.72 6064.47 6142.32 6219.66 6295.49 6374.38 6478.77 6563.24 6644.20 6722.74 6806.70 6889.95 6918.58 7004.65 Projected Survey 9 April, 200f - 9:3'1 Page 5 of 6 DrillQuest 2.00.08.005 Sperry-Sun Drilling Services Survey Report for f J-09 Your Ref: APl 500292300600 Job No. AKZZlO090, Surveyed: 23 April, 2001 Kuparuk River Unit Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) 9850.00 6349.95 6685.61 N 2089.96 W Comment Projected Survey North Slope, Alaska Kuparuk 1J Pad Survey tool program for 1J-09 From MeasUred Vertical Depth Depth (ft) (ft) 0.00 0.00 To Measured Vertical Depth Depth (ft) (ft) 9850.00 6349.95 Survey Tool Description AK-6 BP_IFR-AK DrillQuest 2.00.08.005 9 April, 200'1 - 9:31 Page 6 of 6 7/9/200t Schlumberger Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Sherrie NO. 1267 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite t00 Anchorage, AK 99501 Field: Kuparuk Well Job # Log Description Date BL Sepia CD Color lC-133 ~)/"0'~ 21312 SCMT 06/18/01 1J-09 ZO(" 0~(~ 21311 SCMT 06105101 1J-10 /,~)(- {)'~! 21306 SCMT 061t2/0t 13H-11 / ~7.-/~./~ 21314 USIT 06114/01 i3H-11 /87'/~.///' 21314 USIT 06114/01 3K-20 ~O~r-/~ 21313 SCMT 061tSl01 -- - DATE: Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907') 561-83t7. Thank you. RECEIVED 'JUL 1 5 2001 ~Jadm Oil&Gas Cons.~n Anchorage WELL LOG TRANS~TT~ To: State of Alaska June 06, 2001 Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1J-09, AK-MM-10082 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Jim Galvin, Sperry-Sun Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 1J-09: 2" x 5" MD Resistivity & Gamma Ray Logs: 50-029-23006-00 2" x 5" TVD Resistivity & Gamma Ray LOgs: 50-029-23006-00 2"x 5" MD Neutron & Density Logs: 50-029-23006-00 2"x 5" TVD Neutron & Density Logs: 50-029-23006-00 2"x 5" MD BAT Sonic Logs: 50-029-23006-00 2"x 5" TVD BAT Sonic Logs: 50-029-23006-00 (Blueline q/Rolled Sepia ~t/BlUeline d/Rolled Sepia q/BlUeline q/Rolled Sepia q~Blueline Rolled Sepia q/Blueline ,l/Rolled Sepia 4/Blueline · Rolled Sepia RECEIVED JUN 11 2001 Alaska Oil & Gas Cons. Com~ Anchorage To: WELL LOG TRANSMITTAL State of Alaska Alaska Oil and Gas Conservation Comm. Attn.' Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska May 01,2001 MWD Formation Evaluation Logs 1J-09, AK-MM-10082 1 LDWG formatted Disc with verification listing. API#: 50-029-23006-00 o/--oq9 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Service Attn: Jim Galvin 6900 Arctic Blvd. Anchorage, Alaska 99518 Date: Signe~ ~ (~O__r~- ~~ RECEIVED MAY 0 ! 2001 /SJaska Oil & Gas Oons. Oommisaion ~chor~e PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY Post Office Box 100360 Anchorage, Alaska 99510-0360 J. Trantham Phone (907) 265-6434 Fax: (907) 265-6224 April 5, 2001 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 Subject: Application for Sundry Approval - 1J-09 Annular Disposal Dear Mr. Commissioner: As per AOGCC regulations 20AAC25.080, Phillips Alaska, Inc. is submitting this Application for Sundry Approval for annular disposal in the Kuparuk well 1J-09. Also submitted with this application are attachments to meet the requirements for annular disposal as stipulated by AOGCC. If you have any questions regarding this matter, please contact me at 265-6434 or Todd Mushovic at 265-6974. Sincerely, J. Trantham Drilling Engineering Supervisor PAl Drilling JT/skad RECEIVED APR 09 0il & ~s Co~s. C0mrnissi~)r,, kr~chora.ge STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon _ Suspend _ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Variance _ Pedorate _ Other _X Annular Disposal 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 5. Type of Well: Development _X Exploratory _ Stratigraphic _ Service _ 4. Location of well at surface 2152' FSL, 2574' FEL, Sec. 35, T11N, R10E, UM (ASP: 558635, 5945963) At top of productive interval 1944' FNL, 681' FWL, Sec. 26, T11N, R10E, UM (ASP: 556552, 5952413) At effective depth At total depth 1724' FNL, 622' FWL, Sec. 26, T11N, R10E, UM (ASP: 556491, 5952632) 6. Datum elevation (DF or KB feet) RKB 34 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1J-09 9. Permit number / approval number 201-044 10. APl number 50-029-23006-00 11. Field / Pool Kuparuk River Field / Kuparuk River Pool 12. Present well condition summary Total depth: measured 9850' feet Plugs (measured) true vertical 6350' feet Effective depth: measured 9739' feet Junk (measured) true vertical 6293' feet Casing Length Size Cemented Conductor 81' 16" 460 sx AS I Surface 5605' 9.625" 653 sx AS Lite & 340 sx LiteCRETE Production 9164' 7" 184 sx Class G Liner 826' 3.5" 196 sx Class G Measured Depth True vertical Depth 115' 115' 5639' 3949' 9196' 6011' 9807' 6328' Perforation depth: measured None true vertical None Tubing (size, grade, and measured depth 3.5", 9.3#, L-80 @ 9026' Packers & SSSV (type & measured depth) Baker ZXP packer @ 8988', No SSSV RECEIVED APR 09 2001 13. Attachments Description summary of proposal__ Detailed operations program __ BOP sketch__ Refer to attached morning, drilling report for LOT test, surface cement details and casing detail sheets, schematic m X! 14. Estimated date for commencing' operation 15. Status of well classification as: April 15, 2001 16. If proposal was verbally approved Oil __X Gas _ Name of approver Date approved Service m 17. I hereby &'~rtify that the foregoing is true and correct to the best of my knowledge. t Signed Suspended_ FOR COMMISSION USE ONLY Questions? Todd Mushovic 265-6974 Prepared b~/ Sharon A//sup-Drake Conditions of approval:PlugN°tifY CommissiOnlntegrity __ so representative may witneSSBoP Test _Location clearance _ I Appr°val n°' r"~/' d ~¢'¢ Mechanical Integrity Test _ Subsequent form required 10- t"0_ ~' ~::'~r ~-~.~-.~..~.~.~'~ ~\ % ORIGIN~s'GNEDBy Commissioner Date .... Approved by order of the Commission ~ ~s u Form 10-403 Rev 06'15'88· C~ ~}]~: [ (¢ ~ ~[/'/~ L,~ SUBMIT IN TRIPLICATE Ar ',.alus Disposal Transmittal F[,.,n a. Designation of the well or wells to receive drilling wastes; 1J-09 b. The depth to the base of freshwater aquifers and permafrost, if present; No Aquifers; Bpf-1545 tvd - RKB c. A stratigraphic description of the interval exposed to the open annulus and other information sufficient to support a commission From the 9-5/8" shoe to the Cement top all that finding that the waste will be confined and will not come to the is open is shale or minor Campanian Sands surface or contaminate freshwater; that were not hydrocarbon bearing. d. A list of all publicly recorded wells within one-quarter mile and all publicly recorded water wells within one mile of the well to receive drilling waste; See Attached Map indicating no wells within 1/4 miles or water wells within I mile e. Identify the types and maximum volume of waste to be disposed of and the estimated density of the waste slurry; Types of fluids as defined by code 20 AAC 25.080. Maximum volume to be pumped is 35,000 bbls and the estimated density of waste slurry will be less than 13 ppg. f. An estimate of maximum anticipated pressure at the outer casing shoe during annular disposal operation and calculations showing how this value was determined. Maximum anticipated pressure at casing shoe during disposal operations is 2465 psi. See attached calculation page g. Details that show the shoe of the outer casing is set below the base of any freshwater aquifer and permafrost, if present, and cemented with sufficient cement to provide zone isolation. attached cementing reports, LOT/FIT reports, and casing reports h. Details that show the inner and outer casing strings have sufficient strength in collapse and burst to withstand anticipated pressure of disposal operations. attached: casing summary sheet and calculation pages. i. Any additional data required by the Commission to confirm containment of drilling wastes. CASING TEST and FORMATION INTEGRITY TEST Well Name: 1J-09 Date: 3117t01 Supervisor: Mike Thornton Reason(s) for [~ In,{iai Casing Shoe Test [] Far,at,on Adequacy [or Annular Injection [] Deep Test: Open Hole Adequacy for Higt~er Mud Weight ;asing Size and Description: 9-5!8" 36# J-55, BTCM Casing Seffing Depth: 5,639' TMD 3,948' TVD Hole Depth: 5,684' TMD 3,975' TVD Mud weight: 8.4 ppg .tg/h of Open Hole Section: 45' EMW = Leak-off Press. + Mud Weight = 1;45'0 p. s i + 8.4 ppg 0.052 x TVD 0.052 x 3,g7'5' EMW for open hole section = 15.4 ppg Pump oMi-put 0.0846 bps -'Iuid Pumped = 6.1 bbl LEAK-OFF DATA CASING TEST DATA MI~IUTE$ MINUTES FOR FOR LOT SIROJ(ES PRESSURE CSGTESt STROKES PRESSURE I I I ' I I I ' , , 0 stks , 0 psi , , , 0 stks 0 DSl I I I i I I [ , . 6 stks , 250 psi,i, :z~.~-~ ., 6 stks 200 psi ! I : 12 stks~550 psl,t j,_~ : 12stks 450 psi i i ,18 stks, B0O ps~';r' ~ .. I 18 stks 800 p. sl , ,30 stks, 1,250 si, , ... 30 stks, 1,300 si ................................... E_., > ~.~..~ .......................... ~.-'.., ' ' I " ~ I 'l ; I 36 stks, ~,450 pslr ~ J 36 stks, 1,600 psi. , ,42 stks, 775 psi , , ] 42 stks, 1,900 psi I I r ' i I ~ : ., 48 stks = 775 psi~., / 48 stks ,2,200 psi; : i 60 stks: 775 psi , ' ' : i 66stksl 775 Esi I .... . ........... ............. ,'1 ...................... .[ 72 stks 4 ,' ............ 775 ps,'' -1. ,,J- ........... J 't--- i I I I I'LII'''' ...... · ''''' .... '''q ' .... ''''' --'--Id · I I I ~ I i I I I I I L I I I I I I I I I I I I I I I i p I ! I I . " .. ............... , , . , r ........... ! ........... -,- ............. i ,I ....... -~ . , ,it ............ + ............ ! p I I i I r I · , , , , , J , I i I I I , I I I I I I , I I I I I I I I I , ........... · ........... 1 !' , · rN. ........., q ............ ~ ............. 1' I J I j I,HIJT IN TIME SHUT IN PRESSURE ,i ,; ,, 1.0 m in j 12,550 p si r-- -----------r .... ----- ---~'-" ..... ,,-,-,,,-,'---', i------- ..-....~--..l......-~... ...... ---~ I I 2.0 mln I 12,525 psll I i i ,, ~ ............ ~ ........................ , SHI~TIN TIME SHIJTINI~Re,~SURE! 3.0 mb I ,t~,525 psi.' i o.o mia ! ! 775 psi i ...4:.o...m. j2j .......... [.2.,_s.2_5.£.s.! 11.0 mini : 750psl i ' ' ' ' I ...... :- r ........ ~ ........... '.--i5.0 mln, .,2,500 psi l'--'-'- .... :'"F ........ I ..... -" .... ""I I ....... =-' 't ......... I ....... ~'--'-'1 ' J-50 mm' '~' : . ? ', 750 psi' ',:- .4:0-mm i.-'----- ,-J .760 pSl'l. : ' r; · ; I ; ' F- -: ' r: -~ ; I .~ 4 6.0 mm~L-,__-__=~750_ Dsi ,. :7.0 mrn l' ,- ~ j ,750 psi j? -.8.0mb [~ ~:-: -' 1.750 psi j NOTE: STROKES TURN TO MINUTES DURING "sHUT IN TIME":see I~i~ei'i~e' abOve'NOTE!T(~CI-EAR DATA, HIGHLIGHT AND PRESS THE'DELET · ':. . · CASING TEST and FORMATION INTEGRITY TEST Well Name: 1J-09 Date: 3/25/01 Supervisor: G.R. Whitlock Reason(s) for test: [] Initial Casing Shoe Test [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and Description: 9-5/8" 36# J-55, BTCM Est. Cement Top Casing Setting Depth: 5,639' TMD 3,948' TVD Hole Depth: 8,398' TMD 5,560' TVD Mud Weight: 9.9 ppg Length of Open Hole Section: 2,759' EMW = Leak-off Press. + Mud Weight 0.052 x TVD -- 800 psi + 9.9 ppg 0.052 x 5,560' EMW for open hole section = 12.7 ppg Pump output = 0.0197 bps Fluid Pumped = 6.0 bbl ~,~ - (oh,~_.~~,.ct, q~ 3,000 psi 2,900 psi 2,800 psi 2,700 psi 2,600 psi 2,500 psi 2.400 psi 2,300 psi Z200 p~ 2,100 psi 2,01~O psi 1,9C0 psi ITIME LINE ONE MINUTE TICKS t I _ . I --a--CASING TEST i_ .. '"'-'*--.' CASING IESI SHUI IN lIME _ t~ TIME LINE ...... ~i:~ _ -- "T~i" 1,800 psi 1,700 psi 1,600 psi 1,500 psi 1.400 psi 1,300 psi 1,200 psi 1,100 psi 1.000 psi 900 psi 800 psi 700 psi 500 psi 400 psi 300 psi 200 psi 100 psi 0 psi STROKES LEAK-OFF DATA MINUTES FOR LOT STROKES PRESSURE ..................... _O__s__tk_?- ........ _O__p__s_i_ .... .................... ~_O__s._~_k__s_ ...... ~_O_.O___p_sj .... .................... ~ _s_ _s_ !_k. .s_ ..... .2_.o..o...p.s_L' ................... .s..o..s3.k..s. ...... .2._S_.O...p.s.! ................... _7..5..s._t.k..s. ...... ~.5..O...p. sj .................. _T _O_ .O. .s. !_k_ .s_ ..... .S_.S_.O_._p.s_j .... ................... j..2_.s..s.!_k_.s. .... .7..s..a...p.s_j .... ................... _T _s_ _o_ _s_ !.k_ .s_ ..... ~.o_.o_._p.s.j .... , 175 stks 800 psi .................. ).?..o..s. !.k..s. ..... 7..s..0...p.s_ j .... .................. .2_ _O. .O_ .s_ !.k_ .s_ ..... 7_.o_.o_._p. sj .... CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE , 6 stks 200 ~si ................... 'iiF~'(~i~ ...... '~iJ'~-~i'-'i 24 stks 1,050 psi 30 stks 1,300 psi .................... ~..s!..k.s. ..... _!,.~..O.O...p..s. ~'~- .................... !2_._s.t._k.s. ..... .!.,.~__o_o..p_.s_-.__ .................... ~._s.t.k.s. ...... _2_,_2_ .0.0.._,_.s.L. .................... .S..4__.s.t.k.s. ..... .2.,_s__s_o___p__s.L. .................. .3..O..S..s.!.k..s. ..... .6. .7. .5. . .p.s. j .... ................ i. ............... ,,.i ................. ,J ................. ~. ............... .~ ................. ..~ i SHUT IN TIME SHUT IN PRESSURE .... .Vo___mj_n_ ...................... _2_,_~._~..o_~.s.M. 2.0 min 2,525 ps' SHUT IN TIME i .... .o_..o...m_!_n_ .................. i_____~ZLp_s_!___i 1.0min ~ 550 psi .... ~'~"~i~-'-t ............... l'-'~ii~"~-ir-'1 ..... ' .......... J ................ t ................. 3.0 min i 550 psi ............... S.UT,, P,ESSURE .... .3_..o_..m__i_r] ...................... .2.,.5..2.5._.p_.s_L' .__..~...o...m..i.n. ................... ?,_5..2.5...p_.s_Lj , ,._..5:.o...m_.i.n. ................... ~,..~.,.s..o.o._ p_.s_L' .... ?_..o...mj.n. ................... ,,._.2.,.s..o.o..p_.s_L' ._...7:.o...m..i.n. ................... ( ..2.,_s..o.o._p_.s_[_. .... _~_._o._.mj.n. ................... j__.2_:_s..o.o..p..s.L' .... _~_..o._.m_j_n_ .................... ,...2_,_s._o.o...p..s.L 6.0min i 550 psi i i 10.0min i 2,500 psi ................ ./_ ............... ~ ................. .~ i. ................ i. ............... J ................. J · i i . ! i . i i . i 7.0m~n ~ ~ 550psi ~ ~ 15.0m~n ~ ~ 2,500ps~ ................ J... ............... J. ................. ~. .......................................... · · , , . t , . I' ~ .'l 80mm ~ ~ 550psi ~ ~ 200mm ~ ~ 2,5000s~ ..... ' .......... q ................ { ................. ~ I ...... -' .......... I- ............... -I ........... · ..... · i i · i i · i i · i 9.0m~n ~ ~ 550 psi ~ ~ 25.0m~n ~ ~ 2,500psl ................ -I- ............... ~ ................. · r ................ r ............... ~ ................. · i i · ! i · , ! · 10.0m~n ~ t 550ps~ ~ ~ 30.0m~n ~ ~ 2,500 psi ................ ~ ............... . ......... .-.. ..... ~ ~ ................ . ............... ~ ................. NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY CASING TEST and FORMATION INTEGRITY TEST Well Name: 1J-09 Date: 3/25/01 Supervisor: G.R. Whitlock Reason(s) for test: [] Initial Casing Shoe Tesf [] Formation Adequacy for Annular Injection [] Deep Test: Open Hole Adequacy for Higher Mud Weight Casing Size and DesCription: 9-5/8" 36# J-55, BTCM Casing Setting Depth: Mud Weight: 5,639' TMD 3,948' TVD 9.9 ppg Hole Depth: 5,684' TMD 3,975' TVD Length of Open Hole Section: 45' EMW = Leak-off Press. + Mud Weight -- 800 psi + 9.9 ppg 0.052 x TVD 0.052 x 3,975' EMW for open hole section = 13.8 ppg v'/' Pump output = 0.0197 bps Fluid Pumped = 6.0 bbl 3,000 psi 2,900 psi 2.800 psi' 2,700 psi 2,600 psi 2,500 psi 2,400 psi 2,300 psi 2,200 psi 2,1130 psi 2.O00 psi 1,9~0 psi 1,800 psi 1.700 psi 1.600 psi 1,500 psi 1.400 psi 1,300 psi 1.200 psi 1.100 psi 1.000 psi g~O psi 800 psi 7[;0 psi 600 psi ,500 psi ~0 psi 300 200 psi 100 psi 0 psi ITIME LINE ONE MINUTE Ti~K$:ii -- · -e- LEAK-OFF TEST .-a--CASING TEST .......... ~..i.~:>~. LOT SHUT IN TIME · _~ ....... --~--- CASING TEST sHuT IN TIME ....... i TIME LINE '- STROKES LEAK-OFF DATA MINUTES FoR LOT STROKES PRESSURE ..................... .o..s._~.s. ......... .o...p..sL ..... .................... _3. .O_ .s. !.k. .s_ ...... ~_O_.O___p_s_] .... .................... _4. .S_ .s. !.k. .s_ ...... .2_.O_.O.._p.s_! .... .................... .S..O..s.!.k..s. ...... ~.S..O...p.s.] .... ................... _~..S..s_!.k_.s. ...... .4..S_.O...p.s.] .... .................. )..o.9..s.!.k..s. ...... ~_s._o__e_s_! .... ................... .~._~..s_.s.!_k._s_ ..... Z_S__o_..p.s..i .... ................... ~..5..O..s.!.k..s_ ..... _8__O__O___p.s_] .... ................... .t.7..5..s.!.k..s. ..... ~_O__O___p.s_] .... ................. ,._.?_.O_.s.!.k..s. ..... Z.S..o_._p_sj .... .................. .2__°. _o_.s.!_k__s._,... Z_°..°.._P.S.] .... ~-225stks.t 675 psi ~ ................. .~.~.O..O..s.!.k_.s_ ..... _s_Z.s__.p.s.L..j J 305 stks 675 psi J ................ T ............... ; ................. I ................ T ............... : ': SHUT IN TIME I SHUT IN PRESSURE ................. , ................ ~ ................. ~ 0.0min ~ ~ 675 psi ~ 1.0min i ! 550 psi i ................. .,. ............... f ................. ~ 20m~n , , 550 ps, ~ ---,--' .......... -I ................ ~ ................. · , · , 3.0 m~n , 550ps~ ~ ............... o , , · 5.Omen j j 550ps~ j ....6.:.o__.m_!D.,i ............... L...5._5__o_ _Rs.!_._j CASING TEST DATA MINUTES FOR CSG TEST STROKES PRESSURE ..................... .O...s)..k.s. ......... _o__R_s.i. .... ..................... ~_.s_t_k_s_ ....... ..2.o..o...p..sL..j .................... J.~.?_tk_?. ...... .4..s._o..?..s.L_.j ................. ,._j.~._s!~.s. ...... ..~.o.p..p..sL__i .................... _2__4_..s_t__k.s. ..... .!,.o_.s.o._R.s_L -1 .................... .3._O...s!._k.s_ ..... j.,?.9_o._R.s_Lj .................... .3._6...s!..k.s. ..... .1.,_6._o_o..R.,~~ .................... ~_2...s.t.k.s. ..... J.,.~..o..o.R.'-. .... ' J 48 stks 2,200 psi ................. i , , i , i i , i i , i i i , i i , , i ................. r ............... '1 ................. -1 , , , , ................. ,~ ............... I ................. I i i · i I I SHUT IN TIME ;HUT IN PRESSURE ,"'-~:'~'~T~"-[ .................. '~i~'~-¢~-F'~ 1.0 min 2,550 p_sj,~ r'--5-.'c3'~'i'~ ..................... '~;~'5'~'~: [ '-':~'.'~' ~'i'r~ ................... 2,525 ps, 4 0 min 2,525 psi 5.0 min 2,500 psi . _ _6. :_o.. _ _m_ /,_n. . . . ; ................. .2_,_s._o.o._R_s_:_. 7.0 min 2,500 psi "'"~'.'~'~'i'~ ...................... 10.0 min J 2,500 psi 70min J J 550 psi .J 15.0min J 2,500 psi ..... ' .......... 'I, ................ f ................. t " ................ I' .................................. · i i ' , 8.0m~n ; | 550 ps~ ~ 20.0 min i 2,500 psi ~ ..... ~ .......... ~ ............................. ;Ill I ................. F ................................. 9.0rain ~ ~ 550ps~ ~ , 25.0rain [ 2,500 p. si ,___l_.O...o...m. Ln..~ ............... ]....5..5..o...p.s.].._] !--~'.~ ~in [ 2,500 psi NOTE: STROKES TURN TO MINUTES DURING "SHUT IN TIME":see time line above NOTE: TO CLEAR DATA, HIGHLIGHT AND PRESS THE DELETE KEY Casing Detail WELL: 1J-09 Phillips Alaska Inc DATE: 3/15/01 1 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 16E RKB = 35.35' TOPS ,9-5/8" Landing Joint (RKB) 35.35 9-5/8" FMC GEN V FLUTED MANDREL HANGER 1.43 35.35 its 3-137 9-5/8", 36~, J-55 BTC-MOD (1 35 its) 5520.30 36.78 Gemeco Float Collar 1.49 5557.08 its 1-2 9-5/8", 40#, L-80 BTC-MOD (2 its) 78.74 5558.57 Gemeco Float Shoe 1.72 5637.31 BI'rM OF SHOE @ 5639.03 Shoe @ 5639' MD 3948' TVD 5639.03 TD of 12-1/4" hole = 5649' MD 3954' IVD Note:Joint # ! & #3 are 40#, L-80, BTCM Note:Pup Joint on FMC Hanger also is 40#, L-80, BTCM I Weatherford bow spring on jt 1 & 3 11 Weatherford SpiraGlider centralizers on Jts #2, 4-13 1 Weatherford bowspring on casing collars every 3rd Jt.starting with Jt No. 16 to 136 41 total 8 joints of casing will be left in pipeshed. 3 joints of casing will be left outside of pipeshed 11 joints total out on location I Fill casing w/fill up tool Break circ @ jr. # 45 & # 90 .i ~Remarks: String Weights with Blocks: 250k Up, 150k Dn, 70k Blocks. Ran 137joints of casing. 'Drifted casing with 8. 679" plastic rabbit. USed Best-o-Life 2000 thread compound on all connections. Phillips Alaska Drilling Cementing Details Well Name: 1J-09 Report Date: 03/15/2001 Report Number:. 8 Rig Name: Nabors 16E AFC No.: AK0148 Field: Kupamk River Unit Casing Size Hole Diameter:. Angle Ihru KRU: Shoe Depth: LC Depth: % washout: 9.625' 12.25' 53.77 5639' 5557' . Centralizers ' . State type used, intervals covered and spacing Comments! ' . · I Weatharford bowspring centralizer per Joint on Its I & 3 w/stop collars, 11 Wsatherford spirsgllders on Jta. 2 & 4-13, . . I bowspHng centralizer on evew 3rd. collar 16 thru 136 , Mud · . Weight: PV(prior cond): PV(after cond): I YP(pdor con(I): YP(affer cond): · Comments: ' ' 9.6 55 15I 41 14 . . · . Gels before: Gels after: Total Volume Circulated: · . · 15/38 4/6 1824 bbls. . · ' ' · Type:~/~lu-'~e:~lu : Weight: .'Wash ':0 . '.:.: .: · Lead Cement. 0:... i .... :. :.:...' '. Type: Mix wtr temp: No. of Sacks: Weight: Yield: "Comments:· :: .: .... .'~.' :' .... · !:: '.. ASLIta 80 653 10.7 4.44 .i.:..: =. ::..:' .. : ".. :~ · '.' .: :':i .... Additives: ....... :=:;. DisPlaCement '.:O":== '~ 'i'::' ! i '::.. i. '=:. Rate(before tall at shoe): Rate(tail around shoe): Str. Wt. Up: ... C0mmehts::.: .: :~: ;.. ':. :~:: :i. :. :.:.: ~:: :' 7.6 bpm @ 1000 psi 7.6 bpm @ 1200 250 "· : ".."'. :; ..... ." .:'.~:' ~ Reciprocation length: Reciprocation speed: Str. Wt. Down: ......... ' .... :' "" 10' 10fpm 150 ...... Surface (313 bbls returns) Date: 3/15/01 NO YES Time:2338 hrs Remarks:Hed red dye at surface after 22.5 bbls of displacement, Had cml to surface after 115.6 bbls of displacement, Had total of 313 bbls cmt. returns to surface, Began having difficulty preclprocatlng csg.and discontinued same after pumping 153.7 bbls of displacement, Had good rsturn$ thru out Job, Did not bump plug, Rsata held good. I Cement Company: I Rig Contractor: Approved By: Dowell I NABORS Mike Thornton Casing Detail 7" Intermediate casing WELL: 1J-09 Phillips Alaska Inc. DATE: 03/20/01 OF 1 PAGES # ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN LENGTH DEPTH Nabors 16E RT to LDS = 32.20' TOPS 7" Landing Joint (RKB) 32.20 7" FMC GEN V FLUTED MANDREL HANGER 1.86 32.20 jts 3-223 7", 26#, L-80 BTC-MOD (221 jts) 9077.18 34.06 Gemeco Float Collar 1.29 9111.24 jts 1-2 7", 26#, L-80 BTC-MOD (2 jts) 83.71 9112.53 Gemeco Float Shoe 1.47 9196.24 BTrM OF SHOE @ 9197.71 9197.71 TD of 8-1/2" hole = 9205' MD (6015' TVD) Run 1 Straight blade centrilizers per joint on joints 1-20. 2, 4-20 (total 18 on 18 stop bands) (Note; joints 1 & 3 will have bow springs due to float equipment) Total of 2 bowsprings on stop bands Run 1 centering guide on joints 219,214,211,208,205,202,199,1 96 193,190,187,184,181 ,! 78,175,172,169,166. (18 total) 239 Total Joints of 7" on location 7 Joints will be left out inside pipeshed :9 Joints are outside pipeshed , Remarks: String Weights with Blocks: 275k Up Wt 145k Dn, 70k Blocks. Ran 223 joints of casing. Drifted casing with 6. 151 "plastic rabbitl Used Jet Lube thread compound on connections. ,,, Nabors 16E . Drilling Supervisors: Mike Thornton/G.R. Whitlock , Phillips Alaska Drilling Cementing Details Well Name: 1J-09 Report Date: 03/20/2001 Report Number:. 3 Rig Name: Nat)om 16E AFC No.: AK0148 Field: Kuparuk River Unit Centrall~er~ State type used, intervals covered and spacing Comments: · · . : Straight blade centralizers o~ Jts 2 and 4-20 (18 total). Bowspringsonltsland3(2total) · Mud Weight: PV(prior cond): PV(after cond): YP(pdor cond): YP(after cond): Comments: 9.8 23 14 18 14 ·· · . Gels before: Gels after:. Total Volume Circulated: .: ~ 8/12 6/7 850 · . Waah· , O: . ' , =. Type: Volume: Weight: c0mments:~' ~ .... ":~ "'" ': cw100 20 8.4 ': :.: . ' :. ':. .' . : :"i: ..... · . . . · S~er i.' :';:: !:0'.'.:.. "'.i.'":.':' Type: Volume: Weight: '.:...i b~rnmenis~ ': ::';.'."' '/ :.."/' MUDPUSHXL 30 12 · ..: .'..... :.'.. '..... !. :'.... ;...;..!.: .. ~. I · :' Lead Ca.tit' ':'0 '; :': !'=:..? i:. ':. Type: Mix wtr tamp: No. of Sacks: Weight: Yield: · ' c0mments[. :..'..'. : ~ :.. :' G · 78 184 15.8 1.16 i' :: :i'::'.. :.i .!'"'; i:~i:::": :: ::'."i':: i..'.'.: .~:.'..: .. .~ % BWO¢ 1~6, .3 % BWO¢ DSS, .15 % BWOO i::: d0}n~*~t~:.: :::' ::.:'.' i:,..'i, i:.::. , .:: .'": :: :.'.? :. i:..il..:. :'.:' ' :'.'i :.,:' !i.i '..?";': :' ':'i,' ; ':;:':;:.: !i~:;:!';!i ?'::!';:;/.;:"i'.::i:.ii..;;i" i~.I' Additives: ::' :DlSple0;alrtent !;;0! !;::. ;:: i:. ;. ;' i.! ;' il ?.i Rate(before tail at shoe): Rate(tail around shoe): Str. Wt. Up: · : cOmmei~ts! i:~ :..,".;:? =: ': · .. ;: .'.i :' 'i: 6 6 275 .;;.'. :. ;: i'.' !:..;'; '..:;..: :..:: ::i" :: :'.'i ? ,~. . ......:.:. i.'!. !'. ' ·" '.. ' .' :' .i :' · :: Reciprocation length: Reciprocation speed: Str. Wt. Down: :".!":i i'i:...!i.: ."; '.: ~o ~o 1~ lhooretioal Displacement: Actual Displacement: Str. Wt. In mud: 1148.6 348.8 Calculated top of cement: G~: Bumped plug: Floats held: 8~00' Date:~/~0/01 Timo:~0:13 Remarks:Good r~uma and able to r~olpro¢~ta throughout lob. Cement Company: I Rig Contractor: Approved By: Dowell I NABORS G.R. Whitlock ARco Calculations Cha Sheet number Date '~/~,,~/; ..-. ).c/oo' ~,c, QUALITY LITHO PRINTING, ANCHORAGE, AK (907) 563'4743 159- 5881 ARco Subject File Calculations Cha QUALITYLITHOPRINTING. ANCHORAGE, AK (907) 563-4743 159-5881 plot Rede,er,ce ;, P~;s5 <0-9B50'>. ~Tr~ Vest,el Depths are reference RKB HUGHES ..... Phillips Alaska, Inc.; : Structure : Pod 1J Well : 9 <- West (feet) 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 600 5400 52OO 5000 4800 4600 44OO 4200 4000 3800 3600 3400 3200 3000 28OO / / / // / / / / / / I 2600 ~X \'.,~ 2400 ~. 2200 '"'-. ...... 2000 1800 1600 5/8 Cosing / / /' / / J ./ 5400 5200 5000 48O0 46OO 4400 4200 4000 3800 36oo A I Z 3400 0 3200 ,~, 3000 ~ 28OO 26OO 24O0 22OO 200O 1800 1600 1400 1400 1200 1200 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 200 400 600 <- West (feet) ALASKA OIL AND GAS CONSERYA~ION C0~SSION James Trantham Drilling Engineering Supervisor Phillips Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 TONY KNOWLES, GOVERNOR 333 W. 7TM AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re' Kuparuk River Unit 1J-09 Phillips Alaska, Inc. Permit No: 201-044 Sur Loc: 2152'FSL, 2574'FEL, Sec. 35, T1 iN, R10E, UM Btmhole Loc. 1825'FNL, 669'FWL, Sec. 26, T1 IN, R10E, UM Dear Mr. Trantham: 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. Annular dispoSal of drilling wastes will not be approved for this well until sufficient data is submitted to ensure that the requirements of 20 AAC 25.080 are met. Annular disposal of drilling waste will be contingent on obtaining a well cemented surface casing confirmed by a valid Formation Integrity Test (FIT). Cementing records, FIT data, and any CQLs must be submitted to the Commission on form 10-403 prior to the start of disposal operations. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. . Sincerely, 'D~iel T. Semount, Jr. Co~issioner BY ORDER OF THE COMMISSION DATED this .... ~7 fl~ day of March, 2001 dlffEnclosures cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. 1J-09 Subject: 1J.09 Date: Mon, 5 Mar 2001 13:05:27 -1000 From: "Todd J Mushovic" <tmushov@ppco.com> To: tom_maunder@admin.state.ak.us CC: "James A Trantham" <jtranth@ppco.com> Tom, I just want to verify with you from our telephone conversation that we will test the BOPs to 3000 psi in step 6 of the "General Dill and Complete Procedure" and that this well is a planned topset. We will not be drilling into the higher reservoir pressures of the Kuparuk interval so the MASP that the surface casing will see is 2285 psi. If there are any additional questions that need to be answered please give me a call. Todd Mushovic 265-6974 - office 240-5740 - cell I of 1 3/5/01 1:13 PM STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.005 la. Type of work: Ddll [~] Redrill [~ I lb. Type of well. Exploratory D Stratigraphic Test D Development Oil r~ Re-entry E~] Deepen DI Service [~ Development Gas D single Zone ~'] Multiple Zone D 2. Name of Operator 5. Datum elevation (DF or KB) 10. Field and Pool Phillips Alaska, Inc. RKB 34 feet 3. Address 6. Property Designation Kuparuk River Field P.O. Box 100360 Anchorage, AK 99510-0360 ADL 25661 ALK 471 Kuparuk River Pool 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 2O AAC 25.0251) 2152' FSL, 2574' FEL, Sec. 35, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval 8. Well number Number 2003' FNL, 724' FWL, Sec. 26, T11N, R10E, UM 1J-09 #59-52-180 At total depth 9. Approximate spud date Amount 1825' FNL, 669' FWL, Sec. 26, T11 N, R10E, UM March 5, 2001 $200,000 12. Distance to nearest property line I 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) 724 ' @ TD feetI 161.4' at surface feet 2560 9719' MD / 6305' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth: 300 MD Maximum hole angle 54.8° Maximum surface 3334 psig At total depth (TVD) 4013 psig 18. Casing program Settin~ Depth size Specifications Top Bottom Quant~ of Cement Hole Casin~l Wei~lht Grade coupIin~ Length MD TVD MD TVD {include sta~le data) 24" 16" 62.6# H-40 Welded 80' 120' 120' 120' 120' 460 sx AS 1 12.25" 9.625" 36# J-55 BTCM 5493' 120' 120' 5613' 3939' 640 sx AS Lite & 340 sx LiteCrete 8.5" 7" 26# L-80 BTCM 9108' 120' 120' 9228' 6022' 170 sx Class G 6.125" 3.5" 9.3# L-80 SLHT 641' 9078' 5936' 9719' 6305' 150 sx GasBIok 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 Conductor Surface ProductionRECEIVED Liner F'EB ?o ]. 2001 Perforation depth: measured Alaska Oil & Gas Cons. Commission true vertical Anchorage 20. Attachments Filing fee r~l Property Plat r"] BoP Sketch r"l Dive,er Sketch r"] Drilling program [~] Ddlling fluid program ~] Time vs depth plot [-1Refraction analysis r'~ Seabed report [~ 20 AAC 25.050 requirements E~ 21. i hereby certify that the foregoing is true and correct to the best of my knowledg~ Questions? Todd Mushovic 265-697~ Signed ~i~'~'~'~~ Title: Drilling Engineering Supervisor Date 7--('~[tr~::) [ ~rr-'Jarnes Trantharn ~' Pre~arecl bV Sharer3 AIIsut)-Drat(~ Commission Use Onl) PermitNumber'z~'/" L') {/L// I APInumber .L~Z.~j' ,- ,,~';"~~ "i~-._"}IApprovaldate ISeecoverletter 50--~-~ ~_~ - "~ ~' ~/ Ifor other requirements Conditions of approval Samples required D Yes r~ No Mud log required [-1 Yes r'~ No Hydrogen sulfidemeasures [~] Yes r-~ No Directional surveyrequired ['~ Yes r-] No Requlred working pressure for BOPE F-'~2M; D 3M; ~ 5~ E] lOM;D D Other: ~(~)(~e..~, ,~,~.,~.~..~ ~",~,-~?'1~$, ~,~¢~:)e,~ ~;3~'~ ~,t~ · ' ' 'V' ~"\! ......... byorderof ApprovedbylB 'Ir ~V ~ O '' '~' + 'l'[~: ~ "~ '~ ~ '~ [ i ii C.o.m. missioner the commission Date ~ ' 7-'~ 0 ( ................. Form 10-401 Rev. 12/1/85 · Submit in triplicate GENERAL DRILL AND COMPLETE PROCEDURE EBA PRODUCER KRU 1J-09 General Procedure: 1. Excavate cellar, install cellar box, set and cement 16" conductor to +/- 150' RKB. Weld landing ring on conductor. 2. Move in / rig up Nabors Rig 16E Install diverter & function test same. 3. Spud and directionally drill 12-1/4" hole to 9-5/8" surface casing point (+/5613 MD') according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 4. Run open hole e-line or drill pipe conveyed logs as needed. Obtain sidewall cores on drillpipe as needed to gain additional formation data. 5. Run and cement 9-5/8" 36.0# J-55 BTCM casing to surface using lightweight permafrost cement lead slurry to assure cement returns to the surface. Adequate excess cement will be pumped to ensure cement reaches the surface during the first stage cement job. Displa.c,,e cement with mud. 6. Nipple down diverter and install wellhead. Nipple up BOPE and test to 2~i. Record results. 7. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 8. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). 9. Directionally drill 8-1/2" hole to base HRZ (9228' MD) according to directional plan. Run MWD / LWD logging tools in drill string as required for directional monitoring and formation data gathering. 10. Run 7" 26.0# L-80 BTCM casing to surface and cement. Note: If significant hydrocarbon zones are present above the Kuparuk, sufficient cement will be pumped for isolation in accordance with Rule 20 AAC 25.030 11. Nipple up BOPE and test to 5000 psi. Record results. 12. Shut in BOP's and pressure test casing to 2500 psi for 30 minutes per AOGCC regulations. Record results. 13. Drill out cement and 20' minimum to 50' maximum of new hole. Perform formation integrity test not to exceed 16.0 ppg EMW. This establishes a maximum allowed drilling mud weight below the casing shoe per 20 AAC 25.030 (0.5 ppg less than the FIT or LOT EMW). , 14. Drill 6-1/8" hole to well total depth (+/- 9719' MD) according to directional plan, running LWD logging equipment as needed. Circulate and condition hole. POOH 15. Run open hole e-line or drill pipe conveyed logs as needed. 16. Run and cement 3-1/2" 9.3# L-80 SHLT liner and Baker ZXP/Flexlock hanger/packer assembly. Set packer +/- 150' above intermediate casing shoe to provide appropriate liner lap. 17. RIH with clean out BHA. Scrape casing. Displace well to completion brine. 18. Run and land 3-1/2" tubing. 19. Pull landing joint. Install BPV. NiPple down BOP stack, and nipple up production tree° Pull BPV. Install test plug. Pressure test production tree. Pull test plug. Secure well. TJM, 2/20/01, v3 20. Freeze protect well. Set BPV. Release rig and turn well over to production. 21. Clean location and RDMO in preparation for coiled tubing cleanout and perforating. o TJM, 2/20/01, v3 DRILLING FLUID PROGRAM, PRESSURE CALCULATIONS, & DRILLING AREA RISKS KRU 1J-09 Drilling Fluid Properties: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Spud to 9-5/8" Surface Casin~ 8.5-10.2 16-26 25-50 100-200* 10-20 15-40 7-15 9.5-10 6-8% Drill out to 7" Intermediate Casin[l 8.8-9.8 5-25 8-25 35-55 3-10 10-15 5-15 8.5-9.5 6-8% Drill Out to TD 11.3-13.0 25-35 20-30 50-65 4-7 4-8 8-10 8.0-8.5 4-7% Drilling Fluid System - Nabors 16E 3 - Derrick Shale Shakers Desander Desilter Mud Cleaner Centrifuge Degasser Pit Level Indicator (w/visual and audible alarms) Trip Tank Fluid Flow Sensor Fluid Agitators *Spud mud should be adjusted to a FV between 180-250 sec/qt to drill gravel beds Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Maximum Anticipated Surface Pressure: There is one possibility for the possible maximum anticipated surface pressure (MASP) seen by the surface casing string along the 1J-09 well path since this well is a planned top set and that is. 1) MASP can be calculated using an expected leak-off of 13.3 ppg EMW (0.69 psi/fi) and a gas gradient of 0.11 psi/ft. This shows that formation breakdown would occur at a surface pressure of 2285 psi. The leak off EMW was chosen based on an open hole LOT on well, 1 D-40A, taken to 13.3 ppg (0.69 psi/ft). MASP = (3939 ft)(0.69 - 0.11) = 2285 psi Phillips Alaska, Inc. will test the BOP equipment to :2816 psi prior to drilling out of surface casing. The maximum anticipated pressure for the intermediate casing string would be 2814 psi as calculated below. 1. If surface shoe LOT is higher than expected and the well is drilled out of surface casing to TD, the MASP can be calculated based on a reservoir pressure of 3550 psi at 6305' TVD (0.56 psi/ft) and a gas gradient of 0.11 psi/ff. In this case, MASP would occur at 2837' psi. MASP = (6305 ft)(0.56 - 0.11) = 2837 psi . Some prior EBA and GSA wells in this area have experienced gas charged sands in the D-shale as a result of historic Gas Storage Area injection. These sands are located above the Kuparuk reservoir and are expected to occur at +/- 6174' TVD along the proposed well path in the 1J-09 target area. There is a strong possibility that gas charging will be encountered in this well and if this occurs, MASP would be based on a 12.5 ppg equivalent pressure (0.65 psi/fi). Based on this pressure gradient and a gas gradient of 0.11 psi/ft, MASP would occur at 3334 psi. MASP = (6174 ft)(0.65-0.11) - 3334 psi Phillips Alaska, Inc. will test the BOP equipment to 5000 psi prior to drilling out of intermediate casing. Based the anticipated pressures shown, a maximum mud weight requirement for this well is established based potential charging of the D-shale sands. Assuming a 150 psi overbalance is required to safely drill and trip in this formation, then a required mud weight of 10.9 ppg can be predicted as the maximum mud weight needed to safely conduct rig operations, assuming a TVD of 6305'. MW = [(6305 ft)(0.54)+150]/6305/.052 -- 10.84 ppg Well Proximity Risks: The nearest existing well to 1J-09 is 1J-03. As designed, the minimum distance between the two wells would be 161.4' at surface. 1J-03 is a Kuparuk producer that has recently been drilled, but not completed. Drillinq Area Risks: Risks in the 1J-09 drilling area include surface interval hydrates, lost circulation, and potential borehole instability in and below the permafrost zone as well as through the intermediate shales. Hydrate risks will be minimized by the use of sufficient mud weights to allow for tripping of pipe, controlled drilling rates, and rheological properties which safely appropriate gas breakout. Lost circulation will be addressed with lost circulation material (LCM), reduced circulating rates, and reduced mud weights as needed. Shale instability will be controlled primarily with the planned fluid densities. Additional risk exists with unpredictable charging of the D-shale sands during historic gas injection. These gas pressure risks are mitigated with by top setting above the D-shale. Annular Pumping Operations: Incidental fluids developed from drilling operations will be hauled to the nearest permitted Class II disposal well. (Note that cement rinseate will not be injected down the dedicated disposal well but will be recycled or held for RECEIVED FEB 2, 1 Z00! Alaska Oil & Gas Cons. Commission Anchorage an open annulus.) The 1J-09 surface/production casing annulus will be filled with diesel after setting production casing and prior to the drilling rig moving off of the well. If isolation is required per regulations over significant hydrocarbons, then sufficient cement volume will be pumped during the production cement job to cover those formations. At the end of drilling operations, a request for 1J-09 to be permitted for annular pumping of fluids occurring as a result of future drilling operations on 1J pad, per regulation 20 AAC 25.080, will be submitted. Any zones containing significant hydrocarbons will be isolated prior to initiating annular pumping. There will be no USDW's open below the shoe or potable/industrial water wells within one mile of the receiving zone. Reference the enclosed directional drilling plan for other formation markers in this well. Surface casing will be set in the Cretaceous shales below the base of the West Sak Sands. These 300-500' thick shales are part of the Colville Group and are known to provide vertical barriers to fluid flow. The surface casing shoe will be set a minimum of 200' vertically below the base of the West Sak into the heart of the shales. The surface and production casing strings exposed to the annular pumping operations have sufficient strength by using the 85% collapse and burst ratings listed in the following table: Wt Connection 85% of 85% of OD (ppf) Grade Range Type Collapse Collapse Burst Burst 9-5/8" 36 J-55 3 BTC 2,020 psi NA 3,520 psi 2,992 psi 7" 26 L-80 3 BTCM 5,410 psi 4,599 psi 7,240 psi 6,154 psi 31/=''* 9.3 L-80 2 8rd EUE Mod 10,530 psi 8,951 psi 10,160 psi 8,636 psi *ifneeded Fluids to be disposed of in the annulus will be limited to drilling wastes associated with drilling a well as defined in 20 AAC 25.080 (h). RECEIVED FEB 2, 1 2001 Alaska Oil & Gas Cons, Commission Anchorage KRU 1J-09 Produt ;r Proposed Completion Schematic Topset Base Case PH 'LIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY 16" 62.6# @ +/- 120' MD Depths are based on Nabors 16E RKB Surface csg. 9-5/8" 36.0# J-55 BTCM (+/- 5613' MD / 3939' TVD) 3-1/2" FMC Gen V Tubing Hanger, 3-1/2" L-80 EUE8RD pin down 3-1/2" 9.3# L-80 EUE8RD Spaceout Pups as Required 3-1/2" 9.3# L-80 EUE8RD Tubing to Surface 3-1/2" Camco 'DS' nipple w/2.875" No-Go Profile. 3-1/2" x 6' L-80 pup installed above and below, EUE8RD set at +/- 500' MD 3-1/2" 9.3# L-80 EUE8RD tubing to landing nipple GLM placement to be determined 3-1/2" x 1" Camco 'KBUG' Mandrels w/DV's and RK latch's (Max. OD 5.390", ID 2.867"), 6' L-80 handling pups installed above and below on GLM. 3-1/2" x 1-1/2" Camco 'MMG' mandrel w/shear valve and latch (Max. OD 5.968", ID 2.92"), pinned for 3000 psi shear (casing to tubing differential), 6' L-80 handling pups installed above and below. Intermediate csg. 7" 26.0# L-80 BTCM (+/- 9228' MD / 6022' TVD) Future Perforations Production Liner 3-1/2" 9.3# L-80 SLHT (+/- 9719' MD / 6305' TVD) 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 3-1/2" Camco 'DS' nipple w/2.813" No-Go profile. 3-1/2" x 6' L~80 EUE8RD handling pups installed above and below 1 jt 3-1/2" 9.3# L-80 EUE8RD tubing 5.125" x 3" Baker Iocator sub 4-1/2" Baker GBH-22 casing seal assembly w/15' stroke, 3-1/2" L-80 EUE8RD box up Liner Assembly (run on drillpipe), set @ +/- 9078' MD Baker 7" x 5" 'ZXP' Liner Top Isolation Packer with HR profile Baker 7" x 5" 'Flexlock' Liner Hanger Baker 17' Seal Bore Extension XO Sub, 5" Stub Acme box x 3-1/2" SLHT pin 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Halliburton 'XN' nipple w/2.75" No-Go Profile, 3-1/2" SLHT box x pin 3-1/2" 9.3# L-80 SLHT liner as needed 3-1/2" Baker Landing Collar 1 jt 3~1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Collar 1 jt 3-1/2" 9.3# L-80 SLHT tubing 3-1/2" Baker Float Shoe F' E B 2 1_ 2 0 01 RECEIVED Alaska (~Ij~.G~ ~0rtls. vC~)rnmissi°n Anbflorag~ < 1J-09 Drilling Hazards Summary (to be posted in Rig Floor Doghouse Prior to Spud) (See Well Plan Attachment: Detailed Risk Information for further discussion of these risks) 12-1/4" Hole / 9-5/8" Casing Interval Event Risk Level Mitigation Strategy Conductor Broach Low Monitor cellar continuously during interval. Well Collision Low Careful well planning and surveying, adherence to anti-collision policy Gravel and sand Low Elevated mud viscosity from spud; Hi dens sloughing sweeps; contingent 13-3/8" casing string. Shaker/Trough Ball Mill Low Controlled ROP Overflow Shoe Fracture/Lost Low Reduced pump rates, and lightweight tail Returns during cement cement job 8-1/2" Hole ! 7" Casing Interval Event Risk Level Mitigation Strategy Shale stability in HRZ Moderate Control with higher MW and proper drilling practices. Hole cleaning in long, Moderate Good drilling practices. high angle tangent High ECD and High Pumping and rotating out on all trips to swabbing if higher MW reduce swab and barite sag potential. is required D-shale gas High Increase MW to +/-13 ppg 6-1/8" Hole / 3-1/2" Liner Interval Event Risk Level f4itigati0n Strategy Shale stability across K- High control with higher MW and proper drilling 1 interval practices. High ECD and Moderate Pumping and rotating out on all trips to swabbing if higher MW reduce swab and barite sag potential. is required Gas related to GSA gas High May require MW increase to +/-13 ppg injection RECEIVED FEB ~ ~ ZOnl Alaska Oil & Gas Cons. Commission Anchorage 1J-09 Drilling Hazards Summary. doc prepared by Todd Mushovic 2/2O/01 Page 1 of I 1J-09 Kuparuk Well Surface Cement loads and CemCADE* summary. Use 45% excess below the Permafrost and 250% above. Drilled with 12 1/4" bit. 9 5/8", 36 #casing TMD 5613', Single Stage Design. Tail Slurry TOC is @ 3936' MD ( 800' above the West Sak top). Base of the Permafrost at 1576' MD Volume Calcs: Pump 20 bbls CW100 Preflush, 50 bbls MudPUSH XL Spacer @ 10.5ppg. Cement from MD to 3936' with LiteCRETE @ 12.0 ppg and from 3936' to surface with ASLite @ 10.7 ppg Lead Slurry Requirements: ASLite @ 10.7 ppg, Class G + 50%D124, 9%D44, 0.4%D46, 30%D53, 1.5%S1, 1.5%D79 - 4.44 ft3/sk (3936'-1576') x 0.3132 ft3/ft x 1.45 (45% excess) = (1576') x 0.3132 ft3/ft x 3.50 (250% excess) = 1071.8 ft3+ 1727.6 ft3 = 2799.4 ft3/4.44 ft3/sk = 1071.8 ft3 1727.6 ft3 2799.4 ft3 630.5 sks - Round up to 640 sks Have 260 sks of additional Lead on location for Top Out~2nd stage, if necessary Tail Slurry Requirements: LiteCRETE @ 12.0 ppg - 2.40 ft3/sk (5613'-3936') x 0.3132 ft3/ft x 1.45 (45% excess) = Shoe Joints: (80') x 0.4341 ft3/ft = 761.6 ft3 + 34.7 ft3 = 796.3 ft3/2.40 ft3/sk = 761.6 ft3 34.7 ft3 796.3 ft3 331.8 sks - Round up to 340 sks BHST = 95 deg F (BHST calculated using a gradient of 2.6 °F/100 ft. below the permafrost) CemCADE* Summary: Fluid sequence: Establish circulation using FW. Pump 20 bbl CW100 Preflush. Drop Bottom Plug. Pump 50 bbls 10.5ppg MudPUSH XL Spacer, 640 sks (506 bbl) ASLite Lead, 340 sks (145 bbl) LiteCRETE Tail. Drop Top Plug. Displacement is approximately 428 bbls. Circulation: Circulation and cementing at or less than 8 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug as well as maintaining returns. Run dye marker in the spacer to provide insight into the decision to open the port collar or performing a top job. Expected pressure to bump the plug is 700 psi. At 7 bpm, expect 30 minutes of u-tubing after dropping the top plug. Recommended Conditioned Mud Properties: 10.O ppg, Pv = 15 or under, Ty = 15 or under. RECEIVED FEB 2 1 2nnl Alaska Oil & Gas Cons. Commission Anchorage 1J-09 Well Intermediate Cement loads and CemCADE* summary. Use 75 % excess. Drilled with 8 1/2" bit. 7", 26 #casing TMD 9228'. TOC@ 8428' (800' Shoe Tack). Volume Calcs: Pump 20 bbls CW100 Preflush, 30 bbls MudPUSH XL Spacer @ 12.0ppg. Cement from 9228' MD to 8428' with Class G + adds @15.8 ppg Slurry Requirements' 15.8 ppg Class G 0.2%D46, 0.3%D65, 0.1%D800 - 1.17 ft3/sk (adjust retarder to give 3-4 hours thickening time) 7", 26# x 8 1/2" OH: (9228'-8428') x 0.1268 ft3/ft x 1.75 (75% excess) = 177.5 ft3 Shoe Joints: (80') x 0.2148 ft3/ft = 17.2 ft3 Total Volume = 194.7 ft3. 194.7 ft3 / 1.17 ft3/sk = 166 sks - Round up to 170 sks BHST = 149 deg F (BHST is calculated assuming 2.6 °F/100 ft. gradient below the permafrost.) CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl CW 100 Preflush, Drop Bottom Plug, 30 bbls 12.0 ppg MudPUSH XL Spacer, 170 sks (35 bbls) Class G + adds, Drop Top Plug. Displacement is approximately 350 bbls. Circulation: Circulation and cementing at or less than 7 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 3 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1400 psi. At 7 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 10.0 ppg, Pv = 15 or under, Ty = 15 or under. Kevin Tanner can be reached at the following numbers regarding this job or any other assistance: 265- 6205(w), 336-0067(h), 230-6628(ce11). RECEIVED FEB g 1 2001 Alaska Oil & Gas Cons. Commission Anchorage 1J-09 Kuparuk Well, Liner Cement loads and CemCADE* summary. Use 60% excess. Drilled with 6 1/8" bit. 3 1/2", 9.3 #casing TMD 9719'. TOC@ 8878' (200' over top of liner top). Liner Top @ 9078' Previous casing 7", 26#, 9228' TMD. 4", 14# DP, 150' liner lap. Volume Calcs: Pump 20 bbls CW100 Preflush, 20 bbls MudPUSH XL Spacer @ 13.0ppg. Cement from 9719' MD to 8878' with Class G + adds @ 15.8 ppg Slurry Requirements: 15.8 ppg GasBLOK w/Class G + D53, D600, D135, D800, D047, D065, per lab testing - 3.5 to 4.5 hour thickening time, Yield = 1.2 ft3/sx 3 1/2", 9.3# x 6 1/8" OH: (9719'-9228') x 0.1378 ft3/ft x 1.60 (60% excess) = 108.3 ft3 3 1/2", 9.3# x 7", 26#: (150') x 0.1480 ft3/ft = 22.2 ft3 7", 29#: (200') x 0.2148 ft3/ft = 43 ft3 Shoe Joints: (80') x 0.0488 ft3/ft = 3.9 ft3 Total Volume = 177.4 ft3. 177.4 ft3 / 1.2 ft3/sk = 148 sks - Round up to 150 sks BHST = 157 deg F (BHST is calculated assuming 2.6 °F/100 ft. gradient below the permafrost.) CemCADE* Summary: Fluid sequence: Establish circulation using FW, 20 bbl CW100 Preflush, 20 bbls 13.0 ppg MudPUSH XL Spacer, 150 sks (32 bbls) Class G + adds, Drop Top Plug. Displacement is approximately 103 bbls. Circulation: Circulation and cementing at or less than 3 bpm is within the safe ECD to avoid breaking down the formation. Recommend dropping the rate below 2 bpm for the last 20 bbls of displacement for bumping the plug. Expected pressure to bump the plug is 1700 psi. At 3 bpm, expect no u-tubing after dropping the top plug. Centralizers: Recommend using at least 1/1 across the entire liner interval to maximize primary success. Recommended Conditioned Mud Properties: 13.0 ppg (preferably lower), Pv = 15 or under, Ty = 15 or under. RECEIVED FEB g 1 2001 Alaska Oil & Gas Cons. Commission Anchorage C~o~ed by ~choe~For T Mu~hovie Dote plotted : 14--Feb--2001 Plot Reference is 1J-09 Version#2. Coordinotes are in feet reference slot ~/9. [True Vertical Depths ore reference RKB (Nabors Phillips Alaska, Inc.i Structure : Pod 1J (WS Pilot) Field : Kuparuk River Unit Well : 9 Location : North Slope, Alaska PROFILE COMMENT i Point iKOP iBeg 3/100 Bid iPermofrost iEOC iTop Ugnu iBose Ugnu iTop West Sak MD 500.00 800.00 1576.21 2295.90 5707.02 4493.22 4756.19 lac 0.00 10.00 55.29 54.82 54 82 54 82 54 82 Dir 342.77 542.77 342.77 342.77 342.77 542.77 542.77 DATA iBose West Sok !9 5/8 Casing Pt C80 5265.53 5612.64 6384.96 54 82 54 82 54 82 542.77 542.77 542.77 TVD North East V. Sect 500.00 0.00 0.00 0.00 797.47 41.57 -12.89 45.52 1514.00 315.13 -97.12 527.84 2026.78 786.95 -244.08 823.93 2841.00 1890.06 -586.23 1978.89 3294.00 2505.80 -776.59 2621.47 5434.00 2695.47 -835.42 2820.05 3739.00 5106.69 -963.58 3252.69 3959.00 3577.65 -1047.63 3536.59 4584.00 5980.55 -1234.62 4167.62 Deg/lO0 0.00 2.00 5.oo~ 3.001 0.001 0.001 0.00~ 0.00:. 0.00 0 O0 C50 iC40 iCSO iC20 iBase HRZ/7 Casing P iK-1 iTarget-Top C4/KupD !Top C3 !Top C2 Top C1 iTop B Shale 7929 60 8565 48 8911 92 9167 04 9227 78 9361 42 9491 57 9556 71 9557 54 9574 89 9588 78 54 82 54.82 54.82 54.82 54.82 54.82 54.82 54.82 54.82 54.82 54.82 342.77 342.77 542.77 542.77 542.77 342.77 542.77 542.77 542.77 542.77 342.77 5274.00 5524.00 5840.00 5987 O0 6022 O0 6099 O0 6173 99 6200 O0 6212 O0 6222 O0 6230 O0 5186.34 -1608.62 5450.08 5525.04 -1713.67 5784.70 5955.16 -1846.46 6252.94 6152.32 -1908.23 6441.46 6199.74 -1922.94 6491.11 6504.06 -1955.50 6600.55 6405.66 -1986.81 6706.71 6440.90 -1997.74 6745.60 6457.16 -2002.78 6760.62 6470.71 -2006.98 6774.81 6481.54 -2010.34 6786.16 TD - C a sin ~__Pt ...................................... ~9_7__1.. 8.._._9_._4._ ........ ~_5._.4.:_8_.2_ ...... ~5_4_2.77_____6_3_0_..5__0_0 ........ _6~58_~_._1.~ ............ :~..;~..Q.~:._1...,86 ..... 5.8..9..2,54 0 00! 0 O0 0 00~ 0 00~ 0 00~ o o oo! 0 O0~ 0 00: 0 O0 0 O0 ~ ~;~o~ For T Mushovic Dote &~oHed : 14-~'~b-2001 C~a;notos or~ in feel ~e~erence slot ............................................................. Phillips Alaska, Inc. Structure : Pod 1J (WS Pilot) Well : 9 i ,.Field : Kuporuk River Unit Location : North Slope, Alaska' 342.77 AZIMUTH 6707' (TO TARGET) ***Plane of Proposal*** 45O 9OO 1800 2250 {- 27OO .-I-- 3150 3600 4050 L- I 45oo V 4950 54OO 5850 6300 6750 RKB Elevation: KOP 2.00 4.00 6.00 DLS: 2.00 deg per 100 ft 8.00 Beg 3/100 Blcl 13.00 16.00 19.00 DLS: .3.00 deg per 100 ft 22.00 28.00 Permafrost 34.00 40.00 46.00 52.00E0C Top Ugnu Base Ugnu Top West Sak Base West Sok 9 5/8 Casing Pt C80 TANGENT ANGLE 54.82 DEG C50 C40 C30 .'-,h,~ C20 _ _ "~,~ Base HRZ/7 Casing Target-Top C4/Kupg~~ K-1 Top C3 ,~%"h¢ Top C2 '~* Top C1 Top B Shole TD - Cosing Pt. [ i i i i i i ] i i i i ] i t i i i i i i ] i i i ] i i i i i i 450 900 1350 1800 2250 2700 3150 3600 4050 4500 4950 5400 5850 6300 6750 7200 Verficol Secfion (fee0 -> Azimuth 342.7'] with reference 0.00 N, 0.00 F from slot#9 RECEIVED FIB 2 1 2001 Alaska 0il & Gas Cons. Commission Anchorage Created by m~¢hoel For: T Mushovic ................. 00, Phillips Alaska, Plot Reference is 1J-G9 Verslon~12. :, · T,u* V*rficol O~p,h ...... , ...... RKB (,.~0,. ~ec). Structure : Pod 1J (WS r,,oU Well 9 ~iJ ~ Field : Kuparuk River Unit Location : North Slope, Alaska <- West (feet) 5250 4900 4550 4200 3850 3500 3150 2800 2450 2100 1750 1400 1050 700 350 0 350 [ I I I m I I I I I I I I i i I [ [ I i i I _ 342.77 AZIMUTH 6707' (TO TARGET) ***Plane of Proposal,u, TRUE RECEIVED TD LOCATION: TD C~sin~ Pt I 1825' FNL 669' FWL / ~ T;p I~Sh~ole ' I SEC. 26,T{1N, RIOE / ~Base HRZ/7 Casing Pt ~ c2o ~ C30 TARGET LOCATION: ~ I 2003' FNL, 724' FWL I ~se West Sok p Ugnu ~erm~frost ~ I sic. 3s, ,~, ~o[~ 2~s~' ~sL ~' ~[~ ~ FEB 1 ?nil1 Alaska Oil & Gas Cons. Commission Anchorage 7000 6650 6300 5950 5600 5250 4900 4550 4200 385o z 3500 0 3150 ~ --t- 2800 ~ 2450 2100 1750 1400 1050 7O0 350 350 c.~ote, ~ .~c~o.~ For T Mushovic Dote ¢ott¢cl: 14-Fe~-200~ PIol Reference ;s 1J-O9 Cooke;notes o~e ;n leer ~eleronce slot ~9. True vert;c~l Depths ore re~erence RKB (Nobors .............................................. Phillips Alaska, Inc. i 260 240 220 200 180 160 140 A 120 I lOO 8o '7 60 <- West (feet) 200 180 160 140 120 100 80 60 40 20 0 20 40 60 80 ~ 1400 \ \ \ ~. 1300 \ x)~. 1200 \ \ \ \ \ ~ 1100 ~ 3900 .................. ~. 3800 .................. ,,, ,3700 ................ ~.3600 ............... ,...~..5...0..0 x,~rm '~ 1 000 ................. ,~ 3300 ................... ~. 3t200 ................. ~,,..3,900 ...... ' .......... .~..3100 ~ ................. ~ 3000 .~ 900 .......... ~ 2900 '"'""..,. 3800 ~.~ 800 '"'"'~. 3700 \ "'"'-.~, 3600 ~t 700 ~ 600 ""'.-,, 3500 ~ 500 "'""'...... ~400 RECEIVED .... ........ FEB 1 2001 ...... "~ 3100 Alaska Oil & Gas Cons. Oommission Anchorage ooo .% 6 ' ~ ' i , , , , , , ' 8'0 ' 6'0 ' 4'0 ' 2~0 ' ' ' 2'0 ' 4~0 ' 6'0 ' 8'0 2 0 1 0 160 140 120 100 0 <- West (feet) ""'"x ~., 2800 N. "'" \' 'x,. 'x~, 2700 '""' ~'"" 'x,% 260 240 220 200 180 160 140 120 A I g lOO 0 --% I.i- 8O 60 'Phillips Alaska, Inc.' CreoteO ¥or T Mushovic: Structure : Pad 1J (WS Pilot) Well : 9 Oo~e plotlect: 14-Fe~-2001 i Plot Ret ...... is u-os v.~;o.12. [ Field : Kuparuk River Unit Location : North Slope, Alaska i Coor~[nc~tcs are ;n feet reference ~1ol ~9. ~True Yeti;COl Depths ore reference RKB (Nobors 16£). 18OO 1700 1600 1500 1400 1300 1200 11oo lOOO 900 800 700 600 5OO 400 300 <- West (feet) 1400 1300 1200 11 O0 1000 900 800 700 600 500 400 300 200 1 O00 1 O0 II I [ I I I I I II II II [ [ I I II I I t[ I[ I I RECEIVED 2OO FEB 2 1 ZOO1 Alaska Oil & Gas Oons. Oommission Anchorage 2500 \ \ \ \\ \ \ \ \ \ \ \ \\ ~ 2200 \ \ \\ \ \ \ \\ \ ~ 1900 \ \ \ \ \ \ \ \~ 1600 \ \ \ \ \ ~ 1300 \ 1800 1400 1300 1200 11 O0 1000 1700 1600 1500 1400 1300 1200 1100 1000 9OO 800 7O0 600 500 400 300 2OO ~,~[7~1......, ........ ~ 1 ooo 1 oo 3700 .......... ~ 3100 .... 4000 ,~ "..% , ~ ~ , , , ~ , ' 0 900 800 700 600 500 400 300 200 100 0 100 <- West (feet) Z croatia ~ m~ch~ l~or T Mushovie Plot Reforence is 1J-09 V~rs~n~2. Coor~ina~e~ ar~ ;n feet reference ~lot Ve~col Depths =~e ~eference RKB CNobors 16[).~ 'Phillips Alaska Inc : Structure : Pod 1J (WS Pilot) Well : 9 ' i Field : Kuparuk River Unit Location : North Slope, Aloskol <- West (feet) 5200 4800 4400 4000 3600 3200 2800 2400 2000 1600 1200 800 400 0 400 800 7200 I I I I I [ I I I I I I I I I I I I I I I I I ~ ~ II I I 7200 68OO 6400 6000 5600 52OO 48OO 4400 4ooo 3600 3200 2800 24O0 2000 1600 1200 8OO 400 6100 ~ 5800 \ \ \ ~ 5500 \ \ 5200 \\ \ ~ 4900 \ \ l, 4600 \ 4300 \ ~ 4000 ~ 3700 \ \ 6800 6400 6000 5600 5200 4800 4400 4000 Z O 3600 ~ :~- 3200 2800 3400 ~ 3100 \ ~, 2800 \ \ \ ~ 2500 \ \ ,2200 \ '~ ~9oo ~ , t_37_o_o L ~6oo ~,: 31oo " ,/2800 ~ .,ff2500 240o 2000 1600 1200 8OO 400 ~ i I I I i i ~ i i i i i i i i i i ii i i i i 5200 4800 4400 4000 3600 3200 2800 2400 2000 ' 1600 1200 800 400 0 400 800 <- West(feet) RECEIVED FEB B 1 2.001 Alaska Oil & Gas Oons. Oommission Anchorage c,,o~ ~ ~.~ For: T Mushovic i Dole plollec~: 14-Feb~2001 : P~ol Relerence ;s 1J-O9 Ver~ion~2. ', ITr~ V~rt~ol ~pths ~r~ r~lerence RKB (Nobor~ 16E}.' 330 32O Phillips Alaska, Inc. i Structure : Pad 1J (WS Pilot) Well : 9 Field : Kuparuk River Unit Location : North Slope, Alaska:: TRUE NORTH 350 0 10 340 20 5O 4O 510 5O 300 6O 290 7O 28O 8O 270 9O 260 100 250 110 240 230 soo~ 220 210 200 %~o 160 190 180 170 Normal Plane Travelling Cylinder - Feet All depths shown ore Measured depths on Reference Well 140 150 RECEIVED FEB 2 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot) 9 slot #9 Kuparuk River Unit North Slope, Alaska SUMMARY CLEARANCE REPORT by Baker Hughes INTEQ Your ref : 1J-09 Version#2 Our ref : prop4238 License : Date printed : 13-Feb-2001 Date created : 26-0ct-2000 Last revised : 13-Feb-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.699,w149 31 33.517 Slot Grid coordinates are N 5945963.299, E 558634.622 Slot local coordinates are 2152.86 N 2574.98 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Object wellpath MMS <0-4225'>,,WSP9,Pad 1J (WS Pilot) MMS <0-4182'>,,WSP3,Pad 1J (WS Pilot) MMS <0-4150'>,,WSPT,Pad 1J (WS Pilot) PGMS <0-4305'>,,WSP4,Pad 1J (WS Pilot) MMS <0-4130 >,,WSP5,Pad 1J (WS Pilot) PMSS <0-4200 >,,WSP6I,Pad 1J (WS Pilot) MMS <0-4100 >,,WSP10,Pad 1J (WS Pilot) PMSS <0-3976 >,,WSPllI,Pad 1J (WS Pilot) PMSS <0-4000 >,,WSP12,Pad 1J (WS Pilot) MMS <0-4140 >,,WSP13,Pad 1J (WS Pilot) MSS <0-4025'>,,WSP14I,Pad 1J (WS Pilot) MMS <0-4090'>,,WSP15I,Pad 1J (WS Pilot) PGMS <0-4135'>,,WSP20,Pad 1J (WS Pilot) TOTCO <0-4000'>,,WSP8I,Pad 1J (WS Pilot) TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) PGMS <0-3950'>,,WSP2,Pad 1J (WS Pilot) PMSS <0-???'>,,3,Pad 1J (WS Pilot) Closest approach with 3-D Minimum Distance method Last revised Distance M.D. Diverging from M.D. 19-Jan-2001 569.1 300.0 300.0 19-Jan-2001 254.7 0.0 0.0 19-Jan-2001 456.9 300.0 300.0 19-Jan-2001 298.7 312.5 312.5 19-Jan-2001 349.7 100.0 100.0 19-Jan-2001 402.4 0.0 0.0 19-Jan-2001 624.9 300.0 300.0 19-Jan-2001 684.2 300.0 300.0 19-Jan-2001 742.2 100.0 100.0 19-Jan-2001 800.3 300.0 300.0 19-Jan-2001 859.1 200.0 200.0 19-Jan-2001 189.6 100.0 100.0 19-Jan-2001 243.3 100.0 100.0 22-Jan-2001 511.5 325.0 325.0 22-Jan-2001 179.8 0.0 0.0 19-Jan-2001 215.9 0.0 0.0 13-Feb-2001 161.4 0.0 0.0 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage PhilliDs Alaska, Inc. Pad 1J (WS Pilot) 9 slot #9 Kuparuk River Unit North Slope, Alaska 3-D MINIMUM DISTANCE CLEARANCE INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ REPORT Your ref : 1J-09 Version#2 Our ref : prop4238 License : Date printed : 13-Feb-2001 Date created : 26-0ct-2000 Last revised : 13-Feb-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.699,w149 31 33.517 Slot Grid coordinates are N 5945963.299, E 558634.622 Slot local coordinates are 2152.86 N 2574.98 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North Report is limited to clearances less than 500 feet Proximities will incorporate ellipses - when survey tools are defined for both wells. Ellipse separation in reverse brackets, e.g. )10.2(, where available. DECREASING CLEARANCES of less than 1000 feet are indicated Object wellpath MMS <0-4225'> ,WSP9,Pad 1J (WS Pilot) MMS <0-4182'> ,WSP3,Pad 1J (WS Pilot) MMS <0-4150'> ,WSP7,Pad 1J (WS Pilot) PGMS <0-4305'> ,WSP4,Pad 1J (WS Pilot) MMS <0-4130'> PMSS <0-4200'> MMS <0-4100'> PMSS <0-3976'> PMSS <0-4000'> MMS <0-4140'> MSS <0-4025'>, MMS <0-4090'>, PGMS <0-4135'> ,WSP5,Pad 1J (WS Pilot) ,WSP6I,Pad 1J (WS Pilot) ,WSP10,Pad 1J (WS Pilot) ,WSPllI,Pad 1J (WS Pilot) ,WSP12,Pad 1J (WS Pilot) ,WSP13,Pad 1J (WS Pilot) WSP14I,Pad 1J (WS Pilot) WSP15I,Pad 1J (WS Pilot) ,WSP20,Pad 1J (WS Pilot) TOTCO <0-4000'> ,WSP8I,Pad 1J (WS Pilot) TOTCO <0-9346'> ,WSP1S,Pad 1J (WS Pilot) PGMS <0-3950'> ,WSP2,Pad 1J (WS Pilot) 1J-14 Version#8,,14,Pad 1J (WS Pilot) 1J-3 VersiOn #3,,3,Pad 1J (WS Pilot) PMSS <0-???'>,,3,Pad 1J (WS Pilot) Closest approach with 3-D Last revised Distance 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 19-Jan-2001 22-Jan-2001 22-Jan-2001 19-Jan-2001 13-Feb-2001 8-Feb-2001 13-Feb-2001 563.7 250.3 451.4 295.7 345.2 401.7 619.3 681.8 740.8( 795.1( 853.7( 185.2( 241.0( 511.5 179.8 214.4( 717.6( 159.1( 161.3( by an asterisk, e.g. 487.4* Minimum Distance method M.D. Diverging from M.D. 350.0 350.0 350.0 350.0 350.0 350.0 350.0 350.0 337.5 337.5 200.0 200.0 375.0 375.0 325.0 325.0 312.5 312.5 350.0 350.0 350.0 350.0 387.5 387.5 325.0 325.0 325.0 325.0 0.0 0.0 325.0 325.0 325.0 325.0 312.5 312.5 100.0 100.0 RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 1 Your ref : 1J-09 VersionS2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4182'>,,WSP3,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100 . 0 100.0 0 . 0N 200.0 200.0 0. ON 300.0 300.0 0. ON 312.5 312.5 0.0N 0.0E 0.0 9.0 133.1S 217.0E 121.5 254.7 N/A 0.0E 90.2 99.2 133.2S 217.1E 121.5 254.7 )253.2 0.0E 190.5 199.5 133.6S 217.2E 121.6 255.0 )251.8 0.0E 289.9 298.9 133.9S 217.5E 121.6 255.4 )250.6 0.0W 302.4 311.4 133.9S 217.5E 121.6 255.4 )250.5 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 0.0W 314.9 323.9 134.0S 217.5E 121.6 255.6 )250.4 0.1W 327.4 336.4 134.0S 217.6E 121.7 255.7 )250.3 0.1W 339.9 348.9 134.0S 217.6E 121.7 255.9 )250.3 0.2W 352.4 361.4 134.1S 217.7E 121.7 256.1 )250.3 0.3W 364.9 373.9 134.1S 217.7E 121.8 256.4 )250.4 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 0.4W 377.4 386.4 134.1S 217.7E 121.8 256.7 )250.5 0.5W 389.9 398.9 134.2S 217.8E 121.9 257.1 )250.6 0.7W 402.4 411.4 134.2S 217.8E 122.0 257.5 )250.8 0.8W 414.9 423.8 134.2S 217.9E 122.0 258.0 )251.0 1.0W 427.3 436.3 134.3S 217.9E 122.1 258.4 )251.2 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 1.2W 439.8 448.8 134.3S 218.0E 122.2 259.0 )251.5 1.4W 452.3 461.3 134.3S 218.0E 122.3 259.5 )251.9 1.6W 464.8 473.8 134.3S 218.0E 122.4 260.2 )252.3 1.8W 477.2 486.2 134.4S 218.1E 122.5 260.8 )252.7 2.1W 489.7 498.7 134.4S 218.1E 122.6 261.5 )253.1 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 2.3W 502.2 511.2 134.4S 218.2E 122.8 262.3 )253.6 2.6W 514.6 523.6 134.5S 218.2E 122.9 263.0 )254.2 2.9W 527.1 536.1 134.5S 218.3E 123.0 263.9 )254.8 3.2W 539.6 548.6 134.5S 218.3E 123.2 264.7 )255.4 3.6W 552.1 561.1 134.5S 218.4E 123.3 265.7 )256.1 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 3.9W 564.5 573.5 134.6S 218.4E 123.5 266.6 )256.8 4.3W 577.0 586.0 134.6S 218.4E 123.7 267.6 )257.5 4.6W 589.7 598.7 134.7S 218.5E 123.9 268.7 )258.3 5.0W 602.1 611.1 134.7S 218.5E 124.0 269.7 )259.2 5.5W 614.6 623.6 134.8S 218.5E 124.2 270.9 )260.0 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 5.9W 627.0 636.0 134.8S 218.5E 124.4 272.0 )261.0( 6.3W 639.4 648.4 134.8S 218.6E 124.6 273.2 )261.9( 6.8W 651.8 660.8 134.8S 218.6E 124.8 274.5 )262.9( 7.3W 664.2 673.2 134.9S 218.6E 125.0 275.8 )264.0( 7.8W 676.6 685.6 134.9S 218.6E 125.2 277.1 )265.1( 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 8.3W 689.5 698.5 134.9S 218.7E 125.4 278.5 )266.2 8.8W 701.8 710.8 134.9S 218.7E 125.7 279.9 )267.4 9.3W 714.2 723.2 134.9S 218.7E 125.9 281.4 )268.6 9.9W 726.6 735.6 134.8S 218.7E 126.1 282.9 )269.9 10.4W 738.9 747.9 134.8S 218.8E 126.3 284.5 )271.2 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N ii.0W 751.3 760.3 134.8S 218.8E 126.6 286.1 )272.5 ll.6W 763.6 772.6 134.8S 218.8E 126.8 287.7 )273.9 12.3W 776.0 785.0 134.7S 218.8E 127.0 289.4 )275.4 12.9W 788.3 797.3 134.7S 218.9E 127.3 291.2 )276.8 13.5W 799.3 808.3 134.7S 218.9E 127.5 292.8 )278.2 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 14.1W 810.2 819.2 134.6S 218.9E 127.7 294.4 )279.6 14.7W 821.1 830.1 134.6S 218.9E 127.9 296.2 )281.1 15.3W 832.0 841.0 134.6S 219.0E 128.2 297.9 )282.7 16.0W 842.4 851.4 134.6S 219.0E 128.4 299.8 )284.3 16.7W 853.3 862.3 134.6S 219.0E 128.6 301.7 )286.0 877.8 873.8 56.0N 17.4W 864.2 873.2 134.7S 219.0E 128.9 303.6 )287.7 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 2 Your ref : 1J-09 VersionS2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4182'>,,WSP3,Pad 1J (WS Pilot) M.D. T.V.D. 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 1000.0 992.3 1011.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 58.3N 18.1W 875.0 884.0 134.7S 60.6N 18.8W 885.8 894.8 134.7S 63.0N 19.5W 896.5 905.5 134.8S 65.5N 20.3W 907.3 916.3 134.8S 68.0N 21.1W 918.0 927.0 134.9S 70.6N 21.9W 928.8 937.8 134.9S 73.3N 22.7W 939.6 948.5 134.9S 76.0N 23.6W 950.3 959.3 135.0S 78.8N 24.4W 960.5 969.4 135.0S 81.6N 25.3W 971.2 980.1 135.1S 84.5N 26.2W 981.8 990.8 135.1S 87.5N 27.1W 991.2 1000.2 135.1S 90.5N 28.1W 1001.9 1010.9 135.2S 93.6N 29.0W 1012.5 1021.5 135.2S 96.7N 30.0W 1022.1 1031.1 135.2S 99.9N 31.0W 1032.7 1041.7 135.1S 103.1N 32.0W 1043.3 1052.2 135.1S 106.4N 33.0W 1053.1 1062.0 135.0S 109.8N 34.1W 1063.6 1072.6 134.9S 113.2N 35.1W 1074.1 1083.1 134.8S 116.7N 36.2W 1084.9 1093.9 134.6S 120.3N 37.3W 1095.4 1104.4 134.4S 123.9N 38.4W 1105.9 1114.8 134.1S 127.5N 39.6W 1117.7 1126.6 133.8S 131.2N 40.7W 1128.1 1137.1 133.5S 135.0N 41.9W 1138.6 1147.5 133.1S 138.8N 43.1W 1149.9 1158.8 132.6S 142.7N 44.3W 1160.4 1169.2 132.2S 146.7N 45.5W 1171.3 1180.1 131.7S 150.7N 46.7W 1181.7 1190.5 131.1S 154.7N 48.0W 1192.6 1201.3 130.5S 158.9N 49.3W 1202.9 1211.6 129.9S 163.0N 50.6W 1213.1 1221.8 129.2S 167.3N 51.9W 1223.4 1232.0 128.5S 171.6N 53.2W 1232.8 1241.4 127.8S 175.9N 54.6W 1243.1 1251.6 127.1S 180.3N 55.9W 1252.4 1260.9 126.3S 184.8N 57.3W 1262.7 1271.0 125.5S 189.3N 58.7W 1270.7 1279.0 124.8S 193.8N 60.1W 1280.9 1289.0 124.0S 198.5N 61.6W 1287.5 1295.6 123.4S 203.1N 63.0W 1297.6 1305.6 122.5S 207.9N 64.5W 1307.6 1315.5 121.6S 212.7N 66.0W 1314.1 1321.9 121.1S 217.5N 67.5W 1324.1 1331.7 120.2S 222.4N 69.0W 1330.2 1337.8 119.6S 227.4N 70.5W 1340.1 1347.6 118.8S 232.4N 72.1W 1350.0 1357.3 117.9S 237.4N 73.6W 1355.9 1363.1 117.4S 242.6N 75.2W 1365.7 1372.7 116.5S 76.8W 1371.4 1378.3 247.7N 219.0E 129.1 305.7 )289.5 219.0E 129.4 307.7 )291.4 219.0E 129.7 309.9 )293.3 219.0E 129.9 312.1 )295.3 219.0E 130.2 314.4 )297.3 219.0E 130.5 316.7 219.0E 130.7 319.1 219.0E 131.0 321.5 219.0E 131.3 324.0 219.0E 131.6 326.6 299.4 301.5 303.7 306.0 308.4 219.0E 131.8 329.2 219.1E 132.1 331.9 219.2E 132.4 334.7 219.3E 132.6 337.6 219.4E 132.9 340.6 219.6E 133.2 343.6 219.8E 133.4 346.6 220.0E 133.7 349.8 220.3E 133.9 353.0 220.6E 134.1 356.3 221.0E 134.3 359.6 221.4E 134.5 363.0 221.8E 134.8 366.5 222.3E 134.9 369.9 222.8E 135.1 373.5 223.2E 135.3 377.0 223.8E 135.5 380.7 224.3E 135.7 384.3 224.9E 135.8 388.1 225.5E 136.0 391.8 226.2E 136.1 395.6 226.8E 136.3 399.5 227.5E 136.4 403.4 228.3E 136.6 407.4 229.0E 136.7 411.5 310.8 313.3 315.9 318.5 321.2 324.1 327.1 330.1 333.2 336.4 339.6 342.8 346.2 349.5 352.9 356.4 359.9 363.4 367.0 370.6 374.3 378.1 381.9 385.8 389.7 229.9E 136.8 415.6 )393.7 230.7E 136.9 419.8 )397.8 231.7E 137.0 424.0 )401.9 232.5E 137.2 428.3 )406.1 233.6E 137.3 432.8 )410.4 234.3E 137.4 437.3 )414.8 235.5E 137.5 441.8 )419.2 236.7E 137.6 446.5 )423.8 237.6E 137.7 451.3 )428.4 238.9E 137.8 456.1 )433.1 239.7E 137.9 461.0 )437.9 241.2E 138.0 466.0 )442.8 242.6E 138.1 471.1 )447.8 243.5E 138.2 476.3 )452.9 245.1E 138.3 481.6 )458.0 116.0S 246.0E 138.4 486.9 )463.2 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 3 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4182'>,,WSP3,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 1455.6 1411.1 253.0N 78.5W 1381.0 1387.8 115.2S 247.6E 138.5 492.3 )468.6 1466.7 1420.8 258.2N 80.1W 1390.0 1396.6 114.4S 249.2E 138.5 497.9 )473.9 1477.8 1430.4 263.6N 81.7W 1396.0 1402.5 113.9S 250.2E 138.7 503.4 )479.4 1488.9 1439.9 269.0N 83.4W 1405.5 1411.8 113.0S 251.9E 138.7 509.1 )485.0 1500.0 1449.5 274.4N 85.1W 1415.0 1421.1 112.2S 253.7E 138.8 514.8 )490.6 1510.9 1458.8 279.8N 86.8W 1419.7 1425.7 111.8S 254.6E 138.9 520.5 )496.2 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB B 1, 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 4 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4150'>,,WSP7,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100 . 0 100.0 0 . 0N 200 . 0 200.0 0 . ON 300 . 0 300.0 0 . ON 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 56.0N 0.0E 8.0 0.0 366.3S 273.0E 143.3 456.9 N/A 0.0E 108.0 100.0 366.3S 273.0E 143.3 456.9 )455.2( 0.0E 208.0 200.0 366.3S 273.0E 143.3 456.9 )453.5( 0.0E 308.0 300.0 366.3S 273.0E 143.3 456.9 )451.9( 0.0W 320.5 312.5 366.3S 273.0E 143.3 456.9 )451.7( 0.0W 333.0 325.0 366.3S 273.0E 143.3 457.0 )451.6( 0.1W 345.5 337.5 366.3S 273.0E 143.3 457.1 )451.5( 0.1W 358.0 350.0 366.3S 273.0E 143.3 457.3 )451.4( 0.2W 370.5 362.5 366.3S 273.0E 143.3 457.5 )451.4( 0.3W 383.0 375.0 366.3S 273.0E 143.3 457.8 )451.5( 0.4W 395.5 387.5 366.3S 273.0E 143.4 458.1 )451.6( 0.5W 408.0 400.0 366.3S 273.0E 143.4 458.5 )451.8( 0.TW 420.5 412.5 366.3S 273.0E 143.4 459.0 )451.9( 0.8W 433.0 425.0 366.3S 273.0E 143.4 459.5 )452.2( 1.0W 445.4 437.4 366.3S 273.0E 143.4 460.0 )452.5( 1 2W 457.9 449.9 366.3S 273.0E 143.5 460.6 )452.8( 1 4W 470.4 462.4 366.3S 273.0E 143.5 461.2 )453.2( 1 6W 482.9 474.9 366.3S 273.0E 143.5 461.9 )453.7( 1 8W 495.4 487.4 366.3S 273.0E 143.6 462.7 )454.2( 2 1W 507.8 499.8 366.3S 273.0E 143.6 463.5 )454.7( 2 3W 520.3 512.3 366.3S 273.0E 143.6 464.3 )455.3( 2 6W 532.8 524.8 366.3S 273.0E 143.7 465.2 )455.9( 2 9W 545.2 537.2 366.3S 273.0E 143.7 466.2 )456.6( 3 2W 557.7 549.7 366.3S 273.0E 143.7 467.2 )457.4( 3 6W 570.1 562.1 366.3S 273.0E 143.8 468.2 )458.2( 3.9W 582.6 574.6 366.3S 273.0E 143.8 469.3 )459.0( 4.3W 595.0 587.0 366.3S 273.0E 143.9 470.5 )459.9( 4.6W 607.5 599.5 366.3S 273.0E 143.9 471.7 )460.9( 5.0W 619.9 611.9 366.3S 273.0E 144.0 473.0 )461.9( 5.5W 632.3 624.3 366.3S 273.0E 144.0 474.3 )463.0( 5.9W 644.7 636.7 366.3S 273.0E 144.1 475.7 )464.1( 6.3W 657.1 649.1 366.3S 273.0E 144.2 477.1 )465.2( 6.8W 669.5 661.5 366.3S 273.0E 144.2 478.5 )466.4( 7.3W 681.9 673.9 366.3S 273.0E 144.3 480.1 )467.7( 7.8W 694.3 686.3 366.3S 273.0E 144.3 481.6 )469.0( 8.3W 706.7 698.7 366.3S 273.0E 144.4 483.3 )470.4( 8.8W 719.1 711.1 366.3S 273.0E 144.5 484.9 )471.8( 9.3W 731.4 723.4 366.3S 273.0E 144.5 486.7 )473.3( 9.9W 743.8 735.8 366.3S 273.0E 144.6 488.4 )474.8( 10.4W 756.2 748.2 366.3S 273.0E 144.7 490.3 )476.4( ll.0W 768.5 760.5 366.3S 273.0E 144.7 492.2 )478.0( ll.6W 780.8 772.8 366.3S 273.0E 144.8 494.1 )479.7( 12.3W 793.2 785.2 366.3S 273.0E 144.9 496.1 )481.4( 12.9W 805.5 797.5 366.3S 273.0E 145.0 498.1 )483.2( 13.5W 816.4 808.4 366.3S 273.0E 145.0 500.0 )484.8( 14.1W 827.3 819.3 366.3S 273.0E 145.1 501.9 )486.5( 14.7W 838.2 830.2 366.3S 273.0E 145.2 503.9 )488.3( 15.3W 849.1 841.1 366.3S 273.0E 145.3 506.0 )490.1( 16.0W 860.0 852.0 366.3S 273.0E 145.3 508.1 )492.0( 16.7W 870.9 862.9 366.3S 273.0E 145.4 510.3 )493.9( 17.4W 881.8 873.8 366.3S 273.0E 145.5 512.5 )495.9( All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 3 2001 Alaska Oil & Gas Cons. Commissior~ Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 5 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4150'>,,WSP7,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 888.9 884.6 58.3N 18.1W 892.6 884.6 366.3S 273.0E 145.6 514.8 )498.0( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 6 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <0-4305'>,,WSP4,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 O.0 0.0N 100.0 100 . 0 0 . 0N 200 . 0 200 . 0 0 . ON 300 . 0 300 . 0 0 . 0N 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 0.0E 3.5 0.5 191.6S 231.0E 129.7 300.1 N/A 0.0E 104.9 101.9 191.8S 230.2E 129.8 299.7* )298.8 0.0E 204.3 201.3 192.4S 229.1E 130.0 299.1' )297.3 0.0E 304.0 301.0 192.9S 228.1E 130.2 298.7* )296.0 0.0W 316.5 313.5 193.0S 228.0E 130.3 298.7* )295.8 0.0W 329.0 326.0 193.1S 227.9E 130.3 298.8 )295.7 0.1W 341.5 338.5 193.1S 227.8E 130.3 298.8 )295.7 0.1W 354.1 351.1 193.2S 227.7E 130.4 298.9 )295.7 0.2W 366.6 363.6 193.2S 227.6E 130.4 299.1 )295.7 0.3W 379.1 376.1 193.3S 227.5E 130.5 299.3 )295.8 0.4W 391.6 388.6 193.3S 227.4E 130.5 299.6 )295.9 0.5W 404.3 401.3 193.3S 227.3E 130.6 299.9 )296.0 0.7W 416.8 413.8 193.4S 227.2E 130.6 300.2 )296.2 0.8W 429.3 426.3 193.4S 227.1E 130.7 300.6 )296.5 1.0W 441.8 438.8 193.4S 227.0E 130.8 301.0 )296.7 1.2W 454.3 451.3 193.5S 226.9E 130.9 301.5 )297.1 1.4W 466.8 463.8 193.5S 226.8E 130.9 302.0 )297.4 1.6W 479.3 476.2 193.5S 226.7E 131.0 302.6 )297.9 1.8W 491.7 488.7 193.5S 226.6E 131.1 303.2 )298.3 2.1W 504.2 501.2 193.6S 226.5E 131.2 303.9 )298.8 2.3W 516.7 513.6 193.6S 226.4E 131.3 304.6 )299.4 2.6W 529.1 526.1 193.6S 226.3E 131.4 305.3 )300.0 2.9W 541.6 538.6 193.6S 226.2E 131.5 306.1 )300.6 3.2W 553.7 550.7 193.6S 226.1E 131.7 307.0 )301.3 3.6W 566.2 563.2 193.7S 226.0E 131.8 307.9 )302.1 3.9W 578.6 575.6 193.7S 226.0E 131.9 308.9 )302.9 4.3W 591.1 588.0 193.7S 225.9E 132.0 309.9 )303.7 4.6W 603.3 600.2 193.7S 225.8E 132.2 310.9 )304.6 5.0W 615.7 612.7 193.8S 225.8E 132.3 312.1 )305.6 5.5W 628.1 625.1 193.8S 225.7E 132.4 313.2 )306.6 5.9W 640.5 637.5 193.8S 225.6E 132.6 314.4 )307.6 6.3W 653.0 649.9 193.8S 225.6E 132.7 315.7 )308.7 6.8W 665.4 662.3 193.8S 225.5E 132.9 317.0 )309.9 7.3W 677.8 674.7 193.9S 225.5E 133.0 318.4 )311.1 7.8W 690.1 687.1 193.9S 225.4E 133.2 319.8 )312.3 8.3W 702.5 699.4 193.9S 225.4E 133.3 321.3 )313.6 8.8W 714.8 711.8 193.9S 225.3E 133.5 322.8 )315.0 9.3W 727.2 724.2 193.9S 225.2E 133.7 324.3 )316.3 9.9W 739.6 736.5 193.9S 225.2E 133.8 325.9 )317.8 10.4W 751.9 748.9 194.0S 225.1E 134.0 327.6 )319.3 ii.0W 764.3 761.2 194.0S 225.1E 134.2 329.3 )320.8 ll.6W 776.6 773.6 194.0S 225.0E 134.4 331.1 )322.4 12.3W 788.9 785.9 194.0S 224.9E 134.6 332.9 )324.1 12.9W 801.0 798.0 194.1S 224.9E 134.7 334.8 )325.8 13.5W 811.9 808.9 194.1S 224.8E 134.9 336.5 )327.3 14.1W 822.9 819.8 194.1S 224.8E 135.1 338.2 )328.9 14.7W 833.8 830.7 194.1S 224.7E 135.2 340.1 )330.6 15.3W 844.7 841.6 194.2S 224.7E 135.4 342.0 )332.4 16.0W 855.1 852.1 194.2S 224.6E 135.6 343.9 )334.2 16.7W 866.0 863.0 194.2S 224.6E 135.8 346.0 )336.0 56.0N 17.4W 876.9 873.8 194.2S 224.6E 136.0 348.0 )338.0 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level) Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB .1. 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 7 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <O-4305'>,,WSP4,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 58.3N 18.1W 887.7 884.7 194.3S 60.6N 18.8W 898.1 895.0 194.3S 63.0N 19.5W 908.9 905.9 194.3S 65.5N 20.3W 919.7 916.7 194.3S 68.0N 21.1W 930.5 927.4 194.4S 224.6E 136.1 350.2 )340.0 224.5E 136.3 352.4 )342.0 224.5E 136.5 354.7 )344.2 224.5E 136.7 357.0 )346.3 224.5E 136.9 359.4 )348.6 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 70.6N 21.9W 941.2 938.2 194.4S 73.3N 22.7W 951.5 948.4 194.5S 76.0N 23.6W 962.2 959.1 194.5S 78.8N 24.4W 972.9 969.9 194.5S 81.6N 25.3W 983.6 980.6 194.6S 224.5E 137.1 361.9 )350.9 224.4E 137.3 364.4 )353.3 224.4E 137.5 367.0 )355.7 224.4E 137.7 369.6 )358.2 224.4E 137.9 372.4 )360.8 1000.0 992.3 1011.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 84.5N 26.2W 994.3 991.2 194.6S 87.5N 27.1W 1004.6 1001.5 194.7S 90.5N 28.1W 1015.2 1012.2 194.8S 93.6N 29.0W 1025.8 1022.8 194.8S 96.7N' 30.0W 1036.4 1033.4 194.9S 224.4E 138.1 375.2 )363.4 224.4E 138.3 378.0 )366.1 224.4E 138.5 380.9 )368.9 224.4E 138.7 383.9 )371.7 224.4E 138.9 386.9 99.9N 31.0W 1047.0 1044.0 194.9S 224.4E 139.1 390.0 103.1N 32.0W 1057.6 1054.5 195.0S 224.4E 139.3 393.2 106.4N 33.0W 1068.1 1065.1 195.0S 224.4E 139.5 396.4 109.8N 34.1W 1078.6 1075.6 195.1S 224.4E 139.7 399.7 113.2N 35.1W 1089.1 1086.1 195.2S 224.3E 139.9 403.0 116.7N 36.2W 1099.2 1096.2 195.2S 224.3E 140.1 406.4 120.3N 37.3W 1109.6 1106.6 195.3S 224.3E 140.3 409.9 123.9N 38.4W 1120.1 1117.0 195.3S 224.3E 140.5 413.4 127.5N 39.6W 1130.5 1127.4 195.4S 224.3E 140.7 417.0 131.2N 40.7W 1140.9 1137.8 195.5S 224.4E 140.9 420.7 135.0N 41.9W 1150.6 1147.6 195.5S 224.4E 141.1 424.4 138.8N 43.1W 1160.9 1157.9 195.6S 224.4E 141.4 428.2 142.7N 44.3W 1171.3 1168.2 195.7S 224.4E 141.6 432.1 146.7N 45.5W 1181.5 1178.5 195.7S 224.4E 141.8 436.0 150.7N 46.7W 1191.8 1188.8 195.8S 224.4E 142.0 440.0 154.7N 48.0W 1201.8 1198.8 195.9S 224.5E 142.2 444.0 158.9N 49.3W 1212.1 1209.0 195.9S 224.5E 142.3 448.1 163.0N 50.6W 1222.2 1219.2 196.0S 224.5E 142.5 452.3 167.3N 51.9W 1232.4 1229.4 196.1S 224.5E 142.7 456.5 171.6N 53.2W 1242.5 1239.5 196.2S 224.5E 142.9 460.8 175.9N 54.6W 1252.6 1249.6 196.2S 224.6E 143.1 465.2 180.3N 55.9W 1262.7 1259.7 196.3S 224.6E 143.3 469.6 184.8N 57.3W 1272.8 1269.7 196.4S 224.6E 143.5 474.1 189.3N 58.7W 1282.8 1279.7 196.5S 224.6E 143.7 478.6 193.8N 60.1W 1292.8 1289.7 196.5S 224.6E 143.9 483.2 198.5N 61.6W 1302.6 1299.6 196.6S 224.6E 144.1 487.8 203.1N 63.0W 1312.5 1309.5 196.7S 224.6E 144.3 492.6 207.9N 64.5W 1322.4 1319.4 196.8S 224.6E 144.5 497.3 212.7N 66.0W 1332.3 1329.3 196.8S 224.6E 144.6 502.2 217.5N 67.5W 1342.2 1339.1 196.9S 224.7E 144.8 507.0 222.4N 69.0W 1352.0 1348.9 197.0S 224.7E 145.0 512.0 227.4N 70.5W 1361.8 1358.7 197.1S 224.7E 145.2 517.0 374.6 377.5 380.5 383.6 386.7 389.9 393.2 396.5 399.9 403.3 406.8 410.4( 414.0( 417.7 ( 421.5( 425.3( 429.2( 433.2( 437.2( 441.3( 445.4( 449.6( 453.9( 458.2( 462.6( 467.0( 471.5( 476.1 480.7 485.4 490.1 494.9 499.8 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 1 00t Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARA/qCE LISTING Page 8 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : M_MS <0-4130'>,,WSP5,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100.0 100 . 0 0 . ON 200 . 0 200 . 0 0 . ON 300 . 0 300 . 0 0 . ON 312 . 5 312 . 5 0. ON 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 tg.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 56.0N 0.0E 8.0 0.0 249.6S 244.9E 135.5 349.7 N/A 0.0E 108.0 100.0 249.6S 244.9E 135.5 349.7 348.0 0.0E 207.1 199.1 249.7S 244.9E 135.6 349.7 346.4 0.0E 305.1 297.1 250.5S 245.0E 135.6 350.3 345.4 0.0W 317.6 309.6 250.6S 245.0E 135.7 350.5 345.3 0.0W 330.1 322.1 250.7S 245.0E 135.7 350.6 0.1W 343.7 335.7 250.8S 245.0E 135.7 350.8 0.1W 356.2 348.2 250.9S 245.0E 135.7 351.1 0.2W 368.7 360.7 251.0S 245.0E 135.7 351.4 0.3W 381.7 373.7 251.1S 245.0E 135.8 351.7 0.4W 394.2 386.2 251.1S 245.0E 135.8 352.0 0.5W 406.7 398.7 251.2S 245.0E 135.8 352.4 0.7W 419.2 411.2 251.2S 245.0E 135.9 352.9 0.8W 431.7 423.7 251.3S 245.0E 135.9 353.4 1.0W 444.2 436.2 251.3S 245.0E 136.0 354.0 1.2W 456.7 448.6 251.4S 245.1E 136.0 354.6 1.4W 469.1 461.1 251.4S 245.1E 136.1 355.2 1.6W 481.5 473.5 251.5S 245.1E 136.1 355.9 1.8W 494.0 486.0 251.5S 245.1E 136.2 356.7 2.1W 506.4 498.4 251.6S 245.1E 136.3 357.5 2.3W 518.9 510.9 251.6S 245.1E 136.3 358.3 2.6W 531.3 523.3 251.7S 245.2E 136.4 359.2 2.9W 543.7 535.7 251.7S 245.2E 136.5 360.2 3.2W 556.2 548.2 251.8S 245.2E 136.5 361.2 3.6W 569.0 560.9 251.8S 245.3E 136.6 362.3 3.9W 581.4 573.4 251.8S 245.3E 136.7 363.4 4.3W 593.8 585.8 251.9S 245.3E 136.8 364.5 4.6W 606.3 598.3 251.9S 245.4E 136.9 365.7 5.0W 619.5 611.5 251.9S 245.4E 137.0 366.9 5.5W 631.9 623.9 251.9S 245.4E 137.1 368.2 5.9W 644.3 636.3 251.9S 245.4E 137.2 369.5 6.3W 657.1 649.1 251.9S 245.4E 137.3 370.9 6.8W 669.5 661.5 251.9S 245.4E 137.4 372.3 7.3W 681.9 673.9 251.9S 245.4E 137.5 373.7 7.8W 694.3 686.3 251.9S 245.4E 137.6 375.2 8.3W 706.7 698.7 251.9S 245.4E 137.7 376.8 345.3 345.2 345.2 345.3 345.4 345.5 345.7 345.9 346.2 346.5 346.9 347.3 347.7 348.2 348.8 349.4 350.1 350.8 351.5 352.3 353.2 354.1 355.0 355.9 357.0 358.0 359.1 360.3 361.5 362.7 364.0 8.8W 719.1 711.1 251.9S 245.4E 137.8 378.4 )365.3 9.3W 731.5 723.4 251.9S 245.4E 137.9 380.0 )366.7 9.9W 743.8 735.8 251.9S 245.4E 138.0 381.7 )368.2 10.4W 756.2 748.2 251.9S 245.4E 138.1 383.5 )369.7 ll.0W 768.5 760.5 251.9S 245.4E 138.3 385.3 )371.2 ll.6W 780.8 772.8 251.9S 245.4E 138.4 387.1 )372.8 12.3W 793.2 785.2 251.9S 245.4E 138.5 389.0 )374.5 12.9W 805.5 797.5 251.9S 245.4E 138.7 391.0 )376.1 13.5W 816.4 808.4 251.9S 245.4E 138.8 392.8 )377.7 14.1W 827.3 819.3 251.9S 245.4E 138.9 394.6 )379.3 14.7W 838.2 830.2 251.9S 245.4E 139.0 396.5 )381.0 15.3W 849.1 841.1 251.9S 245.4E 139.1 398.5 )382.8 16.0W 860.0 852.0 251.9S 245.4E 139.3 400.5 )384.6 16.7W 870.9 862.9 251.9S 245.4E 139.4 402.6 )386.4 17.4W 881.8 873.8 251.9S 245.4E 139.5 404.8 )388.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 3 ]. ZO0 Alaska Oil & Gas Oons. Oommission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 9 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4130'>,,WSP5,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 888.9 884.6 58.3N 18.1W 892.6 884.6 251.9S 900.0 895.4 60.6N 18.8W 903.5 895.4 251.9S 911.1 906.3 63.0N 19.5W 914.3 906.3 251.9S 922.2 917.1 65.5N 20.3W 925.1 917.1 251.9S 933.3 927.9 68.0N 21.1W 935.9 927.9 251.9S 245.4E 139.7 407.0 )390.3( 245.4E 139.8 409.3 )392.4( 245.4E 139.9 411.6 )394.5( 245.4E 140.1 414.0 )396.6( 245.4E 140.2 416.4 )398.8( 944.4 938.6 70.6N 21.9W 946.3 938.3 251.9S 955.6 949.4 73.3N 22.7W 957.1 949.1 251.9S 966.7 960.1 76.0N 23.6W 967.8 959.8 252.0S 977.8 970.9 78.8N 24.4W 978.6 970.5 252.0S 988.9 981.6 81.6N 25.3W 988.6 980.6 252.0S 245.4E 140.4 419.0 )401.1( 245.4E 140.5 421.5 )403.5( 245.4E 140.6 424.2 )405.9( 245.4E 140.8 426.9 )408.4( 245.5E 140.9 429.6 )410.9( 1000.0 992.3 84.5N 26.2W 999.3 991.3 252.0S 1011.1 1002.9 87.5N 27.1W 1010.0 1002.0 252.0S 1022.2 1013.6 90.5N 28.1W 1020.6 1012.6 252.0S 1033.3 1024.2 93.6N 29.0W 1031.3 1023.3 252.0S 1044.4 1034.8 96.7N 30.0W 1041.9 1033.9 252.0S 245.5E 141.1 432.5 )413.5 245.5E 141.2 435.4 )416.2 245.6E 141.4 438.3 )418.9 245.6E 141.5 441.4 )421.7 245.6E 141.7 444.5 )424.6 1055.6 1045.4 99.9N 31.0W 1052.5 1044.5 252.0S 1066.7 1056.0 103.1N 32.0W 1063.1 1055.0 252.0S 1077.8 1066.6 106.4N 33.0W 1073.6 1065.6 252.0S 1088.9 1077.1 109.8N 34.1W 1084.8 1076.8 252.0S 1100.0 1087.6 113.2N 35.1W 1095.3 1087.3 252.0S 245.7E 141.8 447.6 )427.5 245.7E 142.0 450.8 )430.5 245.7E 142.1 454.1 )433.5 245.8E 142.3 457.4 )436.6 245.8E 142.4 460.7 )439.7 1111.1 1098.1 116.7N 36.2W 1105.8 1097.8 252.0S 1122.2 1108.6 120.3N 37.3W 1116.3 1108.3 252.0S 1133.3 1119.0 123.9N 38.4W 1126.6 1118.6 252.0S 1144.4 1129.5 127.5N 39.6W 1137.1 1129.0 252.0S 1155.6 1139.9 131.2N 40.7W 1147.5 1139.5 252.0S 245.8E 142.6 464.2 )442.9 245.8E 142.7 467.7 )446.2 245.8E 142.9 471.2 )449.5 245.8E 143.1 474.8 )452.9 245.8E 143.2 478.5 )456.3 1166.7 1150.3 135.0N 41.9W 1157.9 1149.8 252.0S 1177.8 1160.6 138.8N 43.1W 1168.2 1160.2 251.9S 1188.9 1171.0 142.7N 44.3W 1177.7 1169.7 251.9S 1200.0 1181.3 146.7N 45.5W 1188.0 1180.0 251.9S 1211.1 1191.6 150.7N 46.7W 1198.3 1190.3 251.9S 245.9E 143.4 482.2 )459.8 245.9E 143.5 486.0 )463.4 245.9E 143.7 489.9 )467.1 246.0E 143.8 493.8 )470.8 246.1E 144.0 497.8 )474.5 1222.2 1201.8 154.7N 48.0W 1208.6 1200.6 251.9S 1233.3 1212.1 158.9N 49.3W 1217.9 1209.9 251.9S 1244.4 1222.3 163.0N 50.6W 1228.1 1220.1 251.9S 1255.6 1232.5 167.3N 51.9W 1238.3 1230.2 251.8S 1266.7 1242.6 171.6N 53.2W 1248.4 1240.4 251.8S 246.1E 144.1 501.9 )478.4 246.2E 144.3 506.0 )482.3 246.3E 144.4 510.2 )486.2 246.4E 144.6 514.4 )490.2 246.5E 144.7 518.7 )494.3 1277.8 1252.8 175.9N 54.6W 1258.5 1250.5 251.8S 246.6E 144.9 523.1 )498.5 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 10 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PMSS <0-4200'>,,WSP6I,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100.0 100 . 0 0 . ON 200 . 0 200 . 0 0 . ON 300 . 0 300 . 0 0 . ON 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 56.0N 0.0E 7.9 -0.1 308.0S 259.0E 139.9 402.4 0.0E 106.7 98.7 307.8S 259.4E 139.9 402.5 0.0E 204.5 196.5 308.1S 260.1E 139.8 403.2 0.0E 304.1 296.1 308.7S 260.7E 139.8 404.1 0.0W 315.8 307.8 308.8S 260.8E 139.8 404.2 0.0W 328.3 320.3 308.9S 261.0E 139.8 404.5 0.1W 340.8 332.8 308.9S 261.1E 139.8 404.7 0.1W 353.3 345.3 309.0S 261.2E 139.8 405.1 0.2W 365.6 357.6 309.1S 261.3E 139.8 405.4 0.3W 378.1 370.1 309.2S 261.5E 139.8 405.9 0.4W 390.6 382.6 309.3S 261.6E 139.8 406.3 0.5W 403.1 395.1 309.3S 261.8E 139.9 406.9 0.7W 416.0 407.9 309.4S 261.9E 139.9 407.4 0.SW 428.4 420.4 309.5S 262.1E 139.9 408.1 1.0W 440.9 432.9 309.5S 262.2E 139.9 408.7 1.2W 453.9 445.9 309.6S 262.4E 139.9 409.4 1.4W 466.4 458.4 309.6S 262.5E 140.0 410.2 1.6W 478.9 470.8 309.6S 262.7E 140.0 411.0 1.8W 491.3 483.3 309.6S 262.9E 140.0 411.8 2.1W 504.5 496.4 309.7S 263.0E 140.0 412.7 2.3W 516.9 508.9 309.7S 263.2E 140.1 413.7 2.6W 529.4 521.4 309.7S 263.4E 140.1 414.6 2.9W 541.8 533.8 309.6S 263.5E 140.1 415.7 3.2W 554.3 546.3 309.6S 263.7E 140.2 416.7 3.6W 566.7 558.7 309.6S 263.8E 140.2 417.9 3.9W 579.2 571.1 309.6S 264.0E 140.3 419.1 4.3W 590.9 582.9 309.6S 264.2E 140.3 420.3 4.6W 603.4 595.3 309.7S 264.3E 140.4 421.6 5.0W 615.8 607.7 309.7S 264.5E 140.4 423.0 5.5W 628.2 620.2 309.7S 264.6E 140.5 424.4 5.9W 640.6 632.5 309.7S 264.8E 140.5 425.8 6.3W 653.0 644.9 309.8S 264.9E 140.6 427.3 6.8W 665.4 657.3 309.8S 265.1E 140.7 428.9 7.3W 677.8 669.7 309.8S 265.3E 140.7 430.5 7.8W 690.8 682.8 309.8S 265.4E 140.8 432.2 8.3W 703.2 695.1 309.8S 265.6E 140.9 433.8 8.8W 715.5 707.5 309.8S 265.7E 140.9 435.6 9.3W 727.9 719.9 309.8S 265.9E 141.0 437.4 9.9W 740.2 732.2 309.8S 266.1E 141.1 439.2 10.4W 752.6 744.5 309.8S 266.2E 141.1 441.1 ll.0W 764.9 756.9 309.8S 266.4E 141.2 443.0 ll.6W 777.2 769.2 309.8S 266.6E 141.3 445.0 12.3W 789.6 781.5 309.8S 266.7E 141.4 447.1 12.9W 801.9 793.8 309.8S 266.9E 141.5 449.2 13.5W 812.8 804.7 309.8S 267.0E 141.6 451.1 14.1W 823.1 815.0 309.8S 267.2E 141.6 453.1 14.7W 834.0 825.9 309.9S 267.3E 141.7 455.1 15.3W 844.9 836.8 309.9S 267.4E 141.8 457.2 16.0W 855.7 847.7 309.9S 267.6E 141.9 459.4 N/A 401.8 401.7 401.9 401.9 402.0 402.2 402.4 402.6 403.0 403.3 403.7 404.2 404.6 405.2 405.8 406.4 407.0 407.8 408.5 409.3 410.1 411.0 412.0 412.9 414.0 415.1 416.2 417.4 418.7 420.0 421.4 422.8 424.2 425.7 427.3 428.9 430.5 432.2 433.9 435.7 437.6 439.5 441.4 443.2 445.1 447.0 449.0 451.0 16.7W 866.1 858.0 309.9S 267.7E 142.0 461.7 )453.1 17.4W 876.9 868.9 310.0S 267.8E 142.1 464.0 )455.3 All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 2 1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 11 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PMSS <0-4200'>,,WSP6I,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 888.9 884.6 58.3N 18.1W 887.7 879.7 310.0S 900.0 895.4 60.6N 18.8W 898.6 890.5 310.0S 911.1 906.3 63.0N 19.5W 909.0 900.9 310.1S 922.2 917.1 65.5N 20.3W 919.7 911.7 310.1S 933.3 927.9 68.0N 21.1W 930.5 922.4 310.2S 268.0E 142.2 466.3 )457.5( 268.1E 142.3 468.7 )459.8( 268.2E 142.4 471.2 )462.2( 268.4E 142.5 473.8 )464.6( 268.5E 142.6 476.4 )467.0( 944.4 938.6 70.6N 21.9W 941.2 933.2 310.2S 955.6 949.4 73.3N 22.7W 952.0 943.9 310.3S 966.7 960.1 76.0N 23.6W 962.4 954.4 310.4S 977.8 970.9 78.8N 24.4W 973.1 965.1 310.4S 988.9 981.6 81.6N 25.3W 983.8 975.7 310.5S 268.6E 142.7 479.1 )469.6( 268.8E 142.8 481.8 )472.2( 268.9E 142.9 484.6 )474.9( 269.0E 143.0 487.5 )477.6( 269.1E 143.1 490.4 )480.4( 1000.0 992.3 84.5N 26.2W 994.5 986.4 310.6S 1011.1 1002.9 87.5N 27.1W 1006.3 998.2 310.6S 1022.2 1013.6 90.5N 28.1W 1016.9 1008.8 310.7S 1033.3 1024.2 93.6N 29.0W 1027.5 1019.4 310.8S 1044.4 1034.8 96.7N 30.0W 1038.1 1030.0 310.8S 269.2E 143.2 493.4 )483.2( 269.4E 143.3 496.4 )486.1( 269.5E 143.4 499.5 )489.1( 269.6E 143.6 502.7 )492.1( 269.6E 143.7 505.8 )495.2( 1055.6 1045.4 99.9N 31.0W 1051.3 1043.3 310.9S 269.7E 143.8 509.1 )498.3( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 12 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4090'>,,WSP15I,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100.0 100.0 0. ON 200 . 0 200 . 0 0 . ON 300.0 300.0 0.0N 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 387.5 387.5 1.3N 400.0 400.0 1.TN 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 0.0E 8.1 0.1 0.0E 108.0 100.0 0 . 0E 206 . 6 198.6 0.0E 306.7 298.7 0.0W 319.2 311.2 0.0W 331.7 323.7 0.1W 344.5 336.5 0.1W 357.0 349.0 0.2W 369.5 361.5 0.3W 382.2 374.2 0.4W 394.7 386.7 0.5W 407.2 399.2 0.7W 419.7 411.7 0.8W 432.2 424.2 1.0W 444.6 436.6 1.2W 457.1 449.1 1.4W 469.6 461.6 1.6W 482.3 474.3 1.8W 494.8 486.8 2.1W 507.3 499.2 2.3W 520.1 512.1 2.6W 532.6 524.6 2.9W 545.0 537.0 3.2W 557.5 549.5 3.6W 570.3 562.2 3.9W 582.7 574.7 4.3W 595.1 587.1 4.6W 607.6 599.6 5.0W 620.2 612.2 5.5W 632.7 624.7 5.9W 645.1 637.1 6.3W 657.9 649.9 6.8W 670.3 662.3 7.3W 682.7 674.7 7.8W 695.1 687.1 8.3W 708.0 700.0 8.8W 720.4 712.4 9.3W 732.8 724.8 9.9W 745.1 737.1 10.4W 757.6 749.5 II.0W 769.9 761.9 ll.6W 782.3 774.2 12.3W 794.6 786.6 12.9W 806.5 798.5 13.5W 817.4 809.4 14.1W 828.4 820.4 14.7W 839.1 831.1 15.3W 850.0 842.0 16.0W 860.9 852.9 16.7W 871.8 863.8 16.2S 189.0E 94.9 189.7 N/A 16.6S 188.8E 95.0 189.6' 187.9 16.8S 189.1E 95.1 189.8 186.5 16.4S 189.9E 94.9 190.6 185.6 16.4S 190.0E 94.9 190.7 185.5 16.4S 190.0E 95.0 190.8 16.4S 190.1E 95.0 190.9 16.3S 190.2E 95.0 191.1 16.3S 190.3E 95.1 191.2 16.3S 190.3E 95.2 191.4 16.3S 190.4E 95.3 191.6 16.3S 190.4E 95.4 191.8 16.3S 190.5E 95.5 192.0 16.3S 190.5E 95.6 192.3 16.3S 190.6E 95.8 192.6 16.3S 190.6E 96.0 192.9 16.3S 190.7E 96.1 193.2 16.3S 190.7E 96.3 193.5 16.3S 190.8E 96.5 193.9 16.2S 190.8E 96.8 194.3 16.2S 190.9E 97.0 194.7 16.2S 190.9E 97.3 195.1 16.2S 190.9E 97.5 195.5 16.2S 190.9E 97.8 196.0 16.2S 190.9E 98.1 196.4 16.2S 190.9E 98.4 196.9 16.2S 190.9E 98.7 197.5 16.2S 190.9E 99.1 198.0 16.2S 190.9E 99.4 198.6 16.1S 190.9E 99.7 199.2 16.1S 190.9E 100.1 199.8 16.0S 190.8E 100.5 200.5 16.0S 190.8E 100.8 201.2 15.9S 190.8E 101.2 201.9 15.9S 190.7E 101.6 202.7 15.8S 190.7E 102.0 203.4 15.8S 190.6E 102.5 204.2 15.7S 190.6E 102.9 205.1 15.6S 190.5E 103.3 205.9 15.6S 190.4E 103.8 206.8 15.5S 190.3E 104.2 207.7 15.4S 190.3E 104.7 208.7 15.4S 190.2E 105.2 209.8 15.3S 190.1E 105.7 210.9 15.3S 190.1E 106.1 211.9 15.2S 190.1E 106.5 212.9 15.2S 190.0E 107.0 214.1 15.2S 190.0E 107.5 215.2 15.1S 189.9E 107.9 216.5 15.1S 189.9E 108.4 217.7 185.4 185.3 185.3 185.2 185.2 185.2 185.2 185.2 185.2 185.3 185.4 185.5 185.6 185.8 185.9 186.1 186.3 186.5 186.8 187.0 187.3 187.6 187.9 188.3 188.7 189.1 189.5 190.0 190.5 191.0 191.5 192.1 192.7 193.3 194.0 194.7 195.4 196.2 197.1 197.8 198.7 199.6 200.6 201.6 202.6 877.8 873.8 56.0N 17.4W 882.7 874.6 15.1S 189.9E 108.9 219.1 203.7 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECE;VED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 13 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <O-4090'>,,WSP15I,Pad 1J (WS Pilot) M.D. T.V.D. 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 1000.0 992.3 101t.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 58.3N 18.1W 893.5 885.5 15.0S 60.6N 18.8W 904.4 896.3 15.0S 63.0N 19.5W 915.2 907.2 15.0S 65.5N 20.3W 926.0 918.0 14.9S 68.0N 21.1W 936.6 928.6 14.9S 70.6N 21.9W 947.4 939.3 14.9S 73.3N 22.7W 958.1 950.1 14.9S 76.0N 23.6W 968.9 960.9 14.8S 78.8N 24.4W 979.1 971.1 14.8S 81.6N 25.3W 989.8 981.8 14.8S 84.5N 26.2W 1000.5 992.5 14.8S 87.5N 27.1W 1011.2 1003.2 14.8S 90.5N 28.1W 1021.6 1013.6 14.8S 93.6N 29.0W 1032.2 1024.2 14.8S 96.7N 30.0W 1042.8 1034.8 14.8S 31.0W 1053.4 1045.4 14.8S 32.0W 1064.0 1056.0 14.8S 33.0W 1074.6 1066.6 14.8S 34.1W 1085.1 1077.1 14.8S 35.1W 1095.6 1087.6 14.8S 99.9N 103.1N 106.4N 109.8N 113.2N 116.7N 36.2W 1106.1 1098.1 14.8S 120.3N 37.3W 1116.9 1108.9 14.8S 123.9N 38.4W 1127.3 1119.3 14.8S 127.5N 39.6W 1137.8 1129.8 14.8S 131.2N 40.7W 1148.2 1140.2 14.8S 135.0N 41.9W 1158.6 1150.5 14.8S 138.8N 43.1W 1169.5 1161.5 14.8S 142.7N 44.3W 1179.9 1171.9 14.8S 146.7N 45.5W 1190.2 1182.2 14.7S 150.7N 46.7W 1200.5 1192.5 14.7S 154.7N 48.0W 1211.1 1203.0 14.7S 158.9N 49.3W 1221.3 1213.3 14.7S 163.0N 50.6W 1231.5 1223.5 14.7S 167.3N 51.9W 1241.7 1233.7 14.7S 171.6N 53.2W 1251.9 1243.9 14.7S 175.9N 54.6W 1262.1 1254.1 14.6S 180.3N 55.9W 1272.2 1264.2 14.6S 184.8N 57.3W 1282.3 1274.3 14.6S 189.3N 58.7W 1292.4 1284.3 14.6S 193.8N 60.1W 1302.1 1294.0 14.6S 198.5N 61.6W 1312.1 1304.1 14.6S 203.1N 63.0W 1322.0 1314.0 14.6S 207.9N 64.5W 1332.0 1324.0 14.5S 212.7N 66.0W 1341.9 1333.9 14.5S 217.5N 67.5W 1351.1 1343.1 14.5S 189.8E 109.4 220.5 189.8E 109.9 221.9 189.8E 110.4 223.4 t89.7E 111.0 224.9 189.7E 111.5 226.5 189.7E 112.0 228.2 189.6E 112.5 229.9 189.6E 113.1 231.7 189.6E 113.6 233.6 189.6E 114.2 235.5 189.6E 114.7 237.5 189.6E 115.3 239.6 189.6E 115.8 241.8 189.6E 116.4 244.0 189.6E 116.9 246.2 222.4N 69.0W 1361.0 1353.0 14.5S 227.4N 70.5W 1370.8 1362.8 14.5S 232.4N 72.1W 1380.6 1372.6 14.5S 237.4N 73.6W 1390.3 1382.3 14.5S 242.6N 75.2W 1400.1 1392.1 14.5S 189.6E 117.5 248.6 189.6E 118.0 251.0 189.6E 118.6 253.4 189.6E 119.1 256.0 189.6E 119.7 258.6 189.6E 120.2 261.3 189.6E 120.8 264.0 189.6E 121.3 266.8 189.5E 121.8 269.7 189.5E 122.4 272.6 189.5E 122.9 275.6 189.5E 123.4 278.7 189.5E 124.0 281.8 189.4E 124.5 285.0 189.4E 125.0 288.3 189.4E 125.5 291.6 189.3E 126.0 295.0 189.3E 126.5 298.5 189.2E 127.0 302.1 189.2E 127.5 305.7 189.2E 128.0 309.4 189.1E 128.5 313.1 189.1E 129.0 316.9 189.0E 129.5 320.8 189.0E 129.9 324.8 188.9E 130.4 328.8 188.9E 130.8 333.0 188.9E 131.3 337.1 188.9E 131.7 341.4 188.8E 132.2 345.7 188.8E 132.6 350.2 188.8E 133.0 354.6 188.8E 133.4 359.2 188.8E 133.8 363.8 188.8E 134.2 368.5 76.8W 1409.8 1401.8 14.5S 188.8E 134.6 373.3 Ail data is in feet unless otherwise stated. Casing dimensions are not included. 247.7N 204.9( 206.1( 207.4( 208.7( 210.1( 211.5( 213.0( 214.6( 216.2( 217.9( 219.7( 221.5( 223.4( 225.4( 227.4( 229.5( 231.7( 233.9( 236.2( 238.6( 241.0( 243.5( 246.1( 248.7( 251.4( 254.2( 257.0( 259.9( 262.9( 265.9( 269.0( 272.2 275.4 278.7 282.1 285.5 289.0 292.6 296.3 300.0 303.8 307.7 311.6 315.7 319.8 324.0 328.2 332.5 336.9 341.4 345.9( Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 14 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : MMS <0-4090'>,,WSP15I,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 1455.6 1411.1 1466.7 1420.8 1477.8 1430.4 1488.9 1439.9 1500.0 1449.5 253.0N 258.2N 263.6N 269.0N 274.4N 78.5W 1419.5 1411.5 80.1W 1429.1 1421.1 81.7W 1439.5 1431.5 83.4W 1449.1 1441.1 85.1W 1458.7 1450.7 14.5S 188.8E 135.0 378.1 14.4S 188.8E 135.4 383.0 14.4S 188.9E 135.8 387.9 14.3S 188.9E 136.1 393.0 14.2S 189.0E 136.5 398.0 350.5( 355.2( 359.9( 364.7( 369.5( 1510.9 1458.8 1521.8 1468.1 1532.7 1477.3 1543.6 1486.5 1554.4 1495.7 1565.3 1504.9 1576.2 1514.0 1584.1 1520.6 1592.1 1527.2 1600.0 1533.8 1611.1 1543.0 1622.2 1552.2 1633.3 1561.3 1644.4 1570.4 1655.6 1579.4 1666.7 1588.4 1677.8 1597.4 1688.9 1606.3 1700.0 1615.2 1711.1 1624.1 1722.2 1632.9 1733.3 1641.6 1744.4 1650.4 1755.6 1659.1 279.8N 285.2N 290.7N 296.2N 301.8N 307.4N 313.1N 317.3N 321.5N 325.7N 331.7N 337.7N 343.7N 349.9N 356.0N 362.2N 368.5N 374.8N 381.2N 387.6N 394.0N 400.6N 407.1N 413.7N 86.8W 1468.1 1460.1 88.5W 1477.4 1469.4 90.2W 1488.2 1480.2 91.9W 1497.5 1489.5 93.6W 1506.8 1498.8 95.4W 1518.3 1510.3 97.1W 1527.6 1519.6 98.4W 1534.3 1526.3 99.7W 1541.0 1533.0 101.0W 1550.2 1542.2 102.9W 1559.6 1551.6 104.7W 1569.0 1560.9 106.6W 1581.3 1573.2 108.5W 1590.7 1582.6 l10.4W 1600.0 1591.9 112.3W 1612.9 1604.7 114.3W 1622.2 1614.0 116.3W 1631.5 1623.3 118.2W 1644.5 1636.3 120.2W 1653.8 1645.5 122.2W 1667.7 1659.4 124.2W 1677.0 1668.6 126.3W 1691.8 1683.3 128.3W 1701.1 1692.6 14.2S 189.0E 136.8 403.1 14.1S 189.0E 137.2 408.1 13.9S 189.1E 137.5 413.3 13.8S 189.2E 137.8 418.5 13.6S 189.3E 138.1 423.7 13.4S 189.4E 138.4 429.0 13.1S 189.5E 138.7 434.3 12.9S 189.6E 138.9 438.2 12.7S 189.7E 139.1 442.1 12.4S 189.9E 139.3 446.1 12.0S 190.0E 139.6 451.6 11.6S 190.2E 139.8 457.3 11.0S 190.5E 140.1 462.9 10.5S 190.7E 140.3 468.6 10.0S 191.0E 140.5 474.3 9.2S 191.3E 140.7 480.1 8.6S 191.6E 140.9 485.8 7.9S 191.9E 141.2 491.7 6.9S 192.4E 141.3 497.5 6.1S 192.7E 141.5 503.4 4.9S 193.3E 141.7 509.3 4.0S 193.6E 141.8 515.2 2.5S 194.3E 142.0 521.2 1.5S 194.6E 142.1 527.1 374.4( 379.2( 384.2( 389.2( 394.4( 399.5( 404.7( 408.5( 412.4( 416.2( 421.7( 427.1( 432.7( 438.2( 443.8( 449.5( 455.1( 460.8( 466.6( 472.3( 478.1( 483.9( 489.8( 495.6( RECEIVED Alaska Oil & Ga80on$. Oommis$ion Anchora§e Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CLEARANCE LISTING Page 15 Pad 1J (WS Pilot ,9 Kuparuk River Unit,North Slope, Alaska Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <0-4135'>,,WSP20,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 0.0E 0.0 9.0 242.6S 16.9E 176.0 243.3 N/A 100.0 100.0 0.0N 0.0E 90.4 99.4 242.7S 16.9E 176.0 243.3* 242.4 200.0 200.0 0.0N 0.0E 190.3 199.3 243.0S 17.1E 176.0 243.6 241.8 300.0 300.0 0.0N 0.0E 290.4 299.4 243.2S 17.2E 176.0 243.8 241.1 312.5 312.5 0.0N 0.0W 303.1 312.0 243.3S 17.2E 176.0 243.9 241.1 325.0 325.0 0.1N 0.0W 315.6 324.5 243.3S 17.2E 175.9 244.0 337.5 337.5 0.2N 0.1W 328.0 337.0 243.3S 17.2E 175.9 244.2 350.0 350.0 0.4N 0.1W 340.5 349.5 243.3S 17.3E 175.9 244.4 362.5 362.5 0.7N 0.2W 353.4 362.4 243.3S 17.3E 175.9 244.6 375.0 375.0 0.9N 0.3W 365.9 374.9 243.4S 17.3E 175.9 244.9 387.5 387.5 1.3N 0.4W 378.4 387.4 243.4S 17.3E 175.9 245.3 400.0 400.0 1.7N 0.5W 390.9 399.9 243.4S 17.3E 175.8 245.7 412.5 412.5 2.1N 0.7W 403.9 412.9 243.4S 17.4E 175.8 246.1 425.0 425.0 2.6N 0.8W 416.4 425.4 243.3S 17.4E 175.8 246.6 437.5 437.4 3.2N 1.0W 428.9 437.9 243.3S 17.4E 175.7 247.2 450.0 449.9 3.7N 1.2W 441.3 450.3 243.3S 17.5E 175.7 247.7 462.5 462.4 4.4N 1.4W 454.5 463.5 243.2S 17.5E 175.6 248.4 475.0 474.9 5.1N 1.6W 467.0 476.0 243.2S 17.6E 175.6 249.0 487.5 487.4 5.9N 1.8W 479.4 488.4 243.1S 17.7E 175.5 249.8 500.0 499.8 6.7N 2.1W 491.9 500.9 243.1S 17.8E 175.5 250.5 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725°0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 2.3W 504.9 513.9 243.0S 2.6W 517.3 526.3 242.9S 2.9W 529.8 538.8 242.8S 3.2W 542.3 551.3 242.7S 3.6W 554.7 563.7 242.7S 3.9W 567.2 576.2 242.6S 4.3W 579.6 588.6 242.5S 4.6W 592.0 601.0 242.4S 5.0W 604.6 613.6 242.3S 5.5W 617.0 626.0 242.2S 5.9W 629.4 638.4 242.1S 6.3W 641.8 650.8 242.0S 6.8W 654.1 663.1 241.9S 7.3W 666.5 675.5 241.8S 7.8W 678.9 687.9 241.8S 8.3W 691.3 700.3 241.7S 8.8W 703.4 712.4 241.6S 9.3W 715.8 724.7 241.5S 9.9W 728.1 737.1 241.5S 10.4W 740.5 749.5 241.4S ii.0W 752.4 761.4 241.4S ll.6W 764.7 773.7 241.3S 12.3W 777.0 786.0 241.3S 12.9W 789.4 798.3 241.2S 13.5W 800.1 809.0 241.2S 14.1W 811.0 820.0 241.2S 14.7W 821.9 830.9 241.1S 15.3W 832.8 841.8 241.1S 16.0W 843.7 852.7 241.1S 16.7W 854.5 863.5 241.1S 17.9E 175.4 251.3 18.0E 175.3 252.2 18.1E 175.2 253.1 18.2E 175.2 254.1 18.3E 175.1 255.1 18.4E 175.0 256.1 18.5E 174.9 257.3 18.7E 174.8 258.4 18.8E 174.7 259.7 18.9E 174.6 260.9 19.0E 174.6 262.3 19.1E 174.5 263.6 19.2E 174.4 265.1 19.3E 174.3 266.6 19.4E 174.2 268.1 19.5E 174.1 269.7 19.6E 174.0 271.4 19.6E 173.9 273.1 19.7E 173.8 274.9 19.8E 173.7 276.7 19.8E 173.6 278.6 19.9E 173.6 280.6 19.9E 173.5 282.6 19.9E 173.4 284.7 20.0E 173.3 286.6 20.0E 173.2 288.6 20.0E 173.1 290.6 20.0E 173.1 292.7 20.0E 173.0 294.8 20.0E 172.9 297.1 241.0 241.0 241.1 241.2 241.4 241.6 241.9 242.2 242.5 242.9 243.3 243.7 244.3 244.8 245.4 246.1 246.7 247.5 248.3 249.1 250.0( 251.0( 252.0( 253.0( 254.1( 255.3( 256.5( 257.7 259.1 260.4 261.9 263.4 264.9 266.5( 268.2( 269.9( 271.7( 273.5( 275.4( 277.2( 279.0( 280.9( 282.8( 284.8( 286.9( 877.8 873.8 56.0N 17.4W 865.4 874.4 241.0S 20.0E 172.8 299.3 289.0( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot 99 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),9 RECEIVED Alaska 0il & Gas Cons. Commission Anchorage CLEARANCE LISTING Page 16 Your ref : 1J-09 Version#2 Kuparuk River Unit,North Slope, Alaska Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <O-4135'>,,WSP20,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 58.3N 18.1W 876.3 885.2 241.0S 20.0E 172.7 301.7 60.6N 18.8W 887.1 896.1 241.0S 20.0E 172.7 304.1 63.0N 19.5W 898.0 907.0 241.0S 20.0E 172.6 306.6 65.5N 20.3W 908.8 917.8 240.9S 20.0E 172.5 309.1 68.0N 21.1W 919.6 928.6 240.9S 20.0E 172.4 311.7 70.6N 21.9W 930.4 939.4 240.9S 20.0E 172.3 314.3 73.3N 22.7W 941.2 950.1 240.9S 20.0E 172.2 317.1 76.0N 23.6W 952.1 961.1 240.8S 20.0E 172.2 319.8 78.8N 24.4W 962.9 971.8 240.8S 20.1E 172.1 322.7 81.6N 25.3W 973.6 982.6 240.8S 20.1E 172.0 325.6 291.2 293.4 295.7 298.1 300.6 303.1 305.6 308.2 310.9 313.7 1000.0 992.3 1011.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 84.5N 26.2W 984.3 993.2 240.7S 20.1E 171.9 328.5 87.5N 27.1W 994.9 1003.9 240.7S 20.1E 171.8 331.6 90.5N 28.1W 1005.3 1014.3 240.7S 20.1E 171.7 334.6 93.6N 29.0W 1016.0 1025.0 240.6S 20.2E 171.6 337.8 96.7N 30.0W 1026.6 1035.6 240.6S 20.2E 171.5 341.0 99.9N 31.0W 1037.2 1046.2 240.6S 20.2E 171.4 344.3 103.1N 32.0W 1047.8 1056.8 240.5S 20.3E 171.4 347.6 106.4N 33.0W 1057.6 1066.6 240.5S 20.3E 171.3 351.0 109.8N 34.1W 1068.1 1077.1 240.5S 20.4E 171.2 354.5 113.2N 35.1W 1078.6 1087.6 240.5S 20.4E 171.1 358.1 116.7N 36.2W 1089.1 1098.1 240.5S 20.5E 171.0 361.7 120.3N 37.3W 1099.0 1108.0 240.5S 20.5E 170.9 365.4 123.9N 38.4W 1109.5 1118.5 240.5S 20.5E 170.8 369.1 127.5N 39.6W 1119.9 1128.9 240.5S 20.6E 170.7 372.9 131.2N 40.7W 1130.3 1139.3 240.5S 20.6E 170.6 376.8 135.0N 41.9W 1140.7 1149.6 240.5S 20.7E 170.5 380.7 138.8N 43.1W 1150.7 1159.7 240.6S 20.7E 170.5 384.7 142.7N 44.3W 1161.0 1170.0 240.6S 20.8E 170.4 388.8 146.7N 45.5W 1171.3 1180.3 240.6S 20.8E 170.3 392.9 150.7N 46.7W 1181.6 1190.6 240.6S 20.8E 170.2 397.1 154.7N 48.0W 1191.9 1200.9 240.6S 20.8E 170.1 401.3 158.9N 49.3W 1201.9 1210.9 240.7S 20.9E 170.0 405.6 163.0N 50.6W 1212.1 1221.1 240.7S 20.9E 170.0 410.0 167.3N 51.9W 1222.3 1231.3 240.7S 20.9E 169.9 414.4 171.6N 53.2W 1232.4 1241.4 240.7S 21.0E 169.8 418.9 175.9N 54.6W 1242.5 1251.5 240.8S 21.0E 169.7 423.5 180.3N 55.9W 1252.6 1261.6 240.8S 21.0E 169.6 428.1 184.8N 57.3W 1262.7 1271.7 240.8S 21.0E 169.6 432.7 189.3N 58.7W 1272.7 1281.7 240.8S 21.1E 169.5 437.4 193.8N 60.1W 1282.8 1291.7 240.9S 21.1E 169.4 442.2 198.5N 61.6W 1292.7 1301.7 240.9S 21.1E 169.3 447.1 203.1N 63.0W 1303.0 1312.0 240.9S 21.2E 169.3 452.0 207.9N 64.5W 1312.9 1321.9 240.9S 21.2E 169.2 456.9 212.7N 66.0W 1322.9 1331.8 240.9S 21.2E 169.1 461.9 217.5N 67.5W 1332.7 1341.7 241.0S 21.3E 169.0 467.0 222.4N 69.0W 1342.6 1351.5 241.0S 21.3E 169.0 472.1 227.4N 70.5W 1353.1 1362.1 241.0S 21.3E 168.9 477.3 232.4N 72.1W 1362.9 1371.9 241.0S 21.4E 168.8 482.5 237.4N 73.6W 1372.7 1381.7 241.0S 21.4E 168.8 487.8 242.6N 75.2W 1382.4 1391.4 241.0S 21.5E 168.7 493.1 247.7N 76.8W 1392.1 1401.1 241.0S 21.5E 168.6 498.5 316.5 319.3 322.3 325.3 328.3 331.4 334.6 337.9 341.2 344.6 348.1 351.6 355.2 358.9 362.6 366.4 370.2 374.1 378.1 382.1 386.2 390.4 394.6 398.9 403.2 407.6 412.1 416.6 421.2 425.8 430.5 435.2 440.0 444.9 449.8 454.8 459.8 464.9 470.0 475.2 480.5 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot 99 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 17 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <0-4135'>,,WSP20,Pad 1J (WS Pilot) M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 1455.6 1466.7 1477.8 1411.1 1420.8 1430.4 253.0N 78.5W 1402.0 1411.0 241.0S 21.6E 168.6 504.0 )485.8( 258.2N 80.1W 1411.6 1420.6 241.0S 21.6E 168.5 509.5 )491.1( 263.6N 81.7W 1421.2 1430.2 240.9S 21.6E 168.4 515.0 )496.6( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED Alaska Oil & Gas Cons. Commissior~ Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 KuDaruk River Unit,North Slope, Alaska CLEARANCE LISTING Page 18 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100.0 100.0 0. ON 200.0 200.0 0. ON 300.0 300 . 0 0 . ON 312.5 312.5 0.0N 0.0E 3.0 0.0 0.0E 103.0 100.0 0.0E 203.0 200.0 0.0E 303.0 300.0 0.0W 315.5 312.5 42.1N 174.9E 76.5 179.8 N/A 42.0N 174.9E 76.5 179.8 N/A 41.9N 174.9E 76.5 179.8 N/A 41.7N 175.0E 76.6 179.9 N/A 41.6N 175.0E 76.6 179.9 N/A 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 0.0W 328.0 325.0 0.1W 340.5 337.5 0.1W 353.0 350.0 0.2W 365.5 362.5 0.3W 378.0 375.0 41.6N 175.0E 76.7 179.9 N/A 41.6N 175.0E 76.7 179.9 N/A 41.5N 175.0E 76.8 179.9 N/A 41.5N 175.0E 76.9 179.9 N/A 41.5N 175.0E 77.0 179.9 N/A 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 0.4W 390.5 387.5 0.5W 403.0 400.0 0.7W 415.4 412.4 0.8W 427.9 424.9 1.0W 440.4 437.4 41.4N 175.0E 77.1 180.0 N/A 41.4N 175.0E 77.3 180.0 N/A 41.3N 175.1E 77.4 180.0 N/A 41.3N 175.1E 77.6 180.1 N/A 41.2N 175.1E 77.8 180.1 N/A 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 1.2W 452.9 449.9 1.4W 465.4 462.4 1.6W 477.9 474.9 1.SW 490.3 487.3 2.1W 502.8 499.8 41.2N 175.1E 78.0 180.2 N/A 41.1N 175.1E 78.2 180.3 N/A 41.1N 175.1E 78.5 180.3 N/A 41.0N 175.1E 78.8 180.4 N/A 41.0N 175.1E 79.0 180.5 N/A 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 2.3W 515.2 512.2 2.6W 527.7 524.7 2.9W 540.2 537.2 3.2W 552.6 549.6 3.6W 565.1 562.1 40.9N 175.2E 79.3 180.6 N/A 40.9N 175.2E 79.7 180.7 N/A 40.8N 175.2E 80.0 180.9 N/A 40.8N 175.2E 80.3 181.0 N/A 40.7N 175.2E 80.7 181.1 N/A 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 3.9W 577.5 574.5 4.3W 589.9 586.9 4.6W 602.4 599.4 5.0W 614.8 611.8 5.5W 627.2 624.2 40.7N 175.2E 81.1 181.3 N/A 40.6N 175.2E 81.5 181.5 N/A 40.6N 175.3E 81.9 181.7 N/A 40.5N 175.3E 82.3 181.9 N/A 40.5N 175.3E 82.8 182.2 N/A 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 5.9W 639.6 636.6 6.3W 652.0 649.0 6.8W 664.4 661.4 7.3W 676.8 673.8 7.8W 689.2 686.2 40.4N 175.3E 83.3 182.4 N/A 40.4N 175.3E 83.7 182.7 N/A 40.3N 175.3E 84.2 183.0 N/A 40.2N 175.3E 84.7 183.4 N/A 40.2N 175.4E 85.3 183.7 N/A 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 8.3W 701.6 698.6 8.8W 713.9 710.9 9.3W 726.3 723.3 9.9W 738.6 735.6 10.4W 751.0 748.0 40.1N 175.4E 85.8 184.1 N/A 40.1N 175.4E 86.3 184.5 N/A 40.0N 175.4E 86.9 185.0 N/A 40.0N 175.4E 87.5 185.5 N/A 39.9N 175.4E 88.1 186.0 N/A 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N ll.0W 763.3 760.3 ll.6W 775.6 772.6 12.3W 787.9 784.9 12.9W 800.2 797.2 13.5W 811.2 808.2 39.9N 175.4E 88.7 186.5 N/A 39.8N 175.5E 89.3 187.1 N/A 39.8N 175.5E 89.9 187.7 N/A 39.7N 175.5E 90.6 188.4 N/A 39.7N 175.5E 91.1 189.0 N/A 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 14.1W 822.1 819.1 14.7W 833.0 830.0 15.3W 843.9 840.9 16.0W 854.8 851.8 16.7W 865.6 862.6 39.6N 175.5E 91.7 189.7 N/A 39.6N 175.5E 92.3 190.4 N/A 39.5N 175.5E 93.0 191.1 N/A 39.5N 175.5E 93.6 191.9 N/A 39.5N 175.6E 94.2 192.7 N/A 877.8 873.8 56.0N 17.4W 876.5 873.5 39.4N 175.6E 94.9 193.6 N/A Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot ~9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker H~ghes INTEQ RECEIVED FEB B 001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 KuDaruk River Unit,North SloDe, Alaska CLEARANCE LISTING Page 19 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellDath Object wellpath : TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 1000.0 992.3 1011.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 58.3N 18.1W 887.3 884.3 39.4N 175.6E 95.6 194.6 N/A 60.6N 18.8W 898.1 895.1 39.3N 175.6E 96.3 195.6 N/A 63.0N 19.5W 909.0 905.9 39.3N 175.6E 96.9 196.6 N/A 65.5N 20.3W 919.7 916.7 39.2N 175.6E 97.6 197.7 N/A 68.0N 21.1W 930.5 927.5 39.2N 175.6E 98.3 198.8 N/A 70.6N 21.9W 941.3 938.3 39.1N 175.6E 99.1 200.0 N/A 73.3N 22.7W 952.0 949.0 39.1N 175.7E 99.8 201.3 N/A 76.0N 23.6W 962.8 959.7 39.0N 175.7E 100.5 202.6 N/A 78.8N 24.4W 973.5 970.5 39.0N 175.7E 101.2 204.0 N/A 81.6N 25.3W 984.2 981.2 39.0N 175.7E 102.0 205.5 N/A 84.5N 26.2W 994.8 991.8 38.9N 175.7E 102.7 207.0 N/A 87.5N 27.1W 1005.5 1002.5 38.9N 175.7E 103.5 208.6 N/A 90.5N 28.1W 1016.1 1013.1 38.8N 175.7E 104.2 210.2 N/A 93.6N 29.0W 1026.8 1023.7 38.8N 175.7E 105.0 212.0 N/A 96.7N 30.0W 1037.4 1034.4 38.7N 175.7E 105.7 213.7 N/A 99.9N 31.0W 1047.9 1044.9 38.7N 175.8E 106.5 215.6 N/A 103.1N 32.0W 1058.5 1055.5 38.6N 175.8E 107.2 217.5 N/A 106.4N 33.0W 1069.0 1066.0 38.6N 175.8E 108.0 219.5 N/A 109.8N 34.1W 1079.6 1076.6 38.6N 175.8E 108.8 221.6 N/A 113.2N 35.1W 1090.1 1087.1 38.5N 175.8E 109.5 223.8 N/A 116.7N 36.2W 1100.5 1097.5 38.5N 175.8E 110.3 226.0 N/A 120.3N 37.3W 1111.0 1108.0 38.4N 175.8E 111.0 228.3 N/A 123.9N 38.4W 1121.4 1118.4 38.4N 175.8E 111.8 230.7 N/A 127.5N 39.6W 1131.9 1128.8 38.3N 175.9E 112.5 233.1 N/A 131.2N 40.7W 1142.2 1139.2 38.3N 175.9E 113.2 235.7 N/A 135.0N 41.9W 1152.6 1149.6 38.2N 175.9E 114.0 238.3 N/A 138.8N 43.1W 1163.0 1159.9 38.2N 175.9E 114.7 241.0 N/A 142.7N 44.3W 1173.3 1170.3 38.2N 175.9E 115.4 243.7 N/A 146.7N 45.5W 1183.6 1180.6 38.1N 175.9E 116.1 246.6 N/A 150.7N 46.7W 1193.8 1190.8 38.1N 175.9E 116.8 249.5 N/A 154.7N 48.0W 1204.1 1201.1 38.0N 175.9E 117.5 252.5 N/A 158.9N 49.3W 1214.3 1211.3 38.0N 175.9E 118.2 255.6 N/A 163.0N 50.6W 1224.5 1221.5 37.9N 176.0E 118.9 258.8 N/A 167.3N 51.9W 1234.7 1231.7 37.9N 176.0E 119.6 262.0 N/A 171.6N 53.2W 1244.8 1241.8 37.9N 176.0E 120.3 265.3 N/A 175.9N 54.6W 1254.9 1251.9 37.8N 176.0E 120.9 268.7 N/A 180.3N 55.9W 1265.0 1262.0 37.8N 176.0E 121.6 272.2 N/A 184.8N 57.3W 1275.1 1272.1 37.7N 176.0E 122.2 275.8 N/A 189.3N 58.7W 1285.1 1282.1 37.7N 176.0E 122.9 279.4 N/A 193.8N 60.1W 1295.1 1292.1 37.6N 176.0E 123.5 283.1 N/A 198.5N 61.6W 1305.1 1302.1 37.6N 176.0E 124.1 286.9 N/A 203.1N 63.0W 1315.1 1312.1 37.6N 176.1E 124.7 290.8 N/A 207.9N 64.5W 1325.0 1322.0 37.5N 176.1E 125.3 294.8 N/A 212.7N 66.0W 1334.9 1331.9 37.5N 176.1E 125.9 298.8 N/A 217.5N 67.5W 1344.7 1341.7 37.4N 176.1E 126.5 302.9 N/A 222.4N 69.0W 1354.6 1351.6 37.4N 176.1E 127.1 307.1 N/A 227.4N 70.5W 1364.4 1361.4 37.4N 176.1E 127.6 311.4 N/A 232.4N 72.1W 1374.1 1371.1 37.3N 176.1E 128.2 315.7 N/A 237.4N 73.6W 1383.9 1380.9 37.3N 176.1E 128.7 320.1 N/A 242.6N 75.2W 1393.6 1390.6 37.2N 176.1E 129.2 324.6 N/A 247.7N 76.8W 1403.3 1400.3 37.2N 176.2E 129.8 329.2 N/A Ail data is in feet unless Otherwise stated. Casing dimensions are not included. Coordinates from slot ~9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. RECEIVED Alaska Oil & Gas Cons. Commission Annhnrnn~ Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 20 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : TOTCO <0-9346'>,,WSP1S,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. 1455.6 1411.1 1466.7 1420.8 1477.8 1430.4 1488.9 1439.9 1500.0 1449.5 1510.9 1458.8 1521.8 1468.1 1532.7 1477.3 1543.6 1486.5 1554.4 1495.7 1565.3 1504.9 1576.2 1514.0 1584.1 1520.6 1592.1 1527.2 1600.0 1533.8 1611.1 1543.0 1622.2 1552.2 1633.3 1561.3 1644.4 1570.4 1655.6 1579.4 1666.7 1588.4 1677.8 1597.4 1688.9 1606.3 1700.0 1615.2 1711.1 1624.1 1722.2 1632.9 1733.3 1641.6 1744.4 1650.4 1755.6 1659.1 1766.7 1667.7 1777.8 1676.3 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 253.0N 78.5W 1412.9 1409.9 37.1N 176.2E 130.3 333.8 N/A 258.2N 80.1W 1422.5 1419.5 37.1N 176.2E 130.8 338.5 N/A 263.6N 81.7W 1432.1 1429.1 37.1N 176.2E 131.3 343.3 N/A 269.0N 83.4W 1441.7 1438.7 37.0N 176.2E 131.8 348.1 N/A 274.4N 85.1W 1451.2 1448.2 37.0N 176.2E 132.3 353.1 N/A 279.8N 86.8W 1460.5 1457.5 36.9N 176.2E 132.7 358.0 N/A 285.2N 88.5W 1469.7 1466.7 36.9N 176.2E 133.2 362.9 N/A 290.7N 90.2W 1479.0 1476.0 36.9N 176.2E 133.6 368.0 N/A 296.2N 91.9W 1488.2 1485.1 36.8N 176.3E 134.1 373.1 N/A 301.8N 93.6W 1497.3 1494.3 36.8N 176.3E 134.5 378.2 N/A 307.4N 95.4W 1505.9 1502.9 36.8N 176.3E 134.9 383.5 N/A 313.1N 97.1W 1515.0 1512.0 36.7N 176.3E 135.3 388.8 N/A 317.3N 98.4W 1521.6 1518.6 36.7N 176.3E 135.6 392.7 N/A 321.5N 99.7W 1528.2 1525.1 36.7N 176.3E 135.9 396.6 N/A 325.7N 101.0W 1534.7 1531.7 36.6N 176.3E 136.2 400.6 N/A 331.7N 102.9W 1543.9 1540.9 36.6N 176.3E 136.6 406.2 N/A 337.7N 104.7W 1553.0 1550.0 36.5N 176.3E 137.0 411.9 N/A 343.7N 106.6W 1562.1 1559.1 36.5N 176.4E 137.4 417.7 N/A 349.9N 108.5W 1571.1 1568.1 36.4N 176.4E 137.7 423.6 N/A 356.0N l10.4W 1580.1 1577.1 36.4N 176.4E 138.1 429.5 N/A 362.2N 112.3W 1589.1 1586.1 36.3N 176.4E 138.5 435.4 N/A 368.5N 114.3W 1598.0 1595.0 36.3N 176.4E 138.8 441.5 N/A 374.8N 116.3W 1606.9 1603.9 36.2N 176.4E 139.2 447.6 N/A 381.2N 118.2W 1615.8 1612.7 36.1N 176.4E 139.5 453.7 N/A 387.6N 120.2W 1624.6 1621.6 36.1N 176.5E 139.8 460.0 N/A 394.0N 122.2W 1632.0 1628.9 36.0N 176.5E 140.2 466.3 N/A 400.6N 124.2W 1640.7 1637.7 36.0N 176.5E 140.5 472.6 N/A 407.1N 126.3W 1649.3 1646.3 35.9N 176.5E 140.8 479.1 N/A 413.7N 128.3W 1658.0 1655.0 35.8N 176.5E 141.1 485.5 N/A 420.4N 130.4W 1666.6 1663.6 35.8N 176.5E 141.4 492.1 N/A 427.1N 132.5W 1675.1 1672.1 35.7N 176.6E 141.7 498.7 N/A Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. RECEIVED Alaska Oil & Gas Cons. Commission Anchorage Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 21 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <0-3950'>,,WSP2,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Diet Sep'n 0.0 0.0 0.0N 100 . 0 100 . 0 0 . ON 200 . 0 200 . 0 0 . ON 300.0 300.0 0.0N 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.gN 387.5 387.5 1.3N 400.0 400.0 1.TN 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 56.0N 0.0E 2.7 -0.3 0.0E 101.7 98.7 0 . 0E 202 . 1 199 . 1 0.0E 301.9 298.9 0.0W 314.4 311.4 74.2S 202.8E 110.1 215.9 74.4S 203.0E 110.1 216.3 75.0S 203.4E 110.2 216.8 75.8S 203.6E 110.4 217.2 75.9S 203.6E 110.5 217.3 N/A 215.3 215.0 214.5 214.4 0.0W 326.9 323.9 0.1W 339.4 336.4 0.1W 351.1 348.1 0.2W 363.6 360.6 0.3W 376.1 373.1 0.4W 388.6 385.6 0.5W 400.8 397.8 0.7W 413.3 410.3 0.8W 425.8 422.8 1.0W 438.3 435.2 1.2W 451.0 448.0 1.4W 463.5 460.5 1.6W 475.9 472.9 1.8W 488.4 485.4 2.1W 500.8 497.8 2.3W 513.3 510.3 2.6W 525.8 522.7 2.9W 538.2 535.2 3.2W 550.7 547.6 3.6W 563.1 560.1 76.0S 203.6E 110.5 217.4 76.1S 203.7E 110.5 217.6 76.2S 203.7E 110.6 217.8 76.3S 203.8E 110.7 218.0 76.3S 203.9E 110.7 218.3 76.4S 204.0E 110.8 218.7 76.5S 204.1E 110.9 219.0 76.6S 204.2E 111.0 219.5 76.6S 204.3E 111.1 219.9 76.7S 204.4E 111.2 220.4 76.8S 204.5E 111.4 220.9 76.9S 204.6E 111.5 221.4 76.9S 204.7E 111.7 222.0 77.0S 204.8E 111.9 222.6 77.1S 204.9E 112.0 223.2 77.1S 205.0E 112.2 223.9 77.2S 205.0E 112.4 224.6 77.3S 205.1E 112.6 225.4 77.4S 205.2E 112.8 226.2 77.4S 205.3E 113.1 227.0 214.4 214.5 214.5 214.7 214.8 215.0 215.3 215.6 215.9 216.2 216.6 217.0 217.4 217.9 218.4 218.9 219.5 220.1 220.8 221.5 3.9W 575.5 572.5 4.3W 588.0 584.9 4.6W 600.2 597.2 5.0W 612.6 609.6 5.5W 625.0 622.0 77.5S 205.4E 113.3 227.9 )222.2 77.6S 205.5E 113.5 228.8 )223.0 77.7S 205.6E 113.8 229.8 )223.8 77.7S 205.7E 114.0 230.8 )224.6 77.8S 205.8E 114.3 231.8 )225.5 5.9W 637.4 634.4 6.3W 649.8 646.8 6.8W 662.2 659.2 7.3W 674.6 671.6 7.8W 687.0 684.0 77.9S 205.9E 114.6 232.9 )226.5 77.9S 206.0E 114.8 234.0 )227.4 78.0S 206.1E 115.1 235.2 )228.4 78.0S 206.2E 115.4 236.4 )229.5 78.1S 206.3E 115.7 237.6 )230.6 8.3W 699.4 696.4 8.8W 711.8 708.7 9.3W 724.1 721.1 9.9W 736.5 733.4 10.4W 748.8 745.8 78.2S 206.5E 116.0 238.9 )231.7( 78.2S 206.6E 116.3 240.3 )232.9( 78.2S 206.7E 116.6 241.6 )234.1( 78.3S 206.8E 116.9 243.1 )235.4( 78.3S 206.9E 117.3 244.5 )236.7( ii.0W 761.1 758.1 ll.6W 773.5 770.4 12.3W 785.8 782.7 12.9W 798.3 795.3 13.5W 809.3 806.2 78.4S 207.0E 117.6 246.0 )238.1( 78.4S 207.1E 117.9 247.6 )239.5( 78.5S 207.2E 118.3 249.2 )240.9( 78.5S 207.4E 118.6 250.9 )242.4( 78.5S 207.5E 118.9 252.4 )243.7( 14.1W 820.2 817.1 14.7W 831.1 828.0 15.3W 842.0 838.9 16.0W 853.3 850.2 16.7W 864.1 861.1 78.6S 207.6E 119.2 253.9 )245.2( 78.6S 207.6E 119.5 255.5 )246.6( 78.6S 207.7E 119.9 257.2 )248.1( 78.6S 207.8E 120.2 258.9 )249.7( 78.7S 207.9E 120.5 260.7 )251.3( 17.4W 875.0 872.0 78.7S 208.0E 120.9 262.5 )253.0( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) '(114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 1 ZO0 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 22 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <0-3950'>,,WSP2,Pad 1J (WS Pilot) M.D. T.V.D. 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 1000.0 992.3 1011.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 58.3N 18.1W 885.8 882.8 78.7S 60.6N 18.8W 896.7 893.6 78.8S 63.0N 19.5W 907.5 904.4 78.8S 65.5N 20.3W 918.3 915.2 78.8S 68.0N 21.1W 929.0 926.0 78.8S 70.6N 21.9W 939.8 936.8 78.9S 73.3N 22.7W 950.5 947.5 78.9S 76.0N 23.6W 961.3 958.2 78.9S 78.8N 24.4W 972.0 968.9 78.9S 81.6N 25.3W 982.7 979.6 79.0S 84.5N 26.2W 993.3 990.3 79.0S 87.5N 27.1W 1003.9 1000.9 79.0S 90.5N 28.1W 1014.5 1011.5 79.1S 93.6N 29.0W 1025.2 1022.1 79.1S 96.7N 30.0W 1035.8 1032.7 79.1S 99.9N 31.0W 1046.3 1043.3 79.1S 103.1N 32.0W 1056.9 1053.9 79.1S 106.4N 33.0W 1067.4 1064.4 79.2S 109.8N 34.1W 1078.0 1074.9 79.2S 113.2N 35.1W 1088.5 1085.4 79.2S 116.7N 36.2W 1099.0 1096.0 79.2S 120.3N 37.3W 1109.5 1106.4 79.2S 123.9N 38.4W 1119.9 1116.9 79.2S 127.5N 39.6W 1130.3 1127.3 79.2S 131.2N 40.7W 1140.7 1137.7 79.2S 135.0N 41.9W 1150.9 1147.8 79.2S 138.8N 43.1W 1161.2 1158.2 79.2S 142.7N 44.3W 1171.5 1168.5 79.3S 146.7N 45.5W 1181.8 1178.8 79.2S 150.7N 46.7W 1192.1 1189.1 79.2S 154.7N 48.0W 1202.4 1199.4 79.2S 158.9N 49.3W 1212.7 1209.6 79.2S 163.0N 50.6W 1222.9 1219.8 79.2S 167.3N 51.9W 1233.1 1230.0 79.2S 171.6N 53.2W 1243.2 1240.2 79.2S 175.9N 54.6W 1253.3 1250.3 79.2S 180.3N 55.9W 1263.4 1260.4 79.2S 184.8N 57.3W 1273.5 1270.5 79.2S 189.3N 58.7W 1283.6 1280.5 79.2S 193.8N 60.1W 1293.6 1290.5 79.2S 198.5N 61.6W 1303.9 1300.9 79.2S 203.1N 63.0W 1313.9 1310.9 79.1S 207.9N 64.5W 1323.8 1320.8 79.1S 212.7N 66.0W 1333.7 1330.7 79.1S 217.5N 67.5W 1343.6 1340.6 79.1S 222.4N 69.0W 1353.5 1350.4 79.1S 227.4N 70.5W 1363.3 1360.2 79.1S 232.4N 72.1W 1373.1 1370.0 79.1S 237.4N 73.6W 1382.8 1379.8 79.1S 242.6N 75.2W 1392.6 1389.5 79.0S 247.7N 208.0E 121.2 264.4 )254.7 208.1E 121.6 266.3 )256.5 208.2E 121.9 268.3 )258.3 208.2E 122.3 270.3 )260.2 208.3E 122.6 272.4 )262.1 208.4E 123.0 274.5 )264.1 208.4E 123.4 276.8 )266.2 208.5E 123.7 279.0 )268.3 208.6E 124.1 281.4 )270.5 208.6E 124.5 283.8 )272.7 208.7E 124.8 286.2 )275.0 208.8E 125.2 288.8 )277.4 208.9E 125.6 291.4 )279.8 208.9E 126.0 294.0 )282.3 209.0E 126.3 296.7 )284.9( 209.1E 126.7 299.5 )287.5( 209.2E 127.1 302.3 )290.2( 209.3E 127.5 305.2 )292.9( 209.3E 127.8 308.2 )295.7( 209.4E 128.2 311.2 )298.6( 209.5E 128.6 314.3 )301.5( 209.6E 128.9 317.4 )304.5( 209.7E 129.3 320.6 )307.5( 209.7E 129.7 323.9 )310.6( 209.8E 130.0 327.2 )313.8( 209.9E 130.4 330.6 )317.1( 210.0E 130.8 334.1 )320.4( 210.1E 131.1 337.6 )323.7( 210.2E 131.5 341.2 )327.2( 210.3E 131.8 344.9 )330.7( 210.4E 132.2 348.6 )334.3( 210.5E 132.5 352.4 )337.9( 210.6E 132.8 356.3 )341.6( 210.7E 133.2 360.2 )345.4( 210.8E 133.5 364.2 )349.2( 210.9E 133.9 368.2 )353.1 211.0E 134.2 372.3 )357.0 211.2E 134.5 376.5 )361.0 211.3E 134.8 380.7 )365.1 211.4E 135.2 385.0 )369.2 211.5E 135.5 389.4 )373.4 211.5E 135.8 393.8 )377.7 211.6E 136.1 398.3 )382.0 211.7E 136.4 402.8 )386.4 211.8E 136.7 407.4 )390.9 211.9E 137.0 412.1 )395.4 212.0E 137.3 416.8 )400.0 212.1E 137.6 421.6 )404.6 212.2E 137.9 426.5 )409.3 212.3E 138.2 431.4 )414.1 76.8W 1402.3 1399.2 79.0S 212.3E 138.5 436.4 )418.9 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 23 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PGMS <O-3950'>,,WSP2,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm ElliDse Rect Coordinates Bearing Diet Sep'n 1455.6 1411.1 253.0N 1466.7 1420.8 258.2N 1477.8 1430.4 263.6N 1488.9 1439.9 269.0N 1500.0 1449.5 274.4N 78.5W 1411.9 1408.9 79.0S 80.1W 1421.6 1418.5 79.0S 81.7W 1431.2 1428.1 79.0S 83.4W 1440.7 1437.7 79.0S 85.1W 1450.3 1447.2 79.0S 212.4E 138.8 441.4 )423.8( 212.5E 139.1 446.5 )428.7( 212.6E 139.3 451.7 )433.7( 212.7E 139.6 456.9 )438.8( 212.8E 139.9 462.2 )443.9( 1510.9 1458.8 279.8N 1521.8 1468.1 285.2N 1532.7 1477.3 290.7N 1543.6 1486.5 296.2N 1554.4 1495.7 301.8N 86.8W 1459.6 1456.5 79.0S 88.5W 1468.9 1465.8 79.0S 90.2W 1478.1 1475.0 79.0S 91.9W 1487.3 1484.2 78.9S 93.6W 1496.5 1493.4 78.9S 212.8E 140.1 467.4 )449.0( 212.9E 140.4 472.7 )454.2( 213.0E 140.6 478.1 )459.4( 213.1E 140.9 483.5 )464.7( 213.2E 141.1 489.0 )470.0( 1565.3 1504.9 307.4N 1576.2 1514.0 313.1N 1584.1 1520.6 317.3N 1592.1 1527.2 321.5N 1600.0 1533.8 325.7N 95.4W 1505.6 1502.5 78.9S 97.1W 1514.7 1511.6 78.9S 98.4W 1521.3 1518.3 78.9S 99.7W 1527.9 1524.8 78.9S 101.0W 1534.5 1531.4 78.9S 213.3E 141.4 494.5 )475.4( 213.3E 141.6 500.1 )480.8( 213.4E 141.8 504.2 )484.8( 213.5E 142.0 508.3 )488.9( 213.5E 142.1 512.5 )492.9( 1611.1 1543.0 331.7N 102.9W 1543.7 1540.6 78.9S 213.6E 142.4 518.4 )498.7( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Alaska Oil & Gas Cons. Commission Anchorage PhilliDs Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 24 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : 1J-3 Version #3,,3,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100 . 0 100 . 0 0 . ON 200 . 0 200 . 0 0 . 0N 300 . 0 300 . 0 0 . ON 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.9N 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 56.0N 0.0E 2.0 0.0 0.0E 102.0 100.0 0 . 0E 202 . 0 200.0 0.0E 301.7 299.7 0 . OW 313 . 6 311 . 6 0.0W 325.5 323.5 0.1W 337.4 335.4 0.1W 349.9 347.9 0.2W 361.8 359.8 0.3W 373.7 371.7 0.4W 385.5 383.5 0.5W 397.4 395.4 0.7W 409.3 407.3 0.SW 421.2 419.1 1.0W 433.0 431.0 1.2W 444.9 442.8 1.4W 456.7 454.6 1.6W 468.5 466.4 1.8W 480.4 478.2 2.1W 492.2 490.0 2.3W 504.0 501.8 2.6W 515.8 513.6 2.9W 527.5 525.3 3.2W 539.3 537.0 3.6W 551.0 548.7 3.9W 562.8 560.4 4.3W 574.5 572.1 4.6W 586.9 584.4 5.0W 598.5 596.0 5.5W 610.2 607.6 5.9W 621.9 619.2 6.3W 633.5 630.7 6.8W 645.1 642.3 7.3W 656.7 653.8 7.8W 668.3 665.3 8.3W 679.8 676.7 8.8W 691.3 688.1 9.3W 702.8 699.5 9.9W 714.3 710.9 10.4W 725.8 722.2 ll.0W 737.2 733.5 ll.6W 749.4 745.5 12.3W 760.8 756.8 12.9W 772.1 768.0 13.5W 782.1 777.8 44.9S 155.0E 106.2 161.4 44.9S 155.0E 106.2 161.4 44.9S 155.0E 106.2 161.4 44.9S 155.0E 106.2 161.4 44.9S 155.0E 106.2 161.4 14.1W 792.0 787.6 14.7W 802.0 797.4 15.3W 811.9 807.2 16.0W 821.9 817.0 16.7W 832.5 827.5 44.9S 155.1E 106.2 161.5 44.8S 155.2E 106.2 161.7 44.8S 155.4E 106.2 162.0 44.7S 155.6E 106.2 162.3 44.6S 155.9E 106.3 162.8 N/A 160.6 159.9 159.2 159.1 44.6S 156.2E 106.3 163.2 44.5S 156.6E 106.4 163.8 44.4S 157.0E 106.4 164.5 44.2S 157.5E 106.5 165.2 44.1S 158.0E 106.6 166.0 43.9S 158.5E 106.6 166.8 43.8S 159.1E 106.7 167.8 43.6S 159.8E 106.8 168.8 43.4S 160.5E 106.9 169.9 43.2S 161.2E 107.0 171.0 43.0S 162.0E 107.1 172.3 159.1 159.2 159.4 159.6 159.9 160.3 160.8 161.3 161.9 162.6 163.4 164.2 165.1 166.1 167.1 168.3 42.8S 162.8E 107.2 173.6 )169.4 42.6S 163.7E 107.3 175.0 )170.7 42.3S 164.6E 107.4 176.4 )172.1 42.0S 165.6E 107.6 177.9 )173.5 41.8S 166.6E 107.7 179.6 )175.0 41.5S 167.7E 107.8 181.2 )176.5 41.2S 168.9E 107.9 183.0 )178.2 40.9S 170.0E 108.1 184.8 )179.9 40.5S 171.2E 108.2 186.7 )181.6 40.2S 172.4E 108.4 188.7 )183.5 39.9S 173.7E 108.5 190.8 )185.4 39.5S 175.1E 108.7 192.9 )187.4 39.2S 176.4E 108.8 195.1 )189.5 38.8S 177.8E 109.0 197.4 )191.6 38.4S 179.3E 109.1 199.7 )193.9( 38.0S 180.8E 109.3 202.1 )196.1( 37.6S. 182.3E 109.4 204.6 198.5( 37.2S 183.9E 109.6 207.2 200.9( 36.7S 185.5E 109.8 209.8 203.4( 36.3S 187.2E 109.9 212.5 206.0( 35.8S 189.0E 110.1 215.3 208.7( 35.3S 190.7E 110.2 218.2 211.4( 34.8S 192.5E 110.4 221.1 214.2( 34.4S 194.1E 110.6 223.8 216.7( 34.0S 195.7E 110.7 226.5 219.3( 33.5S 197.4E 110.9 229.3 222.0( 33.1S 199.1E 111.0 232.2 224.8( 32.6S 200.8E 111.2 235.2 227.6( 32.0S 202.7E 111.3 238.2 230.4( 233.4( 17.4W 842.4 837.1 31.5S 204.5E 111.5 241.3 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ FEB 2 I Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 25 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : 1J-3 Version #3,,3,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 1000.0 992.3 1011 1 1002.9 1022 2 1013.6 1033 3 1024.2 1044 4 1034.8 1055 6 1045.4 1066 7 1056.0 1077 8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 58.3N 18.1W 852.2 846.8 30.9S 60.6N 18.8W 862.1 856.4 30.3S 63.0N 19.5W 871.8 866.0 29.6S 65.5N 20.3W 881.6 875.5 29.0S 68.0N 21.1W 891.3 885.0 28.3S 70.6N 21.9W 901.0 894.4 27.6S 73.3N 22.7W 910.7 903.9 26.9S 76.0N 23.6W 921.1 914.1 26.0S 78.8N 24.4W 930.7 923.4 25.2S 81.6N 25.3W 940.3 932.7 24.4S 84.5N 26.2W 949.8 941.9 23.6S 87.5N 27.1W 959.3 951.1 22.7S 90.5N 28.1W 968.8 960.2 21.9S 93.6N 29.0W 978.2 969.3 21.0S 96.7N 30.0W 988.5 979.3 19.9S 206.4E 111.7 244.4 208.3E 111.8 247.7 210.2E 112.0 251.0 212.1E 112.1 254.3 214.1E 112.3 257.8 216.1E 112.4 261.3 218.2E 112.6 264.8 220.5E 112.7 268.5 222.6E 112.8 272.2 224.7E 113.0 276.0 226.9E 113.1 279.8 236.4( 239.5( 242.7( 245.9( 249.2( 252.5( 256.0( 259.4( 263.0 266.6 270.3 229.1E 113.3 283.7 )274.0 231.3E 113.4 287.7 )277.8 233.6E 113.6 291.7 )281.7 236.1E 113.7 295.8 )285.7 99.9N 31.0W 997.9 988.3 19.0S 103.1N 32.0W 1007.2 997.3 18.0S 106.4N 33.0W 1016.5 1006.2 17.0S 109.8N 34.1W 1025.7 1015.0 16.0S 113.2N 35.1W 1034.9 1023.9 15.0S 238.5E 113.8 300.0 )289.7 240.8E 113.9 304.2 )293.7 243.2E 114.1 308.5 )297.8 245.6E 114.2 312.9 )302.0 248.0E 114.4 317.3 )306.3 116.7N 36.2W 1044.1 1032.6 13.9S 120.3N 37.3W 1054.2 1042.3 12.7S 123.9N 38.4W 1063.3 1050.9 11.6S 127.5N 39.6W 1072.3 1059.6 10.5S 131.2N 40.7W 1081.3 1068.1 9.4S 135.0N 41.9W 1090.3 1076.6 8.2S 138.8N 43.1W 1100.3 1086.1 6.9S 142.7N 44.3W 1109.1 1094.5 5.7S 146.7N 45.5W 1118.0 1102.8 4.5S 150.7N 46.7W 1126.8 1111.1 3.3S 154.7N 48.0W 1135.5 1119.4 2.1S 158.9N 49.3W 1144.2 1127.6 0.8S 163.0N 50.6W 1154.0 1136.8 0.6N 167.3N 51.9W 1162.6 1144.8 1.9N 171.6N 53.2W 1171.2 1152.9 3.2N 175.9N 54.6W 1179.8 1160.8 4.5N 180.3N 55.9W 1189.4 1169.8 6.0N 184.8N 57.3W 1197.9 1177.7 7.4N 189.3N 58.7W 1206.3 1185.5 8.7N 193.8N 60.1W 1214.6 1193.2 10.iN 198.5N 61.6W 1222.9 1200.9 ll.5N 203.1N 63.0W 1232.4 1209.7 13.1N 207.9N 64.5W 1240.6 1217.3 14.5N 212.7N 66.0W 1248.8 1224.8 15.9N 217.5N 67.5W 1256.9 1232.2 17.4N 222.4N 69.0W 1266.3 1240.8 19.0N 227.4N 70.5W 1274.3 1248.2 20.5N 232.4N 72.1W 1282.3 1255.5 21.9N 237.4N 73.6W 1290.2 1262.7 23.4N 242.6N 75.2W 1299.4 1271.1 25.1N 250.5E 114.5 321.8 253.2E 114.6 326.3 255.7E 114.7 330.9 258.3E 114.9 335.6 260.8E 115.0 340.3 263.4E 115.1 345.1 266.3E 115.2 350.0 268.9E 115.4 354.9 271.5E 115.5 359.9 274.2E 115.6 364.9 276.8E 115.8 370.0 279.5E 115.9 375.2 282.6E 116.0 380.4 285.3E 116.1 385.6 288.0E 116.3 391.0 290.8E 116.4 396.3 293.9E 116.5 401.8 296.7E 116.6 407.3 299.5E 116.7 412.8 302.3E 116.9 418.4 305.2E 117.0 424.1 308.4E 117.1 429.8 311.3E 117.2 435.6 314.1E 117.4 441.4 317.0E 117.5 447.3 320.3E 117.6 453.3 323.2E 117.7 459.2 326.1E 117.9 465.3 310.6 314.9 319.4 323.9 328.4 333.0 337.7 342.4 347.2 352.0 356.9( 361.9( 366.9( 371.9( 377.1( 382.3 ( 387.5( 392.8( 398.1( 403.5( 409.0( 414.4( 420.0( 425.6( 431.3( 437.0( 442.7( 448.6( 329.0E 118.0 471.4 )454.4( 332.4E 118.1 477.5 )460.3( 247.7N 76.8W 1307.2 1278.2 26.6N 335.4E 118.2 483.7 )466.3( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. RECEtVEE),, ,c, Page 26 FEB g ] Z001 Alaska Oil & Gas Cons. Commission Anchorage Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Reference wellpath Object wellpath : 1J-3 Version #3,,3,Pad 1J (WS Pilot) M.D. T.V.D. Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 1455.6 1466.7 1477.8 1488.9 1500.0 1411.1 1420.8 1430.4 1439.9 1449.5 253.0N 258.2N 263.6N 269.0N 274.4N 78.5W 1315.0 1285.2 80.1W 1322.7 1292.2 81.7W 1331.8 1300.4 83.4W 1339.4 1307.3 85.1W 1347.0 1314.1 28.1N 338.3E 118.3 490.0 )472.3( 29.6N 341.2E 118.5 496.3 )478.4( 31.4N 344.7E 118.6 502.6 )484.5( 32.9N 347.6E 118.7 509.0 )490.6( 34.5N 350.5E 118.8 515.5 )496.8( RECEIVED FEB g 1 2001 Alaska Oil & Gas Cons. Commission Anchorage All data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. CLEARANCE LISTING Page 27 Pad 1J (WS Pilot),9 Your ref : 1J-09 Version#2 Kuparuk River Unit,North Slope, Alaska Last revised : 13-Feb-2001 Reference wellpath Object wellpath : PMSS <0-???'>,,3,Pad 1J (WS Pilot) Horiz Min'm Ellipse M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist Sep'n 0.0 0.0 0.0N 100.0 100.0 0.0N 200.0 200.0 0.0N 300.0 300.0 0.0N 312.5 312.5 0.0N 325.0 325.0 0.1N 337.5 337.5 0.2N 350.0 350.0 0.4N 362.5 362.5 0.7N 375.0 375.0 0.gN 387.5 387.5 1.3N 400.0 400.0 1.7N 412.5 412.5 2.1N 425.0 425.0 2.6N 437.5 437.4 3.2N 450.0 449.9 3.7N 462.5 462.4 4.4N 475.0 474.9 5.1N 487.5 487.4 5.9N 500.0 499.8 6.7N 512.5 512.3 7.5N 525.0 524.8 8.4N 537.5 537.2 9.4N 550.0 549.7 10.4N 562.5 562.1 ll.5N 575.0 574.6 12.6N 587.5 587.0 13.8N 600.0 599.5 15.0N 612.5 611.9 16.3N 625.0 624.3 17.6N 637.5 636.7 19.0N 650.0 649.1 20.4N 662.5 661.5 21.9N 675.0 673.9 23.4N 687.5 686.3 25.0N 700.0 698.7 26.6N 712.5 711.1 28.3N 725.0 723.4 30.1N 737.5 735.8 31.8N 750.0 748.2 33.7N 762.5 760.5 35.6N 775.0 772.8 37.5N 787.5 785.2 39.5N 800.0 797.5 41.6N 811.1 808.4 43.4N 822.2 819.3 45.4N 833.3 830.2 47.4N 844.4 841.1 49.4N 855.6 852.0 51.5N 866.7 862.9 53.7N 877.8 873.8 56.0N 0.0E 1.5 -0.5 0.0E 99.3 97.3 0 . 0E 198 . 1 196.1 0.0E 296.6 294.5 0.0W 309.1 307.0 0.0W 321.6 319.4 0.1W 333.7 331.5 0.1W 346.2 344.0 0.2W 358.7 356.5 0.3W 371.1 368.9 44.9S 155.0E 106.2 161.4 N/A 44.4S 155.8E 105.9 162.1 161.3 43.1S 158.3E 105.2 164.1 162.6 41.3S 161.8E 104.3 167.0 164.8 41.0S 162.2E 104.2 167.5 165.1 40.8S 162.7E 104.1 167.9 40.6S 163.2E 104.0 168.4 40.4S 163.7E 104.0 168.9 40.2S 164.2E 103.9 169.5 40.0S 164.7E 103.9 170.1 165.5 165.8 166.3 166.7 167.3 0.4W 382.6 380.4 0.5W 395.1 392.9 0.7W 407.6 405.4 0.8W 418.5 416.2 1.0W 430.9 428.7 1.2W 441.8 439.5 1.4W 454.2 451.9 1.6W 466.7 464.3 1.8W 477.3 474.9 2.1W 489.7 487.2 2.3W 502.1 499.6 2.6W 512.4 509.8 2.9W 524.8 522.2 3.2W 535.0 532.3 3.6W 547.4 544.6 3.9W 559.7 556.9 4.3W 570.2 567.3 4.6W 582.5 579.6 5.0W 594.8 591.8 5.5W 605.5 602.4 5.9W 617.8 614.6 6.3W 628.4 625.1 6.8W 640.7 637.3 7.3W 653.0 649.4 7.8W 663.2 659.5 8.3W 675.4 671.6 8.8W 685.3 681.4 9.3W 697.5 693.4 9.9W 707.2 703.0 10.4W 719.3 714.9 39.8S 165.2E 103.9 170.8 39.5S 165.8E 103.9 171.5 39.3S 166.4E 103.9 172.3 39.1S 167.0E 103.9 173.1 38.8S 167.7E 104.0 174.1 38.5S 168.4E 104.0 175.1 38.2S 169.2E 104.0 176.1 37.8S 170.1E 104.0 177.3 37.5S 170.9E 104.1 178.5 37.2S 171.8E 104.1 179.8 36.8S 172.9E 104.2 181.2 36.5S 173.8E 104.3 182.6 36.2S 174.9E 104.4 184.2 36.0S 175.9E 104.5 185.8 35.6S 177.1E 104.6 187.5 35.3S 178.4E 104.7 189.3 35.1S 179.5E 104.9 191.2 34.8S 180.9E 105.0 193.2 34.4S 182.4E 105.1 195.2 34.0S 183.7E 105.3 197.3 33.6S 185.2E 105.4 199.4 33.2S 186.6E 105.5 201.6 32.7S 188.2E 105.6 203.9 32.2S 189.9E 105.8 206.3 31.7S 191.3E 105.9 208.7 31.3S 193.1E 106.0 211.2 31.0S 194.5E 106.3 213.9 30.7S 196.4E 106.4 216.6 30.5S 197.9E 106.7 219.4 30.3S 199.8E 106.9 222.3 167.8 168.4 169.1 169.8 170.6 171.5 172.5 173.5 174.6 175.8 177.1 178.4 179.9 181.4 183.0 184.7 186.4 188.2 190.1 192.1 194.1 196.2 198.4 200.6 202.9 205.3 207.8 210.4 213.1 215.9 ii.0W 728.8 724.4 ll.6W 740.9 736.3 12.3W 751.6 746.8 12.9W 763.7 758.7 13.5W 774.3 769.2 30.3S 201.4E 107.2 225.3 218.8 30.3S 203.4E 107.5 228.4 )221.7 30.3S 205.3E 107.8 231.6 )224.8 30.3S 207.3E 108.1 234.9 )227.9 30.3S 209.2E 108.3 237.8 )230.7 14.1W 785.1 779.8 14.7W 795.7 790.2 15.3W 806.4 800.7 16.0W 817.1 811.3 16.7W 827.7 821.7 30.3S 211.0E 108.6 240.8 )233.5 30.2S 212.9E 108.8 243.8 )236.4 30.1S 214.8E 109.1 246.8 )239.3 29.9S 216.7E 109.3 249.9 )242.3 29.7S 218.6E 109.5 253.0 )245.2 17.4W 838.3 832.2 29.5S 220.5E 109.8 256.2 )248.2 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 28 Your ref : 1J-09 Version92 Last revised : 13-Feb-2001 RECEIVED FEB 2, 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Reference wellpath M.D. T.V.D. 888.9 884.6 900.0 895.4 911.1 906.3 922.2 917.1 933.3 927.9 944.4 938.6 955.6 949.4 966.7 960.1 977.8 970.9 988.9 981.6 1000.0 992.3 1011.1 1002.9 1022.2 1013.6 1033.3 1024.2 1044.4 1034.8 1055.6 1045.4 1066.7 1056.0 1077.8 1066.6 1088.9 1077.1 1100.0 1087.6 1111.1 1098.1 1122.2 1108.6 1133.3 1119.0 1144.4 1129.5 1155.6 1139.9 1166.7 1150.3 1177.8 1160.6 1188.9 1171.0 1200.0 1181.3 1211.1 1191.6 1222.2 1201.8 1233.3 1212.1 1244.4 1222.3 1255.6 1232.5 1266.7 1242.6 1277.8 1252.8 1288.9 1262.9 1300.0 1273.0 1311.1 1283.0 1322.2 1293.0 1333.3 1303.0 1344.4 1313.0 1355.6 1323.0 1366.7 1332.9 1377.8 1342.8 1388.9 1352.6 1400.0 1362.4 1411.1 1372.2 1422.2 1382.0 1433.3 1391.7 1444.4 1401.4 Object wellpath : PMSS <O-???'>,,3,Pad 1J (WS Pilot) Rect Coordinates M.D. T.V.D. Horiz Min'm Ellipse Rect Coordinates Bearing Dist Sep'n 58.3N 18.1W 848.6 842.3 29.3S 60.6N 18.8W 859.2 852.7 29.0S 63.0N 19.5W 869.8 863.1 28.6S 65.5N 20.3W 879.5 872.7 28.3S 68.0N 21.1W 890.1 883.0 27.9S 70.6N 21.9W 900.6 893.3 27.5S 73.3N 22.7W 910.3 902.9 27.1S 76.0N 23.6W 920.8 913.1 26.6S 78.8N 24.4W 931.3 923.4 26.1S 81.6N 25.3W 940.0 931.9 25.6S 84.5N 26.2W 950.4 942.1 25.0S 87.5N 27.1W 960.8 952.3 24.4S 90.5N 28.1W 968.4 959.7 24.0S 93.6N 29.0W 978.8 969.7 23.3S 96.7N 30.0W 989.1 979.8 22.6S 99.9N 31.0W 999.4 989.8 21.9S 103.1N 32.0W 1006.8 997.0 21.4S 106.4N 33.0W 1017.1 1007.0 20.6S 109.8N 34.1W 1027.3 1016.9 19.8S 113.2N 35.1W 1034.8 1024.2 19.2S 116.7N 36.2W 1045.0 1034.0 18.3S 120.3N 37.3W 1055.1 1043.8 17.4S 123.9N 38.4W 1062.8 1051.2 16.7S 127.5N 39.6W 1072.9 1060.9 15.8S 131.2N 40.7W 1083.0 1070.6 14.8S 135.0N 41.9W 1093.0 1080.2 13.8S 138.8N 43.1W 1100.6 1087.4 13.0S 142.7N 44.3W 1110.5 1097.0 12.0S 146.7N 45.5W 1120.5 1106.5 10.9S 150.7N 46.7W 1128.6 1114.2 10.0S 154.7N 158.9N 163.0N 167.3N 171.6N 175.9N 180.3N 184.8N 189.3N 193.8N 198.5N 203.1N 207.9N 212.7N 217.5N 222.4N 227.4N 232.4N 237.4N 242.6N 48.0W 1138.5 1123.7 8.8S 49.3W 1147.2 1132.0 7.8S 50.6W 1157.1 1141.4 6.5S 51.9W 1166.9 1150.7 5.2S 53.2W 1175.6 1158.9 4.0S 54.6W 1185.4 1168.2 2.7S 55.9W 1194.0 1176.3 1.4S 57.3W 1203.8 1185.5 0.1N 58.7W 1213.5 1194.6 1.6N 60.1W 1219.7 1200.4 2.6N 61.6W 1229.3 1209.5 4.1N 63.0W 1239.0 1218.4 5.7N 64.5W 1242.5 1221.7 6.3N 66.0W 1252.0 1230.6 8.0N 67.5W 1261.5 1239.3 9.7N 69.0W 1264.8 1242.3 10.2N 70.5W 1274.1 1250.9 ll.9N 72.1W 1283.5 1259.5 13.7N 73.6W 1292.8 1268.0 15.4N 75.2W 1295.6 1270.6 15.9N 76.8W 1304.8 1278.9 247.7N 222.4E 110.0 259.3 )251.3( 224.3E 110.2 262.6 )254.4( 226.3E 110.4 265.9 )257.5( 228.1E 110.7 269.2 )260.7( 230.1E 110.9 272.6 )264.0( 232.1E 111.1 276.0 )267.3( 234.0E 111.4 279.5 )270.6( 236.0E 111.6 283.1 )274.0( 238.1E 111.8 286.6 )277.4( 239.8E 112.0 290.3 )280.9( 241.9E 112.2 294.0 )284.4( 244.1E 112.4 297.7 )288.0( 245.7E 112.7 301.6 )291.7( 247.9E 112.9 305.5 )295.5( 250.2E 113.1 309.5 )299.3( 252.5E 113.2 313.5 )303.2( 254.2E 113.5 317.6 )307.1( 256.6E 113.7 321.8 )311.1( 259.0E 113.9 326.0 )315.2( 260.8E 114.1 330.3 )319.3( 263.3E 114.3 334.7 )323.5( 265.8E 114.4 339.1 )327.8( 267.7E 114.7 343.6 )332.1( 270.2E 114.8 348.1 )336.4( 272.8E 115.0 352.8 )340.9( 275.5E 115.1 357.4 )345.3( 277.5E 115.4 362.1 )349.9( 280.1E 115.5 366.9 )354.5( 282.8E 115.6 371.8 )359.1( 285.1E 115.8 376.7 )363.9( 287.8E 116.0 381.6 )368.6( 290.3E 116.1 386.6 )373.4( 293.1E 116.3 391.6 )378.2( 295.9E 116.4 396.7 )383.1( 298.4E 116.5 401.9 )388.1( 301.3E 116.6 407.1 )393.0( 303.9E 116.8 412.3 )398.1( 306.8E 116.9 417.6 )403.1( 309.8E 117.0 422.9 )408.3( 311.7E 117.2 428.3 )413.5( 314.8E 117.3 433.7 )418.7( 317.8E 117.4 439.3 )424.0( 319.0E 117.7 444.9 )429.4( 322.2E 117.8 450.6 )434.9( 325.4E 117.9 456.3 )440.4( 326.5E 118.2 462.2 )446.1( 329.8E 118.3 468.1 )451.7( 333.1E 118.4 474.0 )457.5( 336.5E 118.4 480.1 )463.3 337.5E 118.8 486.2 )469.2 17.7N 341.0E 118.8 492.4 )475.2 Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot 99 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska CLEARANCE LISTING Page 29 Your ref : 1J-09 Version%2 Last revised : 13-Feb-2001 RECEIVED FEB Alaska Oil & Gas Cons. Commission Anchorage Reference wellpath Object wellpath : PMSS <O-???'>,,3,Pad 1J (WS Pilot) Horiz Min'm M.D. T.V.D. Rect Coordinates M.D. T.V.D. Rect Coordinates Bearing Dist 1455.6 1411.1 253.0N 78.5W 1314.5 1287.6 19.6N 344.6E 118.9 498.7 1466.7 1420.8 258.2N 80.1W 1317.7 1290.5 20.3N 345.9E 119.2 505.0 1477.8 1430.4 263.6N 81.7W 1326.8 1298.7 22.1N 349.4E 119.3 511.4 1488.9 1439.9 269.0N 83.4W 1335.8 1306.8 24.0N 352.9E 119.3 517.8 Ellipse Sep'n )481.2( )487.4( )493.5( )499.6( Ail data is in feet unless otherwise stated. Casing dimensions are not included. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 2 I 2r!n Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot) 9 slot #9 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING INCLUDING POSITION UNCERTAINTIES by Baker Hughes INTEQ Your ref : 1J-09 Version#2 Our ref : prop4238 License : Date printed : 13-Feb-2001 Date created : 26-0ct-2000 Last revised : 13-Feb-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.699,w149 31 33.517 Slot Grid coordinates are N 5945963.299, E 558634.622 Slot local coordinates are 2152.86 N 2574.98 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED FEB ;8 1 ZOO1 Alaska Oil & Gas Cons, Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 KuDaruk River Unit,North Slope, Alaska PROPOSAL LISTING Page 1 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Measured Inclin. Azimuth True Vert R E C T A N G U L A R Vert Ellipse Semi Axes Minor Depth Degrees Degrees Depth C O 0 R D I N A T E S Sect Major Minor Vert. Azi. 0.00 0.00 0.00 0.00 100.00 0.00 342.77 100.00 200.00 0.00 342.77 200.00 300.00 0.00 342.77 300.00 400.00 2.00 342.77 399.98 0.00 N 0.00 N 0.00 N 0.00 N 1.67 N 500.00 4.00 342.77 499.84 600.00 6.00 342.77 599.45 700.00 8.00 342.77 698.70 800.00 10.00 342.77 797.47 900.00 13.00 342.77 895.45 6.67 N 14.99 N 26.63 N 41.57 N 60.61 N 1000.00 16.00 342.77 992.25 84.52 N 1100.00 19.00 342.77 1087.61 113.24 N 1200.00 22.00 342.77 1181.27 146.68 N 1300.00 25.00 342.77 1272.96 184.76 N 1400.00 28.00 342.77 1362.45 227.38 N 1500.00 31.00 342.77 1449.47 274.40 N 1576.21 33.29 342.77 1514.00 313.13 N 0.00 E 0.00 0.00 0.00 0.00 N/A 0.00 E 0.00 0.48 0.48 0.26 N/A 0.00 E 0.00 0.96 0.96 0.52 N/A 0.00 E 0.00 1.43 1.43 0.77 N/A 0.52 W 1.75 2.11 1.91 1.03 72.77 2.07 W 6.98 2.99 2.39 1.29 72.77 4.65 W 15.69 3.93 2.88 1.56 72.77 8.26 W 27.88 4.90 3.37 1.84 72.77 12.89 W 43.52 5.88 3.87 2.13 72.77 18.80 W 63.46 6.86 4.38 2.44 72.77 26.21 W 88.49 7.83 4.92 2.78 72.77 35.12 W 118.56 8.80 5.47 3.15 72.77 45.49 W 153.58 9.74 6.06 3.56 72.77 57.30 W 193.45 10.68 6.68 4.00 72.77 70.52 W 238.06 11.59 7.34 4.49 72.77 85.11 W 287.30 12.49 8.05 5.02 72.77 97.12 W 327.84 13.15 8.62 5.45 72.77 1600.00 34.00 342.77 1533.80 325.72 N 101.02 W 341.02 13.36 8.79 5.59 72.77 1700.00 37.00 342.77 1615.20 381.17 N 118.22 W 399.09 14.20 9.59 6.20 72.77 1800.00 40.00 342.77 1693.46 440.62 N 136.66 W 461.33 15.02 10.44 6.86 72.77 1900.00 43.00 342.77 1768.34 503.90 N 156.29 W 527.58 15.80 11.35 7.56 72.77 2000.00 46.00 342.77 1839.66 570.84 N 177.05 W 597.67 16.56 12.31 8.29 72.77 2100.00 49.00 342.77 1907.21 641.25 N 198.89 W 671.39 17.28 13.33 9.06 72.77 2200.00 52.00 342.77 1970.81 714.94 N 221.75 W 748.54 17.97 14.42 9.87 72.77 2293.90 54.82 342.77 2026.78 786.95 N 244.08 W 823.93 18.59 15.49 10.66 72.77 2500.00 54.82 342.77 2145.53 947.83 N 293.98 W 992.37 19.93 17.90 12.42 72.77 3000.00 54.82 342.77 2433.63 1338.15 N 415.04 W 1401.03 23.93 23.16 16.66 162.77 3500.00 54.82 342.77 2721.72 1728.46 N 536.10 W 1809.69 30.09 26.36 20.90 162.77 3707.02 54.82 342.77 2841.00 1890.06 N 586.23 W 1978.89 32.67 27.68 22.65 162.77 4000.00 54.82 342.77 3009.81 2118.78 N 657.17 W 2218.35 36.31 29.54 25.13 162.77 4493.22 54.82 342.77 3294.00 2503.80 N 776.59 W 2621.47 42.49 32.67 29.31 162.77 4500.00 54.82 342.77 3297.91 2509.09 N 778.23 W 2627.01 42.57 32.72 29.37 162.77 4736.19 54.82 342.77 3434.00 2693.47 N 835.42 W 2820.05 45.54 34.21 31.37 162.77 5000.00 54.82 342.77 3586.00 2899.41 N 899.29 W 3035.67 48.86 35.88 33.60 162.77 5265.53 54.82 342.77 3739.00 3106.69 N 963.58 W 3252.69 52.20 37.56 35.85 162.77 5500.00 54.82 342.77 3874.10 3289.72 N 1020.35 W 3444.33 55.15 39.04 37.83 162.77 5612.64 54.82 342.77 3939.00 3377.65 N 1047.63 W 3536.39 56.57 39.75 38.79 162.77 6000.00 54.82 342.77 4162.19 3680.04 N 1141.41 W 3852.98 61.46 42.19 42.07 162.77 6384.96 54.82 342.77 4384.00 3980.55 N 1234.62 W 4167.62 66.32 44.61 45.33 162.77 6500.00 54.82 342.77 4450.28 4070.35 N 1262.48 W 4261.64 67.78 45.34 46.30 162.77 7000.00 54.82 342.77 4738.38 4460.67 N 1383.54 W 4670.30 74.10 48.48 50.53 162.77 7500.00 54.82 342.77 5026.47 4850.98 N 1504.60 W 5078.96 80.42 51.62 54.77 162.77 7929.60 54.82 342.77 5274.00 5186.34 N 1608.62 W 5430.08 85.86 54.32 58.40 162.77 8000.00 54.82 342.77 5314.57 5241.30 N 1625.66 W 5487.62 86.75 54.76 59.00 162.77 8363.48 54.82 342.77 5524.00 5525.04 N 1713.67 W 5784.70 91.35 57.04 62.08 162.77 8500.00 54.82 342.77 5602.66 5631.61 N 1746.73 W 5896.28 93.08 57.90 63.23 162.77 8911.92 54.82 342.77 5840.00 5953.16 N 1846.46 W 6232.94 98.29 60.48 66.72 162.77 9000.00 54.82 342.77 5890.75 6021.93 N 1867.79 W 6304.94 99.41 61.03 67.46 162.77 9167.04 54.82 342.77 5987.00 6152.32 N 1908.23 W 6441.46 101.53 62.08 68.88 162.77 9227.78 54.82 342.77 6022.00 6199.74 N 1922.94 W 6491.11 102.30 62.46 69.39 162.77 Ail data is in feet unless otherwise stated. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Bottom hole distance is 6892.54 on azimuth 342.77 degrees from wellhead. Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB g I 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 9361.42 54.82 342.77 6099.00 6304.06 N 1955.30 W 9491.57 54.82 342.77 6173.99 6405.66 N 1986.81 W 9491.59 54.82 342.77 6174.00 6405.67 N 1986.81 W 9500.00 54.82 342.77 6178.85 6412.24 N 1988.85 W 9536.71 54.82 342.77 6200.00 6440.90 N 1997.74 W PROPOSAL LISTING Page 2 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Vert Ellipse Semi Axes Minor Sect Major Minor Vert. Azi. 6600.33 103.99 63.29 70.52 162.77 6706.71 105.64 64.11 71.62 162.77 6706.72 105.64 64.11 71.62 162.77 6713.60 105.74 64.16 71.70 162.77 6743.60 106.21 64.39 72.01 162.77 9557.54 54.82 342.77 6212.00 6457.16 N 2002.78 W 6760.62 9574.89 54.82 342.77 6222.00 6470.71 N 2006.98 W 6774.81 9588.78 54.82 342.77 6230.00 6481.54 N 2010.34 W 6786.16 9718.94 54.82 342.77 6305.00 6583.16 N 2041.86 W 6892.54 106.47 64.52 72.18 162.77 106.69 64.63 72.33 162.77 106.87 64.72 72.45 162.77 108.52 65.54 73.55 162.77 POSITION UNCERTAINTY SUMMARY Depth Position Uncertainty From To Survey Tool Error Model Major Minor Vert. 0 9719 MWD + IFR (Alaska) - Corrected Dar User specified 108.52 65.54 73.55 1. Ellipse dimensions are half axis. 2. Casing dimensions are not included. 3. Ellipses are calculated on 2.58 standard deviations. 4. Uncertainty calculations start at drill depth zero. 5. Surface position uncertainty is not included. 6. Where two surveys are tied together the errors of one are considered to have a systematic relationship to the corresponding errors of the other. 7. Detailed description of the INTEQ error models can be found in the Ec*Trak manual. Ail data is in feet unless otherwise stated. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Bottom hole distance is 6892.54 on azimuth 342.77 degrees from wellhead. Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB g 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 800.00 1576.21 2293.90 3707.02 4493.22 4736.19 5265.53 5612.64 6384.96 7929.60 8363.48 8911.92 9167.04 9227.78 9361.42 9491.57 9491.59 9536.71 9557.54 9574.89 9588.78 9718.94 300 00 797 47 1514 00 2026 78 2841 00 3294 00 3434 00 3739 00 3939 00 4384 00 5274 00 5524 00 5840.00 5987.00 6022.00 6099.00 6173.99 6174.00 6200°00 6212.00 6222.00 6230.00 6305.00 0.00 41.57 313.13 786.95 1890.06 2503.80 2693.47 3106.69 3377.65 3980.55 5186.34 5525.04 5953 16 6152 32 6199 74 6304 06 6405 66 6405 67 6440 90 6457 16 6470 71 6481 54 6583 16 0 00 E 12 89 W 97 12 W 244 08 W 586 23 W 776 59 W 835 42 W 963 58 W 1047.63 W 1234.62 W 1608.62 W 1713.67 W 1846.46 W 1908.23 W 1922.94 W 1955.30 W 1986.81 W 1986.81 W 1997.74 W 2002.78 W 2006.98 W 2010.34 W 2041.86 W KOP Beg 3/100 Bld Permafrost EOC Top U~nu Base Ugnu Top West Sak Base West Sak 9 5/8" Casing Pt C80 C50 C40 C30 C20 Base HRZ/7" Casing Pt K-1 Target-Top C4/KupD 1J-09 C4 Rvsd 26-Jan-01 Top C3 Top C2 Top C1 Top B Shale TD - Casing Pt. Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 9718.94 6305.00 6583.16N 2041.86W 3-1/2" tubing 0.00 0.00 0.00N 0.00E 9227.78 6022.00 6199.74N 1922.94W 7" Casing 0.00 0.00 0.00N 0.00E 5612.64 3939.00 3377.65N 1047.63W 9 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1J-09 C4 Rvsd 26-Jan 556596.000,5952352.000,0.0000 6174.00 6405.67N 1986.81W 20-Dec-2000 RECEIVED FEB 1 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot) 9 slot #9 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 1J-09 Version#2 Our ref : prop4238 License : Date printed : 13-Feb-2001 Date created : 26-Oct-2000 Last revised : 13-Feb-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is nT0 15 46.699,w149 31 33.517 Slot Grid coordinates are N 5945963.299, E 558634.622 Slot local coordinates are 2152.86 N 2574.98 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED FEB g ] 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 KuDaruk River Unit,North Slope, Alaska Measured Depth 0.00 100.00 200.00 300.00 400.00 500.00 600.00 700.00 800.00 900.00 1000.00 1100.00 1200.00 1300.00 1400.00 1500.00 1576.21 1600.00 1700.00 1800.00 1900.00 2000.00 2100.00 2200.00 2293.90 2500.00 3000.00 3500.00 3707.02 4000.00 4493.22 4500.00 4736.19 5000.00 5265.53 5500.00 5612.64 6000.00 6384.96 6500.00 7000.00 7500.O0 7929,60 8000.00 8363.48 8500.00 8911.92 9000.00 9167.04 9227.78 PROPOSAL LISTING Page 1 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Inclin Azimuth True Vert R E C T A N G U L A R G R I D C O 0 R D S G E O Degrees Degrees Depth C 0 0 R D I N A T E S Easting Northing C 0 0 0.00 0.00 0.00 0.00N 0.00E 558634.62 5945963.30 n70 15 0.00 342.77 100.00 0.00N 0.00E 558634.62 5945963.30 n70 15 0.00 342.77 200.00 0.00N 0.00E 558634.62 5945963.30 nT0 15 0.00 342.77 300.00 0.00N 0.00E 558634.62 5945963.30 nT0 15 2.00 342.77 399.98 1.67N 0.52W 558634.09 5945964.96 nT0 15 4.00 342.77 499.84 6.67N 2.07W 558632.50 5945969.95 n70 15 6.00 342.77 599.45 14.99N 4.65W 558629.85 5945978.25 n70 15 8.00 342.77 698.70 26.63N 8.26W 558626.15 5945989.86 n70 15 10.00 342.77 797.47 41.57N 12.89W 558621.39 5946004.76 n70 15 13.00 342.77 895.45 60.61N 18.80W 558615.33 5946023.75 n70 15 16.00 342.77 992.25 84.52N 26.21W 558607.72 5946047.60 n70 15 19.00 342.77 1087.61 113.24N 35.12W 558598.59 5946076.24 n70 15 22.00 342.77 1181.27 146.68N 45.49W 558587.94 5946109.59 n70 15 25.00 342.77 1272.96 184.76N 57.30W 558575.82 5946147.57 n70 15 28.00 342.77 1362.45 227.38N 70.52W 558562.26 5946190.07 n70 15 31.00 342.77 1449.47 274.40N 85.11W 558547.30 5946236.97 n70 15 33.29 342.77 1514.00 313.13N 97.12W 558534.97 5946275.60 n70 15 34.00 342.77 1533.80 325.72N 101.02W 558530.97 5946288.15 n70 15 37.00 342.77 1615.20 381.17N 118.22W 558513.32 5946343.46 n70 15 40.00 342.77 1693.46 440.62N 136.66W 558494.40 5946402.75 n70 15 43.00 342.77 1768.34 503.90N 156.29W 558474.26 5946465.87 n70 15 46.00 342.77 1839.66 570.84N 177.05W 558452.95 5946532.63 n70 15 49.00 342.77 1907.21 641.25N 198.89W 558430.55 5946602.85 n70 15 52.00 342.77 1970.81 714.94N 221.75W 558407.09 5946676.35 n70 15 54.82 342.77 2026.78 786.95N 244.08W 558384.18 5946748.16 n70 15 54.82 342.77 2145.53 947.83N 293.98W 558332.98 5946908.62 nT0 15 54.82 342.77 2433.63 1338.15N 415.04W 558208.76 5947297.90 n70 15 54.82 342.77 2721.72 1728.46N 536.10W 558084.54 5947687.18 nT0 16 54.82 342.77 2841.00 1890.06N 586.23W 558033.11 5947848.35 nT0 16 54.82 342.77 3009.81 2118.78N 657.17W 557960.32 5948076.46 nT0 16 54.82 342.77 3294.00 2503.80N 776.59W 557837.78 5948460.46 n70 16 54.82 342.77 3297.91 2509.09N 778.23W 557836.10 5948465.74 n70 16 54.82 342.77 3434.00 2693.47N 835.42W 557777.42 5948649.63 n70 16 54.82 342.77 3586.00 2899.41N 899.29W 557711.88 5948855.02 n70 16 54.82 342.77 3739.00 3106.69N 963.58W 557645.91 5949061.76 n70 16 54.82 342.77 3874.10 3289.72N 1020.35W 557587.66 5949244.30 n70 16 54.82 342.77 3939.00 3377.65N 1047.63W 557559.68 5949332.00 nT0 16 54.82 342.77 4162.19 3680.04N 1141.41W 557463.44 5949633.58 n70 16 54.82 342.77 4384.00 3980.55N 1234.62W 557367.80 5949933.30 n70 16 54.82 342.77 4450.28 4070.35N 1262.48W 557339.22 5950022.86 n70 16 54.82 342.77 4738.38 4460.67N 1383.54W 557215.00 5950412.15 n70 16 54.82 342.77 5026.47 4850.98N 1504.60W 557090.79 5950801.43 nT0 16 54.82 342.77 5274.00 5186.34N 1608.62W 556984.06 5951135.89 n70 16 54.82 342.77 5314.57 5241.30N 1625.66W 556966.57 5951190.71 n70 16 54.82 342.77 5524.00 5525.04N 1713.67W 556876.26 5951473.70 n70 16 54.82 342.77 5602.66 5631.61N 1746.73W 556842.35 5951579.99 n70 16 54.82 342.77 5840.00 5953.16N 1846.46W 556740.01 5951900.69 n70 16 54.82 342.77 5890.75 6021.93N 1867.79W 556718.13 5951969.27 n70 16 54.82 342.77 5987.00 6152.32N 1908.23W 556676.63 5952099.32 n70 16 54.82 342.77 6022.00 6199.74N 1922.94W 556661.54 5952146.61 n70 16 GRAPHIC RDINATES 46.70 w149 31 33.52 46.70 w149 31 33.52 46.70 w149 31 33.52 46.70 w149 31 33.52 46.72 w149 31 33.53 46.76 w149 31 33.58 46.85 w149 31 33.65 46.96 w149 31 33.76 47.11 w149 31 33.89 47.30 w149 31 34.06 47.53 w149 31 34.28 47.81 w149 31 34.54 48.14 w149 31 34.84 48.52 w149 31 35.19 48.94 w149 31 35.57 49.40 w149 31 36.00 49.78 w149 31 36.35 49.90 w149 31 36.46 50.45 w149 31 36.96 51.03 w149 31 37.50 51.65 w149 31 38.07 52.31 w149 31 38.68 53.01 w149 31 39.31 53.73 w149 31 39.98 54.44 w149 31 40.63 56.02 w149 31 42.08 59.86 w149 31 45.61 03.70 w149 31 49.14 05.29 w149 31 50.60 07.53 w149 31 52.67 11.32 w149 31 56.15 11.37 w149 31 56.20 13.19 w149 31 57.86 15.21 w149 31 59.73 17.25 w149 32 01.60 19.05 w149 32 03.26 19.91 w149 32 04.05 22.89 w149 32 06.79 25.84 w149 32 09.50 26.73 w149 32 10.32 30.56 w149 32 13.85 34.40 w149 32 17.38 37.70 w149 32 20.41 38.24 w149 32 20.91 41.03 w149 32 23.48 42.08 w149 32 24.44 45.24 w149 32 27.35 45.92 w149 32 27.97 47.20 w149 32 29.15 47.66 w149 32 29.58 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Bottom hole distance is 6892.54 on azimuth 342.77 degrees from wellhead. Total Dogleg for wellpath is 54.82 degrees. Vertical section is from wellhead on azimuth 342.77 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spherbid Presented by Baker Hughes INTEQ RECEIVED FEB B 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska Measured Inclin Azimuth True Vert Depth Degrees Degrees Depth RECTANGULAR COORDINATES 9361.42 54.82 342.77 6099.00 6304.06N 1955.30W 9491.57 54.82 342.77 6173.99 6405.66N 1986.81W 9491.59 54.82 342.77 6174.00 6405.67N 1986.81W 9500.00 54.82 342.77 6178.85 6412.24N 1988.85W 9536.71 54.82 342.77 6200.00 6440.90N 1997.74W 9557.54 54.82 342.77 6212.00 6457.16N 2002.78W 9574.89 54.82 342.77 6222.00 6470.71N 2006.98W 9588.78 54.82 342.77 6230.00 6481.54N 2010.34W 9718.94 54.82 342.77 6305.00 6583.16N 2041.86W PROPOSAL LISTING Page 2 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 GRID C OORD S GEOGRAPHIC Easting Northing C 0 0 R D I N A T E S 556628.34 5952250.66 n70 16 48.69 w149 32 30.53 556596.00 5952351.99 nT0 16 49.69 w149 32 31.45 556596.00 5952352.00 n70 16 49.69 w149 32 31.45 556593.91 5952358.55 n70 16 49.75 w149 32 31.51 556584.79 5952387.13 n70 16 50.04 w149 32 31.77 556579.62 5952403.35 n70 16 50.20 w149 32 31.91 556575.30 5952416.86 nT0 16 50.33 w149 32 32.04 556571.85 5952427.67 n70 16 50.44 w149 32 32.13 556539.52 5952529.01 n70 16 51.43 w149 32 33.05 Ail data in feet unless otherwise stated. Calculation uses minimum curvature method. Coordinates from slot 99 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Bottom hole distance is 6892.54 on azimuth 342.77 degrees from wellhead. Total Dogleg for wellpath is 54.82 degrees. Vertical section is from wellhead on azimuth 342.77 degrees. Grid is alaska - Zone 4. Grid coordinates in FEET and computed using the Clarke - 1866 spheroid Presented by Baker Hughes INTEQ RECEIVED FEB g 1 2001 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Comments in wellpath MD TVD Rectangular Coords. Comment 300.00 300 00 0.00N 0.00E KO? 800.00 797 47 41.57N 12.89W Beg 3/100 Bld 1576 2293 3707 4493 4736 5265 5612 6384 7929 8363 8911 9167 9227 9361 9491 9491 9536 9557 9574 9588 9718 .21 1514 .90 2026 .02 2841 .22 3294 19 3434 53 3739 64 3939 96 4384 60 5274 48 5524 92 5840 04 5987 78 6022 42 6099 57 6173 59 6174 71 6200 54 6212 89 6222 78 6230 94 6305 00 313.13N 97.12W Permafrost 78 786.95N 244.08W EOC 00 1890.06N 586.23W Top Ugnu 00 2503.80N 776.59W Base Ugnu 00 2693.47N 835.42W Top West Sak 00 3106.69N 963.58W Base West Sak 00 3377.65N 1047.63W 9 5/8" Casing Pt 00 3980.55N 1234.62W C80 00 5186.34N 1608.62W C50 00 5525.04N 1713.67W C40 00 5953.16N 1846.46W C30 00 6152.32N 1908.23W C20 00 6199.74N 1922.94W Base HRZ/7" Casing Pt 00 6304.06N 1955.30W K-1 99 6405.66N 1986.81W Target-Top C4/KupD 00 6405.67N 1986.81W 1J-09 C4 Rvsd 26-Jan-01 00 6440.90N 1997.74W Top C3 00 6457.16N 2002.78W Top C2 00 6470.71N 2006.98W Top Cl 00 6481.54N 2010.34W Top B Shale 00 6583.16N 2041.86W TD - Casing Pt. Casing positions in string 'A' ============================== Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 9718.94 6305.00 6583.16N 2041.86W 3-1/2" tubing 0.00 0.00 0.00N 0.00E 9227.78 6022.00 6199.74N 1922.94W 7" Casing 0.00 0.00 0.00N 0.00E 5612.64 3939.00 3377.65N 1047.63W 9 5/8" Casing Targets associated with this wellpath ===================================== Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1J-09 C4 Rvsd 26-Jan 556596.000,5952352.000,0.0000 6174.00 6405.67N 1986.81W 20-Dec-2000 RECEIVED FEB g 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot) 9 slot $9 Kuparuk River Unit North Slope, Alaska PROPOSAL LISTING by Baker Hughes INTEQ Your ref : 1J-09 VersionS2 Our ref : prop4238 License : Date printed : 13-Feb-2001 Date created : 26-0ct-2000 Last revised : 13-Feb-2001 Field is centred on n70 16 18.576,w150 5 56.536 Structure is centred on 561226.769,5943831.650,999.00000,N Slot location is n70 15 46.699,w149 31 33.517 Slot Grid coordinates are N 5945963.299, E 558634.622 Slot local coordinates are 2152.86 N 2574.98 W Projection type: alaska - Zone 4, Spheroid: Clarke - 1866 Reference North is True North RECEIVED FEB ZOO1' Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 0 0 R D I N A T E S PROPOSAL LISTING Page 1 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Dogleg Vert Deg/lOOft Sect 0.00 0.00 0.00 0.00 0.00 N 0.00 E 0.00 0.00 100.00 0.00 342.77 100.00 0.00 N 0.00 E 0.00 0.00 200.00 0.00 342.77 200.00 0.00 N 0.00 E 0.00 0.00 300.00 0.00 342.77 300.00 0.00 N 0.00 E 0.00 0.00 KOP 400.00 2.00 342.77 399.98 1.67 N 0.52 W 2.00 1.75 500.00 4.00 342.77 499.84 6.67 N 2.07 W 2.00 6.98 600.00 6.00 342.77 599.45 14.99 N 4.65 W 2.00 15.69 700.00 8.00 342.77 698.70 26.63 N 8.26 W 2.00 27.88 800.00 10.00 342.77 797.47 41.57 N 12.89 W 2.00 43.52 Beg 3/100 Bld 900.00 13.00 342.77 895.45 60.61 N 18.80 W 3.00 63.46 1000.00 16.00 342.77 992.25 84.52 N 26.21 W 3.00 88.49 1100.00 19.00 342.77 1087.61 113.24 N 35.12 W 3.00 118.56 1200.00 22.00 342.77 1181.27 146.68 N 45.49 W 3.00 153.58 1300.00 25.00 342.77 1272.96 184.76 N 57.30 W 3.00 193.45 1400.00 28.00 342.77 1362.45 227.38 N 70.52 W 3.00 238.06 1500.00 31.00 342.77 1449.47 274.40 N 85.11 W 3.00 287.30 1576.21 33.29 342.77 1514.00 313.13 N 97.12 W 3.00 327.84 Permafrost 1600.00 34.00 342.77 1533.80 325.72 N 101.02 W 3.00 341.02 1700.00 37.00 342.77 1615.20 381.17 N 118.22 W 3.00 399.09 1800.00 40.00 342.77 1693.46 440.62 N 136.66 W 3.00 461.33 1900.00 43.00 342.77 1768.34 503.90 N 156.29 W 3.00 527.58 2000.00 46.00 342.77 1839.66 570.84 N 177.05 W 3.00 597.67 2100.00 49.00 342.77 1907.21 641.25 N 198.89 W 3.00 671.39 2200.00 52.00 342.77 1970.81 714.94 N 221.75 W 3.00 748.54 2293.90 54.82 342.77 2026.78 786.95 N 244.08 W 3.00 823.93 EOC 2500.00 54.82 342.77 2145.53 947.83 N 293.98 W 0.00 992.37 3000.00 54.82 342.77 2433.63 1338.15 N 415.04 W 0.00 1401.03 3500.00 54.82 342.77 2721.72 1728.46 N 536.10 W 0.00 1809.69 3707.02 54.82 342.77 2841.00 1890.06 N 586.23 W 0.00 1978.89 Top Ugnu 4000.00 54.82 342.77 3009.81 2118.78 N 657.17 W 0.00 2218.35 4493.22 54.82 342.77 3294.00 2503.80 N 776.59 W 0.00 2621.47 Base Ugnu 4500.00 54.82 342.77 3297.91 2509.09 N 778.23 W 0.00 2627.01 4736.19 54.82 342.77 3434.00 2693.47 N 835.42 W 0.00 2820.05 Top West Sak 5000.00 54.82 342.77 3586.00 2899.41 N 899.29 W 0.00 3035.67 5265.53 54.82 342.77 3739.00 3106.69 N 963.58 W 0.00 3252.69 Base West Sak 5500.00 54.82 342.77 3874.10 3289.72 N 1020.35 W 0.00 3444.33 5612.64 54.82 342.77 3939.00 3377.65 N 1047.63 W 0.00 3536.39 9 5/8" Casing Pt 6000.00 54.82 342.77 4162.19 3680.04 N 1141.41 W 0.00 3852.98 6384.96 54.82 342.77 4384.00 3980.55 N 1234.62 W 0.00 4167.62 C80 6500.00 54.82 342.77 4450.28 4070.35 N 1262.48 W 0.00 4261.64 7000.00 54.82 342.77 4738.38 4460.67 N 1383.54 W 0.00 4670.30 7500.00 54.82 342.77 5026.47 4850.98 N 1504.60 W 0.00 5078.96 7929.60 54.82 342.77 5274.00 5186.34 N 1608.62 W 0.00 5430.08 C50 8000.00 54.82 342.77 5314.57 5241.30 N 1625.66 W 0.00 5487.62 8363.48 54.82 342.77 5524.00 5525.04 N 1713.67 W 0.00 5784.70 C40 8500.00 54.82 342.77 5602.66 5631.61 N 1746.73 W 0.00 5896.28 8911.92 54.82 342.77 5840.00 5953.16 N 1846.46 W 0.00 6232.94 C30 9000.00 54.82 342.77 5890.75 6021.93 N 1867.79 W 0.00 6304.94 9167.04 54.82 342.77 5987.00 6152.32 N 1908.23 W 0.00 6441.46 C20 9227.78 54.82 342.77 6022.00 6199.74 N 1922.94 W 0.00 6491.11 Base HRZ/7" Casing Pt Ail data is in feet unless otherwise stated. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Bottom hole distance is 6892.54 on azimuth 342.77 degrees from wellhead. Total Dogleg for wellpath is 54.82 degrees. Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 1 ZO0 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska Measured Inclin. Azimuth True Vert R E C T A N G U L A R Depth Degrees Degrees Depth C 00 R D I N A T E S PROPOSAL LISTING Page 2 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Dogleg Vert Deg/100ft Sect 9361.42 54.82 342.77 6099.00 6304.06 N 1955.30 W 0.00 6600.33 K-1 9491.57 54.82 342.77 6173.99 6405.66 N 1986.81 W 0.00 6706.71 Target-Top C4/KupD 9491.59 54.82 342.77 6174.00 6405.67 N 1986.81 W 0.00 6706.72 1J-09 C4 Rvsd 26-Jan-01 9500.00 54.82 342.77 6178.85 6412.24 N 1988.85 W 0.00 6713.60 9536.71 54.82 342.77 6200.00 6440.90 N 1997.74 W 0.00 6743.60 Top C3 9557.54 54.82 342.77 6212.00 6457.16 N 2002.78 W 0.00 6760.62 Top C2 9574.89 54.82 342.77 6222.00 6470.71 N 2006.98 W 0.00 6774.81 ToD C1 9588.78 54.82 342.77 6230.00 6481.54 N 2010.34 W 0.00 6786.16 Top B Shale 9718.94 54.82 342.77 6305.00 6583.16 N 2041.86 W 0.00 6892.54 TD - Casing Pt. Ail data is in feet unless otherwise stated. Coordinates from slot #9 and TVD from RKB (Nabors 16E) (114.00 Ft above mean sea level). Bottom hole distance is 6892.54 on azimuth 342.77 degrees from wellhead. Total Dogleg for wellpath is 54.82 degrees. Vertical section is from wellhead on azimuth 342.77 degrees. Calculation uses the minimum curvature method. Presented by Baker Hughes INTEQ RECEIVED FEB 1 ZOO1 Alaska Oil & Gas Cons. Commission Anchorage Phillips Alaska, Inc. Pad 1J (WS Pilot),9 Kuparuk River Unit,North Slope, Alaska PROPOSAL LISTING Page 3 Your ref : 1J-09 Version#2 Last revised : 13-Feb-2001 Comments in wellpath .................... MD TVD Rectangular Coords. Comment 300.00 800.00 1576.21 2293.90 3707.02 4493.22 4736.19 5265.53 5612.64 6384.96 7929.60 8363.48 8911.92 9167.04 9227.78 9361.42 9491.57 9491.59 9536.71 9557.54 9574.89 9588.78 9718.94 300 797 1514 2026 2841 3294 3434 3739 3939 00 4384 00 5274 00 5524 00 5840 00 5987 00 6022 00 6099.00 6173.99 6174.00 6200.00 6212.00 6222.00 6230.00 6305.00 00 47 00 78 00 00 00 00 0. 41. 313. 786. 1890. 2503. 2693. 3106. 3377. 3980 5186 5525 5953 6152 6199 6304 6405 6405 6440 6457 6470 6481 6583 00 N 0 57 N 12 13 N 97 95 N 244 06 N 586 80 N 776 47 N 835 69 N 963 65 N 1047 55 N 1234 34 N 1608 04 N 1713 16 N 1846 32 N 1908 74 N 1922 06 N 1955 66 N 1986 67 N 1986 90 N 1997 16 N 2002 71 N 2006 54 N 2010 16 N 2041 00 E KOP 89 W Beg 3/100 Bld 12 W Permafrost 08 W EOC 23 W Top Ugnu 59 W Base Ugnu 42 W Top West Sak .58 W Base West Sak .63 W 9 5/8" Casing Pt .62 W C80 .62 W C50 .67 W C40 .46 W C30 .23 W C20 .94 W Base HRZ/7" Casing Pt .30 W K-1 .81 W Target-Top C4/KupD .81 W 1J-09 C4 Rvsd 26-Jan-01 .74 W Top C3 .78 W Top C2 .98 W Top C1 .34 W Top B Shale .86 W TD - Casing Pt. Casing positions in string 'A' Top MD Top TVD Rectangular Coords. Bot MD Bot TVD Rectangular Coords. Casing 0.00 0.00 0.00N 0.00E 9718.94 6305.00 6583.16N 2041.86W 3-1/2" tubing 0.00 0.00 0.00N 0.00E 9227.78 6022.00 6199.74N 1922.94W 7" Casing 0.00 0.00 0.00N 0.00E 5612.64 3939.00 3377.65N 1047.63W 9 5/8" Casing Targets associated with this wellpath Target name Geographic Location T.V.D. Rectangular Coordinates Revised 1J-09 C4 Rvsd 26-Jan 556596.000,5952352.000,0.0000 6174.00 6405.67N 1986.81W 20-Dec-2000 RECEIVED FEB Z 1, 7_001 Alaska Oi~ & Gas Cons. Commissior~ Anchorage PHILL ' S Alaska, Inc. Subsidiary of PHILLIPS PETROLEUM COMPANY Phillips Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510 February 20, 2001 Alaska Oil and Gas Conservation Commission 333 West 7'h Avenue, Suite 100 Anchorage, AK 99501 (907) 279-1433 Re: Application for Permit to Drill: KRU 1J-09 Surface Location: Target Location: Bottom Hole Location: 2152' FSL, 2574' FEL, Sec. 35, T11 N, R10E 2003' FNL, 724' FWL, Sec. 26, T11 N, R10E 1825' FNL, 669' FWL, Sec. 26, T11 N, R10E Dear Sirs: Phillips Alaska, Inc. hereby applies for a Permit to Drill an onshore development well KRU 1J-09. The well will be drilled and completed using Nabors 16E. Please utilize documents on file for this rig. Subject to AOGCC approval, fluids and cuttings generated from drilling the well will be pumped down an approved and existing annulus on Drillsite 1J, or hauled to an approved Prudhoe or GKA Class II disposal well. Also note that Phillips Alaska, Inc. does not anticipate the presence of H2S in the formations to be encountered in this well. However, there will be H2S and combustible gas monitoring equipment functioning on the rig as is the standard operating procedure in the Kuparuk River Unit drilling operation. The following people are the designated contacts for reporting responsibilities to the Commission: A) Completion Report Sharon AIIsup-Drake, Drilling Technologist (20 AAC 25.070) 263-4612 B) Geologic Data and Logs (20 AAC 25.071) Stacy Waggoner, Geologist 265-1391 If you have any questions or require further information, please contact Todd Mushovic at (907) 265-6974 or James Trantham at (907) 265-6434. Sincerely, , Todd ~ushovic Operations Drilling Engineer REcE VEE) FEB 1 001 Alaska 0i[ & Gas Cons. commission Anchorage O t$1N L American Express ® Cash Advance Draft 118 PAY TO THE · , ORDER Or ~ ~ . ~ ~. $ [/O~_.3, ~.;>(Q '~ ~'~: /~~'/~~ '~-~. ~ "'~/~:~ ~ DOLLARS Issued by Integrated Payment System, Inc. Englewood, Colorado Payable at Norwest B~nk of Grand Junction - Downtown, Grand Junction, Colorado PERIOD ENDING ,: ;,O 8 ~,OO [,DDi: 3 5 NOT VALID FOR AMOUNT OVER $ 1000 ,,,D ~ ? 5DDD 5 ~=,'D ~, wELL PERMIT CHECKLIST COMPANY :/~.,~/~/~,~---~ WELL NAME./'-,/- ~ 'PROGRAM: exp FIELD & POOL ~-~'-~L"'~/x/~__,,~_ INIT CLASSv ~~/ /2'~/~. GEOL AREA ADMINISTRATION 1. ~NN . 3. 4. 5. 6. 7. 8. 9. 10. 11. DATE 12. ,;Z ',Z~.~/ 13. Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from drilling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available, in ddlling unit ............ if deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can. be issued without administrative approval ...... Can permit be approved before 15-day wait ........... ENGINEERING 14. Conductor string provided ................... 15. Surface casing protects all known USDWs ........... 16. CMT vol adequate to circulate on conductor & surf csg ..... 17. CMT vol adequate to tie-in long string to surf csg ........ 18. CMT will cover all known productive horizons .......... 19. Casing designs adequate for C, T, B & permafrost ....... 20. Adequate tankage or reserve pit ................. 21. If a re-drill, has a 10-403 for abandonment been approved... -'N dev "/'redrll . serv UNIT# wellbore sag ann. disposal para req /"'~/.//~::~ ~ ON/OFF SHORE 22. AdequateDrilling wellbOreprogramSeparation propoSedequip ............. adequate ..... 23. If diverter required, does it meet regulations .......... N ,~ ,,. '. 24..fluid schematic & list N 25. BOPEs, do they meet regulation ................ ~NN '" " 26. DOPE press rating appropriate; test to ~{:~(~(~ I ~;(~ psig. ~:3~%,~ -~ Ct ~'("k ~"~(~t~ ~ ~"~." ' . 27. Choke manifold complies w/APl RP-53 (May 84) ........ ~N ' 28. Work will occur without operation shutdOwn..., ........ N . ' . 29. Is presence of H2S gas probable ................. Y GEOLOGY 30. Permit can be issued wlo hydrogen sulfide measures ...... Y.~"~ .... 31. Data presented on potential overpressure zones~. ...... (~N~. [-"/_.,'/t',,,~ 32. Seismic analysis of shallow gas zones ............. ~ ,, ~ .-~-.- ,~-~~,-c~/~ ~ 'r''5''~"~" ~ ~ ~'./(/75-- 7'~'~ 7 '~'rZ~.SX*;~' ,~"~'//~ ~,P~ DATE 33. Seabed condition survey (if off-shore) ...... , ...... ~'~Y N.5~. ~'. ~ ~ ~ 34. Contact name/phone for weekly progress reports [explora. t~fy'only] Y N ~ ~ /. '_"7..~.~.~ ,/~ ,~.~,.,z,~¥,/~_ ~.~c,.~.~ >',~/~.: ~-.~,~ :; -:~Z/r-~//~.-( ~;,, ~- ANNULAR DISPOSAL35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zonei ....... Y APPR DATE (B) will not contaminate freshwater; or cause drilling waste . . . Y N to surface; v~r~ ~ ~j ol (C) will not impair mechanical integrity of the well used for disposal; Y N (D) will not damage producing formation or impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N GEOLQGY: ENGINEERING: UIC/Annular COMMISSION: WM~,~N~ Comments/Instructions: Z ---I -I- 3> c:\msoffice\wordian\diana\checklist (rev. 11/01//00) Well History File APPENDIX Information of detailed nature that is not partiCularly germane to the Well Permitting Process but is part of the history file. ,. To improve the readability of the Well History file and to simplify finding informatiOn, information, of this. · nature is accumulated at the end of the file under APPENDIXi .o No'special'effort has been made to chronologically'.. organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Apr 30 12:58:37 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/30 Origin ................... STS Tape Name'. ............... UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kaparuk River Unit MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10082 T. MCGUIRE M. THORTON 1J-09 500292300600 PHILLIPS Alaska, Inc. Sperry Sun 28-APR-01 MWD RUN 2 AK-MM-10082 T. MCGUIRE M. THORTON MWD RUN 3 AK-MM-10082 T. MCGUIRE M. THORTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: MWD RUN 4 AK-MM-10082 P. SMITH G. WHITLOCK MWD RUN 99 AK-MM-10082 35 lin 10E 2107 2419 .00 115.05 GROUND LEVEL: WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING # REMARKS: 79.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 12.250 16.000 120.0 12.250 16.000 120.0 8.500 9.625 5639.0 6.125 7.000 9197.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND BIMODAL ACOUSTIC TOOL (BAT). 3. MWD RUNS 2 AND 4 ARE DIRECTIONAL WITH DGR, EWR4, BAT, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITH- DENSITY (SLD). 4. VERTICAL RESISTIVITY INVERSION (VRI) COMPUTED DATA IS PRESENTED AS AN ENHANCED DEEP RESISTIVITY CURVE (RDVR) WITH MERGED DATA, AND AS 4 ENHANCED AND FOUR FORWARD MODELED CURVES IN THE FINAL RAW FILE (RUN 99). 5. MWD DATA IS PDC PER THE PHONE CONVERSATION BETWEEN J. HARRISON OF PHILLIPS ALASKA, INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 04/10/01. 6. MWD RUNS 1-4 REPRESENT WELL 1J-09 WITH API%: 50-029-23006-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9850~MD, 6350~TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DTCP = COMPRESSIONAL WAVE TRAVEL TIME -POST PROCESSED. VEXP = INVERSION-DERIVED EXTRA SHALOW PHASE RESISTIVITY (ENHANCED). VESP = INVERSION-DERIVED SHALOW PHASE RESISTIVITY (ENHANCED). VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED). VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25"-6.125" MUD WEIGHT: 9.6 - 11.9 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY : 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR DT RPD RPM RPS RPX FET ROP NPHI FCNT NCNT DRHO RHOB .5000 START DEPTH 67.0 81 5 110 0 110 0 110 0 110 0 119 5 123 0 1190 5 1190 5 1190 5 1200 5 1200 5 STOP DEPTH 9766.5 9800.5 9774.5 9774.5 9774.5 9774 5 977 6 5 9849 0 9719 0 9719 0 9719 0 9734 0 9734 0 PEF 1200.5 9734.0 RDVR 4320.0 5570.0 $ # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: BIT RUN NO MERGE TOP MERGE BASE 1 67.0 1305.0 2 1305.0 5653.0 3 5653.0 9205.0 4 9205.0 9849.0 99 4320.0 5570.0 MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 NPHI MWD PU-S 4 1 68 12 4 FCNT MWD CNTS 4 1 68 16 5 NCNT MWD CNTS 4 1 68 20 6 RHOB MWD G/CM 4 1 68 24 7 DRHO MWD G/CM 4 1 68 28 8 PEF MWD BARN 4 1 68 32 9 DT MWD US/F 4 1 68 36 10 RVDR MWD OHMM 4 1 68 40 11 RPX MWD OHMM 4 1 68 44 12 RPS MWD OHMM 4 1 68 48 13 RPM MWD OHMM 4 1 68 52 14 RPD MWD OHMM 4 1 68 56 15 FET MWD HOUR 4 1 68 60 16 Name Service Unit Min Max Mean Nsam DEPT FT 67 9849 4958 19565 ROP MWD FT/H 0.18 2583.06 154.097 19453 GR MWD API 15.91 445.42 102.302 19400 NPHI MWD PU-S 7.12 64.35 39.5975 9745 FCNT MWD CNTS 116 878 575.69 9745 NCNT MWD CNTS 2429 35847 4455.04 9745 RHOB MWD G/CM 1.198 3.103 2.17309 9746 DRHO MWD G/CM -0.249 0.596 0.0528165 9746 First Reading 67 123 67 1190.5 1190.5 1190.5 1200.5 1200.5 Last Reading 9849 9849 9766.5 9719 9719 9719 9734 9734 PEF MWD BARN 0.85 18.78 DT MWD US/F 50 168 RVDR MWD OHMM 1.193 148.645 RPX MWD OHMM 0.34 2000 · RPS MWD OHMM 0.1 1228.49 RPM MWD OHMM 0.41 2000 RPD MWD OHMM 0.16 2000 FET MWD HOUR 0.26 118.94 2.81167 9774 117.06 19430 12.3867 2501 16.0514 19330 21.0434 19330 44.0273 19330 68.1096 19330 2.40234 19315 1200.5 81.5 4320 110 110 110 110 119.5 9734 9800.5 5570 9774.5 9774.5 9774.5 9774.5 9776.5 First Reading For Entire File .......... 67 Last Reading For Entire File ........... 9849 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR DT RPX RPS RPD RPM FET ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 67.0 81 5 110 0 110 0 110 0 110 0 119 5 123 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT): STOP DEPTH 1248.5 1262 5 1241 0 1241 0 1241 0 1241 0 1241 0 1305 5 09-MAR-01 Insite 65.44 Memory 1307.0 lj09.txt Sperry-Sun Drillin9 Services LIS Scan Utility SRevision: 3 $ LisLib SRevision: 4 $ Mon Apr 30 12:58:37 2001 Reel Header Service name ............. LISTPE Date ..................... 01/04/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Tape Header Service name ............. LISTPE Date ..................... 01/04/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Kaparuk River Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 AK-MM-10082 T. MCGUIRE M. THORTON 1J-09 500292300600 PHILLIPS Alaska, Inc. Sperry Sun 28-APR-01 MWD RUN 2 AK-MM-10082 T. MCGUIRE M. THORTON MWD RUN 3 AK-MM-10082 T. MCGUIRE M. THORTON JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: MWD RUN 4 AK-MM-10082 P. SMITH G. WHITLOCK MWD RUN 99 AK-MM-10082 35 lin 10E Page 1 FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD ljO9.txt 2107 2419 .00 115.05 79.70 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 12.250 16.000 120.0 2ND STRING 12.250 16.000 120.0 3RD STRING 8.500 9.625 5639.0 PRODUCTION STRING 6.125 7.000 9197.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. MWD RUNS 1 AND 3 ARE DIRECTIONAL WITH DUAL GAMMA RAY (DSm) UTILIZING GEIGER-MUELLER TUBE DETECTORS, ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4), AND BIMODAL ACOUSTIC TOOL (BAT). 3. MWD RUNS 2 AND 4 ARE DIRECTIONAL WITH DGR, EWR4, BAT, COMPENSATED NEUTRON POROSITY (CNP), AND STABILIZED LITH- DENSITY (SLD). 4. VERTICAL RESISTIVITY INVERSION (VRI) COMPUTED DATA IS PRESENTED AS AN ENHANCED DEEP RESISTIVITY CURVE (RDVR) WITH MERGED DATA, AND AS 4 ENHANCED AND FOUR FORWARD MODELED CURVES IN THE FINAL RAW FILE (RUN 99). 5. MWD DATA IS PDC PER THE PHONE CONVERSATION BETWEEN J. HARRISON OF PHILLIPS ALASKA, INC. AND R. KALISH OF SPERRY-SUN DRILLING SERVICES ON 04/10/01. 6. MWD RUNS 1-4 REPRESENT WELL 1J-09 WITH API#: 50-029-23006-00. THIS WELL REACHED A TOTAL DEPTH (TD) OF 9850'MD, 6350'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY Page 2 lj09.txt (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. SPSF = SMOOTHED COMPENSATED NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). SNFA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SNNA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SS MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBU2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SCO2 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR DETECTOR ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). DTCP = COMPRESSIONAL WAVE TRAVEL TIME -POST PROCESSED. VEXP = INVERSION-DERIVED EXTRA SHALOW PHASE RESISTIVITY (ENHANCED). VESP = INVERSION-DERIVED SHALOW PHASE RESISTIVITY (ENHANCED). VEMP = INVERSION-DERIVED MEDIUM PHASE RESISTIVITY (ENHANCED). VEDP = INVERSION-DERIVED DEEP PHASE RESISTIVITY (ENHANCED). MEXP = FORWARD-MODELED EXTRA SHALLOW PHASE RESISTIVITY. MESP = FORWARD-MODELED SHALLOW PHASE RESISTIVITY. MEMP = FORWARD-MODELED MEDIUM PHASE RESISTIVITY. MEDP = FORWARD-MODELED DEEP PHASE RESISTIVITY. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 12.25"-6.125" MUD WEIGHT: 9.6 - 11.9 PPG MUD SALINITY: 500 PPM CHLORIDES FORMATION WATER SALINITY: 13000 PPM CHLORIDES FLUID DENSITY : 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.000 Comment Record FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. Page 3 DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR DT RPD RPM RPS RPX FET ROP NPHI FCNT NCNT DRHO RHOB PEF RDVR $ .5000 START DEPTH 67 0 81 5 110 0 110 0 110 0 110 0 119 5 123 0 1190 5 1190 5 1190 5 1200 5 1200 5 1200 5 4320 0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD $ REMARKS: lj09.txt STOP DEPTH 9766.5 9800.5 9774.5 9774 5 9774 5 9774 5 9776 5 9849 0 9719 0 9719 0 9719 0 9734 0 9734 0 9734 0 5570 0 EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 67.0 1305.0 2 1305.0 5653.0 3 5653.0 9205.0 4 9205.0 9849.0 99 4320.0 5570.0 Page 4 DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 NPHI MWD PU-S 4 1 68 12 4 FCNT MWD CNTS 4 1 68 16 5 NCNT MWD CNTS 4 1 68 20 6 RHOB MWD G/CM 4 1 68 24 7 Name Service Order Units Size Nsam Rep Code Offset Channel MERGED MAIN PASS. $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 DRHO MWD G/CM 4 1 PEF MWD BARN 4 1 DT MWD US/F 4 1 RVDR MWD OHMM 4 1 RPX MWD OHMM 4 1 RPS MWD OHMM 4 1 RPM MWD OHMM 4 1 RPD MWD OHMM 4 1 FET MWD HOUR 4 1 lj09.txt 68 28 8 68 32 9 68 36 10 68 40 11 68 44 12 68 48 13 68 52 14 68 56 15 68 60 16 Name Service Unit Min Max DEPT FT 67 9849 ROP MWD FT/H 0.18 2583.06 GR MWD API 15.91 445.42 NPHI MWD PU-S 7.12 64.35 FCNT MWD CNTS 116 878 NCNT MWD CNTS 2429 35847 RHOB MWD G/CM 1.198 3.103 DRHO MWD G/CM -0.249 0.596 PEF MWD BARN 0.85 18.78 DT MWD US/F 50 168 RVDR MWD OHMM 1.193 148.645 RPX MWD OHMM 0.34 2000 RPS MWD OHMM 0.1 1228.49 RPM MWD OHMM 0.41 2000 RPD MWD OHMM 0.16 2000 FET MWD HOUR 0.26 118.94 Mean Nsam 4958 19565 154.097 19453 102.302 19400 39.5975 9745 575.69 9745 4455.04 9745 2.17309 9746 0.0528165 9746 2.81167 9774 117.06 19430 12.3867 2501 16.0514 19330 21.0434 19330 44.0273 19330 68.1096 19330 2.40234 19315 First Readin¢ 67 123 67 1190 5 1190 5 1190 5 1200 5 1200 5 1200 5 81 5 4320 110 110 110 110 119.5 Last Reading 9849 9849 9766.5 9719 9719 9719 9734 9734 9734 9800.5 5570 9774.5 9774.5 9774.5 9774.5 9776.5 First Reading For Entire File .......... 67 Last Reading For Entire File ........... 9849 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.002 Physical EOF File Header Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.001 Comment Record Page 5 lj09.txt FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 1 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 67 0 DT 81 5 RPX 110 0 RPS 110 0 RPD 110 0 RPM 110 0 FET 119 5 ROP 123 0 $ # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BAT BIMODAL ACOUST. TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: STOP DEPTH 1248 5 1262 5 1241 0 1241 0 1241 0 1241 0 1241 0 1305 5 09-MAR-01 Insite 65.44 Memory 1307.0 .9 19.5 TOOL NUMBER PB01899HRG8 PB01899HRG8 PB01899HRG8 12.250 120.0 Water Based 9.60 304.0 9.0 300 9.4 2.300 2.269 2.000 3.000 67.0 68.0 67.0 67.0 Page 6 Dat Name DEPT ROP GR RPX RPS RPH RPD FET DT MATRIX DENSITY: HOLE CORRECTION (IN): lj09.txt TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ a Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Service Order Units Size Nsam Rep FT 4 1 68 MWD010 FT/H 4 1 68 MWD010 API 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 OHMM 4 1 68 MWD010 HOUR 4 1 68 MWD010 US/F 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 Name Service Unit Min Max DEPT FT 67 1305.5 ROP MWD010 FT/H 0.21 2583.06 GR MWD010 API 18.15 134.59 RPX MWD010 OHMM 0.96 2000 RPS MWD010 OHMM 0.89 1228.49 RPM MWD010 OHMM 0.9 2000 RPD MWD010 OHMM 0.85 2000 FET MWD010 HOUR 0.41 8.56 DT MWD010 US/F 58 124 Mean 686.25 116.883 70.8469 54.4497 89.0669 155.381 293.936 0.866016 95.6276 Nsam 2478 2366 2364 2263 2263 2263 2263 2244 2363 First Reading 67 123 67 110 110 110 110 119.5 81.5 Last Reading 1305.5 1305.5 1248.5 1241 1241 1241 1241 1241 1262.5 First Reading For Entire File .......... 67 Last Reading For Entire File ........... 1305.5 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.003 Page 7 ljO9.txt Physical EOF File Header Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH NPHI FCNT NCNT DRHO RHOB PEF RPX RPS RPM FET RPD GR DT ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 1190 5 1190 5 1190 5 1200 5 1200 5 1200 5 1243 0 1243 0 1243 0 1243 0 1243 0 1250 5 1269 0 1307 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON Page 8 STOP DEPTH 5530 0 5530 0 5530 0 5539 5 5539 5 5539 5 5584 0 5584 0 5584 0 5584 0 5584 0 5591 5 5606 5 5653 0 12-MAR-01 Insite 65.44 Memory 5649.0 21.5 57.8 TOOL NUMBER PB01899HRG8 PB01899HRG8 PB01899HRG8 SLD BAT $ lj09.txt STABILIZED LITHO DEN BIMODAL ACOUST. TOOL BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 PB01899HRG8 PB01899HRG8 12.250 120.0 Water Based 9.60 128.0 9.0 700 4.2 2.500 1.703 2.200 3.000 65.0 98.6 65.0 65.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 NPHI MWD020 PU-S 4 1 68 32 9 -FCNT MWD020 CNTS 4 1 68 36 10 NCNT MWD020 CNTS 4 1 68 40 11 RHOB MWD020 G/CM 4 1 68 44 12 DRHO MWD020 G/CM 4 1 68 48 13 PEF MWD020 BARN 4 1 68 52 14 Page 9 DT MWD020 US/F 4 ljO9.txt 1 68 56 15 Name Service Unit Min Max DEPT FT 1190.5 5653 ROP MWD020 FT/H 0.37 1978.88 GR MWD020 API 15.91 142.24 RPX MWD020 OHMM 0.86 1868.94 RPS MWD020 OHMM 0.1 254.87 RPM MWD020 OHMM 0.41 1803.06 RPD MWD020 OHMM 0.16 2000 FET MWD020 HOUR 0.33 13.54 NPHI MWD020 PU-S 7.12 64.35 FCNT MWD020 CNTS 480 878 NCNT MWD020 CNTS 2429 3041 RHOB MWD020 G/CM 1.198 3.103 DRHO MWD020 G/CM -0.225 0.596 PEF MWD020 BARN 0.85 8.12 DT MWD020 US/F 79 168 Mean 3421.75 150.223 77. 9895 17.42 19.1365 25.0072 32.8883 1.09293 39.4265 615.35 2465.56 2.13994 0.0515139 2.17567 136.514 Nsam 8926 8692 8683 8683 8683 8683 8683 8683 8680 8680 8680 8679 8679 8679 8676 First Reading 1190.5 1307.5 1250.5 1243 1243 1243 1243 1243 1190 5 1190 5 1190 5 1200 5 1200 5 1200 5 1269 Last Reading 5653 5653 5591.5 5584 5584 5584 5584 5584 5530 5530 5530 5539.5 5539.5 5539.5 5606.5 First Reading For Entire File .......... 1190.5 Last Reading For Entire File ........... 5653 File Trailer Service name ............. STSLIB.003 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.004 Physical EOF File Header Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH Page 10 FET R?D RPM RPS RPX GR DT ROP $ # LOG HEADER DATA DATE LOGGED: SOFTWARE 5584 5 5584 5 5584 5 5584 5 5584 5 5592 0 5607 5 5653 5 lj09.txt 9132 5 9132 5 9132 5 9132 5 9132 5 9140 0 9155 5 9204 5 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 BAT BIMODAL ACOUST. TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM): FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Page 11 19-MAR-01 Insite 65.44 Memory 9204.5 53.3 57.6 TOOL NUMBER PB01892HWRG6 PB01892HWRG6 PB01892HWRG6 8.500 5639.0 Water Based 9.80 43.0 8.5 550 4.0 1.750 1.000 1.600 2.000 65.0 118.8 65.0 65.0 lj09.txt Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .liN Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 ROP MWD030 FT/H 4 1 68 GR MWD030 API 4 1 68 RPX MWD030 OHMM 4 1 68 RPS MWD030 OHMM 4 1 68 RPM MWD030 OHMM 4 1 68 RPD MWD030 OHMM 4 1 68 FET MWD030 HOUR 4 1 68 DT MWD030 US/F 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 32 9 Name Service Unit DEPT FT ROP MWD030 FT/H GR MWD030 API RPX MWD030 OHMM RPS MWD030 OHMM RPM MWD030 OHMM RPD MWD030 OHMM FET MWD030 HOUR DT MWD030 US/F Min 5584.5 0.38 43 88 0 34 0 39 0 76 0 74 0 26 50 Max 9204.5 901.65 445.42 34.66 192.43 2000 2000 118.94 130 Mean 7394.5 186.212 136.342 3.42419 3.63676 6.83312 26.8911 3.15908 104.291 Nsam 7241 7103 7097 7097 7097 7097 7097 7097 7088 First Reading 5584.5 5653.5 5592 5584 5 5584 5 5584 5 5584 5 5584 5 5607 5 Last Reading 9204.5 9204.5 9140 9132 5 9132 5 9132 5 9132 5 9132 5 9155 5 First Reading For Entire File .......... 5584.5 Last Reading For Entire File ........... 9204.5 File Trailer Service name ............. STSLIB.004 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.005 Physical EOF File Header Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Page 12 ljO9.txt Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 # FILE SUMMARY VENDOR TOOL CODE START DEPTH NCNT FCNT FET RPX RPS RPM RPD GR DT PEF NPHI RHOB DRHO ROP $ LOG HEADER DATA DATE LOGGED: SOFTWARE 9090.0 9090 0 9131 0 9131 0 9131 0 9131 0 9131 0 9140 5 9156 0 9187 0 9187 0 9201 0 9201 0 9205 0 SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 CTN COMP THERMAL NEUTRON SLD STABILIZED LITHO DEN BAT BIMODAL ACOUST. TOOL $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS STOP DEPTH 9719 0 9719 0 9774 5 9774 5 9774 5 9774 5 9774 5 9766 5 9800 5 9734 0 9719 0 9734 0 9734 0 9849 0 Page 13 23-MAR-01 Insite 0.43 Memory 9850.0 57.5 59.3 TOOL NUMBER 1752GR4/1826NL4 1752GR4/1826NL4 1752GR4/1826NL4 1752GR4/1826NL4 1752GR4/1826NL4 6.125 9197.0 ljO9.txt MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY S): MUD PH: MUD CHLORIDES PPM) : FLUID LOSS (C3 : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 LSND 11.90 51.0 8.5 500 4.0 2.900 1.411 1.900 3.000 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 NPHI MWD040 PU-S 4 1 68 32 9 FCNT MWD040 CNTS 4 1 68 36 10 NCNT MWD040 CNTS 4 1 68 40 11 RHOB MWD040 G/CM 4 1 68 44 12 DRHO MWD040 G/CM 4 1 68 48 13 PEF MWD040 BARN 4 1 68 52 14 DT MWD040 US/F 4 1 68 56 15 65.0 140.8 65.0 65.0 Name Service Unit Min Max Mean Nsam DEPT FT 9090 9849 9469.5 1519 ROP MWD040 FT/H 0.18 420.13 71.7946 1289 GR MWD040 API 43.75 370.22 137.407 1253 Page 14 First Reading 9090 9205 9140.5 Last Reading 9849 9849 9766.5 lj09.txt RPX MWD040 OHMM 0.38 822.44 RPS MWD040 OHMM 0.43 880.8 RPM MWD040 OHMM 0.75 2000 RPD MWD040 OHMM 0.6 2000 FET MWD040 HOUR 0.98 73.73 NPHI MWD040 PU-S 20.65 63.54 FCNT MWD040 CNTS 114 803 NCNT MWD040 CNTS 14168 35847 RHOB MWD040 G/CM 2.181 3.09 DRHO MWD040 G/CM -0.249 0.415 PEF MWD040 BARN 4.43 18.78 DT MWD040 US/F 51 132 8.7519 9.96089 180.982 134.929 9.72638 40.9917 237.879 20019.2 2.44269 0.0634124 7.85263 95.4318 1288 1288 1288 1288 1288 1065 1259 1259 1067 1067 1095 1290 9131 9131 9131 9131 9131 9187 9090 9090 9201 9201 9187 9156 9774.5 9774.5 9774.5 9774.5 9774.5 9719 9719 9719 9734 9734 9734 9800.5 First Reading For Entire File .......... 9090 Last Reading For Entire File ........... 9849 File Trailer Service name ............. STSLIB.005 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.006 Physical EOF File Header Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Previous File Name ....... STSLIB.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE VEMP VESP VEDP MEXP MESP MEMP MEDP VEXP $ 99 .5OO0 START DEPTH 4320.0 4320 0 4320 0 4320 0 4320 0 4320 0 4320 0 4320 0 STOP DEPTH 5570.0 5570 0 5570 0 5570 0 5570 0 5570 0 5570 0 5570 0 Page 15 # LOG HEADER DATA ljO9.txt DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE IMEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999 Depth Units ....................... Datum Specification Block sub-type...0 VRI Processed TOOL NUMBER Page 16 Name Service Order Units Size DEPT FT 4 VEXP MWD099 OHMM 4 VESP MWD099 OHMM 4 VEMP MWD099 OHMM 4 VEDP MWD099 OHMM 4 MEXP MWD099 OHMM 4 MESP MWD099 OHMM 4 MEMP MWD099 OHMM 4 MEDP MWD099 OHMM 4 ljO9.txt Nsam Rep Code Offset Channel 1 68 0 1 1 68 4 2 1 68 8 3 1 68 12 4 1 68 16 5 1 68 20 6 1 68 24 7 1 68 28 8 1 68 32 9 Name Service Unit Min DEPT FT 4320 VEXP MWD099 OHMM 1.84 VES? MWD099 OHMM 0.975 VEMP MWD099 OHMM 1.06 VEDP MWD099 OHMM 1.193 MEXP MWD099 OHMM 2.588 MESP MWD099 OHMM 2.626 MEMP MWD099 OHMM 2.57 MEDP MWD099 OHMM 2.727 Max 5570 119 583 116 533 147 108 148 645 77 099 86 182 99 484 91.22 Mean Nsam 4945 2501 10.4414 2501 11.0015 2501 11.693 2501 12.3867 2501 10.0975 2501 10.5316 2501 11.0622 2501 11.4513 2501 First Reading 4320 4320 4320 4320 4320 4320 4320 4320 4320 Last Reading 5570 5570 5570 5570 5570 5570 5570 5570 5570 First Reading For Entire File .......... 4320 Last Reading For Entire File ........... 5570 File Trailer Service name ............. STSLIB.006 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 01/04/30 Maximum Physical Record..65535 File Type ................ LO Next File Name ........... STSLIB.007 Physical EOF Tape Trailer Service name ............. LISTPE Date ................ . ..... 01/04/30 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 01/04/30 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Page 17 lj09.txt Next Reel Name ........... UNKNOWN Comments ................. STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File Page 18
