Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
197-187
RECEIVED s • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION �� 3 di "7 R / WELL COMPLETION OR RECOMPL TION REPORT AN 11 ' teeSiK 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned ( uspended C, 1b. Wek f"' 20AAC 25.105 2• 25.110 Development Q Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ,; .lr ConocoPhillips Alaska, Inc. orAband.: December...1.4; 2011 197 - 187 / 311 - 358 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 November 7, 1997 50 029 - 20857 - 01 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 171' FSL, 226' FEL, Sec. 16, T11N, R10E, UM November 11, 1997 1E Top of Productive Horizon: 8. KB (ft above MSL): 99' RKB 15. Field /Pool(s): 1375' FNL, 2514' FWL, Sec. 22, T11N, R10E, UM GL (ft above MSL): 67' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 1434' FNL, 2453' FEL, Sec. 22, T11N, R10E, UM 4913' MD / 4630' TVD Kuparuk River 011 Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 550301 y 5959761 Zone 4 8167' MD / 6442' TVD ADL 25651 TPI: x - 553054 y - 5958234 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 553368 y 5958177 Zone 4 none 469 18. Directional Survey: Yes ❑ No 0 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) 3380' MD / 3345 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" 65# H -40 35' 112' 35' 112' 24" 326 sx AS II 10.75" 45.5# K -55 33' 2398' 33' 2398' 13.5" 1400 sx AS III, 250 sx AS I 7" 26# K -55 32' 7395' 32' 6095' 8.75" 700 sx Class G, 250 sx AS I 3.5 9.3# L -80 5360' 8167' 4987' 6443' 6.125" 510 sx Class G 24. Open to production or injection? Yes ❑ No Q 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" 4985-5370' 5370' MD / 4995' TVD perfs squeezed off from 4978' -4988' MD 4684'4692' TVD tubing punches from 5350' -5356' MD 4979' -4984' TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. perfs squeezed off from 7344' - 7900' MD 6071 TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 4952' -4988' MD 20 bbls 15.8# Class G 5308' -7006' MD 6 bbls 15.8# cement 7006-7900' MD 26 bbls 15.8# cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) shut - in 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 01L -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No Q 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 REIDMS JAN 21 2012 Form 10 -407 Revised 12/2009 CONTINUED ON REVERSE Submit original only A 28. GEOLOGIC MPjRKERS (List all formations and m• encountered): 29. • FORMATION TESTS ' NAME MD TVD Well tested? ❑ Yes EI 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 3380' 3345' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: not applicable 30. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese © 263 - 4250 1*J, Printed Name H. Gober Title: Wells Engineering Supervisor 1 + /� Signature Phone 263 - 4200 Date ( Z(4 / 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 12/2009 1 E -24A Well Work Summary DATE SUMMARY • 11/23/11 GAUGED TUBING 2.78" TO ' SLM. IN PROGRESS. 11/24/11 SET 2.81" MA -2 PLUG @ 5331' RKB. SET 3 1/2" AVA CATCHER @ 5331' RKB. PULLED 5/16" GLV FROM 4807' RKB. LOADED TUBING AND IA W/ DIESEL. IN PROGRESS. 11/25/11 CMIT TO 2500 PSI PASSED. SET 1" INT. LATCH DV @ 4807' RKB. PULLED CATCHER FROM 5531' RKB. PULLED 2.81" MA -2 PLUG FROM 5331' RKB. WELL IS READY FOR CTU. 11/27/11 RUN# 1 - -RAN A NIPPLE LOCATOR FOR DEPTH CORRELATION. PUMPED 150 BBLS TO KILL THE WELL, DISPLACED S/D OUT OF CT, RUN #2 - -RIH, AT SET DEPTH, CEMENT RETAINER SET PREMATURELY AT 7006' RKB WITH NO INDICATION AT SURFACE, TROUBLE SHOT THE PROBLEM, POOH, F/P THE WELL, RE -START IN THE AM 11/28/11 RIH, STING INTO CEMENT RETAINER, PREFORM INJECTIVITY TEST FOR PRESSURES & RATES. PUMPED 12 BBLS 15.8# CEMENT BELOW RETAINER, LAYED IN 14 BBLS 15.8# CEMENT ABOVE RETAINER. TOC @ 5390' RKB. JOB IN PROGRESS, READY FOR S/L 11/29/11 GAUGED TBG TO 2.78" TO CMT © 5379' SLM. READY FOR E -LINE. 11/30/11 MIT TUBING TO 2500 PSI (PASSED). PERFORATE SQUEEZE HOLES FROM 5350 -5356' WITH A 2.0 ", 4 SPF, 0 DEG PHASE, BH CHARGES (24 HOLES). ESTABLISH 2 BPM RATE THRU SQUEEZE HOLES WITH LRS. DISPLACE TUBING X IA WITH 190 BBLS SEAWATER FOLLOWED 100 BBL DIESEL. ALLOW FLUIDS TO U -TUBE. 12/1/11 RAN BAKER CEMENT RETAINER (2.70" RUN OD) AND SET AT 5308' MID ELEMENT. SET DEPTH WAS 8' THAN PROCEDURE TO AVOID A 5' PUP AND COLLAR. 12/2/11 RIH, STING INTO UPPER CEMENT RETAINER © 5308' RKB, PERFORMED INJECTIVITY TEST, F/P IA, PUMPED 4 BBLS 15.8# CEMENT BELOW RETAINER INTO IA, LAYED IN 2 BBLS 15.8# CEMENT ABOVE RETAINER. TOC @ 5250' RKB. JOB IN PROGRESS, READY FOR S/L 12/3/11 TAGGED @ 5307' RKB WITH 2.77" BARBELL ASS'Y. ATTEMPTED MIT TBG, FAILED. STATE WITNESS LEFT LOCATION, INSTRUCTED NOT TO PROCEED WITH TUBING CUT. REATTEMPTED MIT TBG 2500 PSI, PASSED. UNABLE TO MIT IA, LIVE GLVs (F /Ns STRIPPED SEPT, 2006). IN PROGRESS. 12/6/11 CONDUCTED STATE WITNESS MIT TUBING TO 2500 PSI (PASSED) AND MIT TUBING X IA TO 1500 PSI (PASSED). RAN RADIAL CEMENT BOND TOOL (RCBL) TO 5304', CEMENT RETAINER AT 5308'. FOUND TOP OF CEMENT AT 5020'. 12/7/11 RUN JET RESEARCH 2.5" CAST IRON TUBING CUTTE CUT TUBING AT 4985' RKB. CORRELATE TO TUBING DETAIL NOV 14, 1997. TUBING PRESSURE EQUALIZED WITH THE IA `RESSURE AFTER CUT. BEFORE: T /IA/OA = 1200/50/420, AFTER: T /IA/OA = 400/400/420 12/10/11 Rig Released from well 3G -22 © 0400 HRS. Blow down all lines. Move Boiler, Motors, Pump & Pit complexes to 1 E - pad. MOve pipe sheds. Pull Sub structure off of well 3G -22. Move sub to 1 E pad. SPot over well 1 E -24. Spot all complexes. Spot rockwasher & pipe sheds. Trucks back to 3G to move rig camp. Work on rig acceptance checklist. 12/11/11 Continue work on Rig acceptance checklist. Move rig camp to 1E pad. Spot and rig up same. Rig accepted at 0300 HRS. Take on seawater. Rig up bleed tank & lines. RU lines in cellar. test lines to 2000 PSI. Pull BPV w/ Lubricator. Pump down tubing taking returns to bleed tank, 185 BBLS. Monitor well - static. Set BPV. Nipple down tree. NU BOP's. Rig up and test BOP's. Witness of test waived by AOGCC rep John Crisp. 12/12/11 Continue test BOP's. All test 250 / 3500 PSI, recorded on chart. Perform Koomey test. Observed initial 200 PSI increase in 37 Seconds, full 3000 PSI gained in 192 Seconds. 5 Nitrogen bottles with an avg PSI of 2100. Witness of test waived by AOGCC rep John Crisp. Pull & lay down 3 1/2" tbg. Set test plug, and test BOP's with 4" test joint. Make up BHA #1, Mill & scraper run, TIH picking up 4" DP singles from shed. Tag up at 4947'. 12/13/11 Pumps on, Rotate 60 RPM's to wash down 21' to 4968' DPM. Confirm DP depth. Hard tag with 15K set down, and wouldn't mill off. Circulate Safe surf & Hi Visc sweeps, until clean. POOH 12/13/11 PERFORATE FROM 4978' -4988' USING 10' 2.5" HSC LOADED 6 SPF, 60 DEG PHASED, 11 GR BIG HOLE MILLENIUM CHARGES SET 5.5" BAKER CEMENT RETAINER AT 4968' 12/14/11 Pump cement squeeze job. POOH to 20 stands. P/U Storm Packer, set Packer 75 feet down. Nipple down BOP. 10" growth. Spear 7" casing. Set slips with 80K. Cut casing. /15/11 Install new packoff and tubing spool. N/U BOPE. Test. Retrieve storm packer. POOH to cement stinger. L /D.P /U whipstock. TIH. Begin Milling to 4922' MD. 9 feet. Stop to treat milling fluid. 12/16/11 Displace Drill Plex mud out to LSND. Mill Window and 20 feet of new hole to 4946'. Perform FIT to 12.5 PPG EMW. POOH. RIH with magnets to bottom. POOH for Sperry BHA. opff�,.. -/ KUP • 1E-24A A Conoco 'Phillips twat Well Attributes Max Angle & MD TD Alaska Wel!bore API /UWI Field Name Well Status Inc/ ( °) MD (108) Act Btm (ftKB) Lor,.xa+„wps 500292085701 KUPARUK RIVER UNIT PROD 64.89 7,795.51 8,167.0 ''" Comment H2S (ppm) Date Annotation End Date KB - Grd (ft) Rig Release Date "' SSSV: NIPPLE 90 9/15/2010 Last WO: 32.30 12/13/1982 Well Confi9: -18 -248 1/25/20128:28'07 AM ' Schematic - Aber" Annotation Depth (ftKB) End Date Annotation Last Mod... End Date Last Tag: RKB 5,307.0 12/3/2011 Rev Reason: ADD TUBING 8 NOTES ninam 1/25/2012 HANGER, 23 Casing Strings I .. Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd CONDUCTOR 16 15.062 35.0 112.0 112.0 65.00 H WELDED - ' Casing P 9 9 P l ) Depth ( Pt (TV ) 9 String String Top 1 111 MIK ! Description Strin 0. .. Strin ID ... To ftKB Set De h f... Set De h D ... String Wt... Strin Strin To Thrd SURFACE 103/4 9.794 33.0 2,398.2 2,398.2 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd PRODUCTION 7 6.276 31.9 7,394.6 6,094.9 26.00 K - 55 BTC 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 _ 5,360.4 8,167.0 9.30 L - 80 BTC - MOD CONDUCTOR, 35-112 Liner Details • Top Depth SAFETY VLV. (TVD) Top Inc! Nomi... 1,785 1 ° Top (ftKB) (RKB) 1 ") Item Description Comment ID (In) 5,360.4 4,987.2 38.18 SLEEVE BAKER HR SETTING SLEEVE 4.187 SURFACE, 5,370.4 4,995.1 38.14 PACKER BAKER C -2 ZXP MECHANICAL ISOLATION PACKER 5.000 33 - 2,398 5,374.2 4,998.0 38.13 HANGER BAKER HMC HYDRAULIC LINER HANGER 5.000 GAS LIFT, 5,381.0 5,003.4 37.87 SBE BAKER 80-40 SEAL BORE EXTENSION w/ XO TO 3 1/2 BTC -MOD 2.992 2,504 GAS LIFT, Tubing Strings 3,709 Tubing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd GAS A772: TUBING 31/2 I 2.992 !Top ( 5,396.9 I 5,016.0 I 9.30 I L - 80 I EUE8RDMOD WHIPSTOCK, 4.913 A. Com Details RETAINER, Top Depth 4,952 - - (TVD) Top Inc' Noml... IPERF,_ 4,978 <.988 Top (ftKB) ( ftKB) (1 Item Description Comment ID (in) pion TBG CU ✓ T. 5,331.5 4,964.5 38.27 NIPPLE CAMCO W LANDING NIPPLE 2.812 4.985 GAS LIFT._ - 5,371.1 4,995.6 38.14 SEAL ASSY BAKER GBH - 22 LOCATOR SEAL ASSEMBLY w/ 10' SEALS 3.000 5,288 RETAINER. - -1 Other In Hole (Wireline retrievable plugs, valves, pumps, fish, etc.) NIPPLE. 5,331 - • Top Depth TBG (TVD) Top Inc] PUNCHES,- - Top ftKB ftKB) (°) Description Comment Run Date ID 5, P( ) ((in) IPERF, . 4,913 4,630.6 34.20 WHIPSTOCK BAKER GEN 11 12/15/2011 5,350 SEAL ASSY, 4,952 4,662.5 34.18 RETAINER Baker Model "K -1" cement retainer run on WL. Set @ 4968' 12/13/2011 5.371 WLM. Tagged w/ drill pipe @ 4952 Doyon 141 RKB. 5.5 LINER, 4 ' 6 °'� 4,985 4,689.7 36.15 TBG CUT 12/7/2011 2.992 5,308 4,946.0 38.31 RETAINER CEMENT RETAINER 12/6/2011 I . 7 5,350 4,979.0 38.21 TBG PUNCH TUBING w/ 2." MILLENIUM, 4 SPF, 0 DEG 11/30/2011 2.992 PUNCHES PHASING Perforations & Slots Shot Top (TVD) Btm (TVD) T op (ftKB) Btm (ftKB) (ftKB) De ) (rtK8) Zone Date (.h.- Type Comment 4,978 4,988 4,684.1 4,692.2 12/13/2011 6.0 IPERF 10', 2.5" HSC LOADED, 60 DEG A� PHASING, 11 GR BIG HOLE MILLENIUM CHARGES IIIQ 5,350 5,356 4,979.0 4,983.7 11/30/2011 4.0 IPERF 0 DEG PHASE, BH CHARGES C, 7,344 7,360 6,071.1 6,078.6 C-4, 1E -24A 8/26/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random orient Inn ? 7,360 7,390 6,078.6 6,092.7 C-4, 1E -24A 2/24/2000 4.0 APERF 2 1/2" HC, 180 deg phasing, 90 deg orient 1 1 1\ 7,400 7,420 6,097.4 6,106.8 C-4, 1E -24A 1/25/2000 4.0 APERF 2 1/2" HC, 180 deg phasing, 90 deg orient 7,430 7,440 6,111.6 6,116.2 C-4, C -3, 1E -24A 8/26/2004 6.0 APERF 2' HSD Guns, 60 deg phase, random orient z o. _, 7,442 7,452 6,117.1 6,121.8C- 3,1E -24A 7/13/1998 4.0 IPERF 180 deg phasing, 90 deg orient, 2 ` - - 7 I 1/2' HC ' 7,460 7,470 6,125.5 6,130.1 C -3, 1E -24A 8/26/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random "I - orient 7,520 7,550 6,153.2 6,167.1 C- 2,C -1, 1E -24A 8/25/2004 6.0 APERF 2' HSD Guns, 60 deg phase, random orient 7,818 7,840 ' 6,284.0 6,294.2 A -5, 1E -24A 8/25/2004 6.0 APERF 7' HSD Guns, 60 deg phase, random orient ji 7,880 7,900 6,312.6 6,321.3 A-4, 1E -24A 11/28/1997 4.0 IPERF 180 deg. phasing, 2' Hollow Carrier APERF. Cement Squeezes 7.344-7.360 Top Depth Mat Depth APERF, "ro (ND) (TVD) 7.380-7I390 (ftKB) (ftKB) Description Start Date Comment PRODUCTION, Top (ftKB) Btm (ftKB) ( 32 5,360.0 8,167.0 4,986.9 LINER 12/28/2011 CEMENT, 4,959 Notes: General & Safety APERF, End Date Annotation 7,400 11/24/2004 NOTE: WAIVERED WELL: IA x OA COMMUNICATION APERF, 7,430 - 7,440 8/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 IPERF, 7,442 -7,452 Mandrel Details APERF, Top Depth Top Port 7.480 -7,470 (TVD) Inc! OD Valve Latch Size TRO Run Stn Top (ftKB) (ftKB) 0 Make Model (in) Sery Type Type (In) (psi) Run Date Corn... 75201 1 2,504.1 2,504.0 0.99 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/29/2011 2 3,709.3 3,638.6 31.73 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/29/2011 3 4,772.1 4,512.1 32.71 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/29/2011 APERF, 4 5,448.9 5,092.9 19.50 CAMCO KBG -2 -9 1 GAS LIFT DMY DK -1 0.000 0.0 12/29/2011 7818 - 7,840 5 6,001.0 5,615.3 25.40 CAMCO KBG - 2 - 9 1 GAS LIFT SOV DCK - 3 0.000 0.0 12/29/2011 IPERF, - 7.880 -7,900 -- 3.5 Liner, 5.360 LINER, 5,380-8,187 TD (1E-24A), 8,167 KUP • 1E-24A Conoc f • Alaska. Inc. ConocOPh4lhps HBGrd ( Rig Release Date ••• WWI Conk. -1E -24A 1125120128'. 2807 AM 32.30 12/13/1982 - Schematic - Actual HANGER. 23 I�r! Notes: General & Safety End Date Annotation 12/6/2011 NOTE: TOC @ 5020' BEHIND T CASING CONDUCTOR, ■ 35 -112 SAFETY VLV, o 785 SURFACE. 3 -2398 3 III J -2 398 GAS LIFT, 2.506 GAS LIFT, 3,709 Fri, .. GAS LIFT, 4,772 WHIPSTOCK, 4,913 (- RETAINER, 4, 952 - IPERF 4 978 CU r — II TBG CU 1,985 GAS LIFT. 5 288 RETAINER, 5.308 NIPPLE,5331 TAG ' PUNCHES 5.. I PESFRF. SE A SEAL L A AS . 371 5.371 5.5 LINER ■1 • 14 4,879 -8,458 II I-1 [ __ *, IMIU C MU I - : imt 1111 J` =r 1 Ilr • APERF, 7,344-7.360 APERF, 7,360 -7.390 PRODUCTION. 32 -7.395 CEMENT, • 4.954 APERF, 7400 -7 420 APERF, 7,430 -7,440 IPERF. __ 7442 -7,452 APERF. 7,460 -7.470 APERF, 7,520 -7,550 APERF, 7 818-7,840 IPERF, 7,880-7,900 3 5" Leer, 5,360 LINER, 5.360-8,187 TD (1E -24A), • 8.167 • • ConocoPhillips Time Log & Summary Wel'view Web Reporting Report Well Name: 1E-24 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 12/11/2011 3:00:00 AM Rig Release: 12/31/2011 2:00:00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/10/2011 ps hr Summary Rig Released from well 3G -22 @ 0400 HRS. Blow down all lines. Move Boiler, Motors, Pump & Pit complexes to 1E - pad. MOve pipe sheds. Pull Sub structure off of well 3G -22. Move sub to 1 E pad. SPot over well 1 E -24. Spot all complexes. Spot rockwasher & pipe sheds. Trucks back to 3G to move rig camp. Work on rig acceptance checklist. 04:00 12:00 8.00 0 0 MIRU MOVE MOB P Rig released from 3G -22 at 0400 HRS. Prep rig to move. Blow down steam, water, air lines. Disconnect all interconnects. Move pipe sheds. Move rockwasher. Load rig modules with PEAK. Move rig from 3G -22 to 1E-24B 12:00 15:30 3.50 0 0 MIRU MOVE MOB P Move Sub base, Pipe Sheds, & Rockwasher from 3G -22 to 1 E -24B 15:30 18:00 2.50 0 0 MIRU MOVE PSIT P Spot sub base over well 1E-24. 18:00 21:00 3.00 0 0 MIRU MOVE PSIT P Spot power pack complexes. Spot rockwasher, and pipe sheds. 21:00 00:00 3.00 0 0 MIRU MOVE MOB P Mobilize trucks to 3G Pad to get rig camp, sewer plant & truck shop. Work on rig acceptance checklist. 12/11/2011 Continue work on Rig acceptance checklist. Move rig camp to 1 E pad. Spot and rig up same. Rig accepted at 0300 HRS. Take on seawater. Rig up bleed tank & lines. RU lines in cellar. test lines to 2000 PSI. Pull BPV w/ Lubricator. Pump down tubing taking returns to bleed tank, 185 BBLS. Monitor well - static. Set BPV. Nipple down tree. NU BOP's. Rig up and test BOP's. Witness of test waived by AOGCC rep John Crisp. 00:00 03:00 3.00 0 0 MIRU MOVE MOB P Continue work on rig acceptance checklist. Move rig camp from 3G - 1E pad. Set stairs,and build berms. Spot and rig up same. Rig accepted at 0300 HRS. 03:00 05:00 2.00 0 0 SLOT DRILL RURD P Take on 580 BBLS of seawater to pits. Set bleed tank. Rig up lines from cellar to tank. 05:00 08:15 3.25 0 0 SLOT DRILL RURD P Rig up lubricator as per FMC rep. Test Lub to 5K - 5 minutes. Pull BPV. Observed no pressure under BPV. Rig down Lubricator. 08:15 08:30 0.25 0 0 SLOT DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to tets lines, kill well, pumping diesel returns to bleed tank. Page 1 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 08:30 11:30 3.00 0 0 SLOT DRILL KLWL P Pump down tubing at 3 BPM - 800 PSI, returns (diesel) to bleed tank. Observed "packing off' when attempting to pump 4 BPM. Pressure stabilized at 1500 PSI with 1.2 BPM. Pumped a total of 185 BBLS> 11:30 12:00 0.50 0 0 SLOT DRILL OWFF P Monitor well - static. Blow diown lines to bleed tank. Crew Change 12:00 12:45 0.75 0 0 SLOT DRILL CIRC P Line up to take returns to rockwashewr, and pump to verify down hole packoff at 2.5 BPM -1600 PSI. Pump a total of 20 BBLS. Monitor well - static. 12:45 13:00 0.25 0 0 SLOT DRILL RURD P Blow down all lines. Rig down lines in cellar and to tank. 13:00 13:30 0.50 0 0 SLOT WHDBO NUND P Install BPV. Held PJSM - ND Tree. 13:30 16:00 2.50 0 0 SLOT WHDBO NUND P Nipple down tree as per FMC rep. Observe orientatioin of tree for future reference. Install blanking plug for test. Nipple up double studded adapter flange. 16:00 18:30 2.50 0 0 SLOT WHDBO NUND P Nipple up BOP stack, choke & kill lines. 18:30 19:00 0.50 0 0 SLOT WHDBO BOPE P Rig up to test BOP's. Load system with water. 19:00 22:45 3.75 0 0 SLOT WHDBO BOPE P Test BOP's. Several attempts made for initial test, without success, observed that the blanking plug D leaking. Install solid joint, and n rt remove test joint. Re test, with same result. Pull blanking plug, change out ball seat in blanking plug. Install 3 1/2" test joint. Test to 3500, for good initial test. 22:45 00:00 1.25 0 0 SLOT WHDBO BOPE P Continue test BOP's. Test choke manifold and all valves. Test choke & kill lines manual valves and HCR's. Test Upper and lower rams, and IBOP. All test 250 / 3500 PSI as per permit. All tests recorded on chart. Witness of test waived by AOGCC rep John Crisp. Crew Change 12/12/2011 Continue test BOP's. All test 250 / 3500 PSI, recorded on chart. Perform Koomey test. Observed initial 200 PSI increase in 37 Seconds, full 3000 PSI gained in 192 Seconds. 5 Nitrogen bottles with an avg PSI of 2100. Witness of test waived by AOGCC rep John Crisp. Pull & lay down 3 1/2" tbg. Set test plug, and test BOP's with 4" test up scraper Make u BHA #1, Mill & er run, TIH picking up 4" DP singles from shed. Tag up at joint. P 4947'. Page 2of • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:15 3.25 0 0 SLOT WHDBO BOPE P Continue test BOP's. Utilize 3 1/2" test joint. All test 250 / 3500 PSI, recorded on chart. Perform Koomey test. Observed initial 200 PSI gained in 37 seconds. Full 3000 PSI obtained in 192 seconds. Observed 5 Nitrogen bottles iwth an avg PSI of 2100. Witness of test waived by AOGCC rep John Crisp. 03:15 05:00 1.75 0 0 SLOT WHDBO BOPE P Rig down test equipment. Drain stack, and pull blanking plug. 05:00 05:30 0.50 0 0 SLOT DRILL PULD P Break floor valves. Blow down choke & kill lines. Pull tools to rig floor. 05:30 05:45 0.25 0 0 SLOT DRILL SFTY P Held PJSM with crew and Doyon casing rep. Discuss safety & hazard recognition issues. Discuss procedure to rig up and pull 3 1/2" tubing. 05:45 06:45 1.00 0 0 SLOT DRILL RURD P Pull tools to rig floor. Make up power tongs, prep to pull 3 1/2" tubing. Make up landing joint with pups. BOLDS. 06:45 07:00 0.25 0 0 SLOT DRILL PULL P Pull on 3 1/2" tbq, hanger & tbg free movement. UP WT = 70K. 07:00 12:00 5.00 0 0 SLOT DRILL PULL P Breakout & lay down hanger, and landing joint. Install stripping rubbers. Pull and lay down 136 joints of 3 1/2" tbg. Observed proper displacement. Crew Change 12:00 13:15 1.25 0 0 SLOT DRILL PULL P Continue POOH lay down 3 1/2" tubing. Total laid down = 158 jnts, 3 GLM's, 2 pups and a cut off joint = 15.58'. Cut looked good. Strapped tubing & jewelry laid down - total - 4945.43' 13:15 14:30 1.25 0 0 SLOT DRILL RURD P Rig down handling equipment. Clean & clear rig floor. 14:30 17 :30 3.00 0 0 SLOT WHDBO BOPE P Held PJSM. RU test equipment, set test plug with 4" test joint. Test BOP's to 250 / 3500 PSI, record on chart. RD test equipment, pull test plug. 17:30 18:00 0.50 0 0 SLOT DRILL RURD P Install wear bushing. RILDS 18:00 18:15 0.25 0 0 SLOT DRILL SFTY P Held PJSM with crew. Discuss safety & hazard recognition issues. Discuss procedure to make up BHA, and TIH picking up DP from shed. 18:15 00:00 5.75 0 4,947 SLOT DRILL TRIP P Make up BHA 31, 6.125" Mill and scraper assembly. Trip in hole picking up 4" DP singles from shed. Tag up at 4947' DPM. Crew Change 12/13/2011 Pumps on, Rotate 60 RPM's to wash down 21' to 4968' DPM. Confirm DP depth. Hard tag with 15K set down, and wouldn't mill off. Circulate Safe surf & Hi Visc sweeps, until clean. POOH Page 3 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 01:00 1.00 4,947 4,968 SLOT DRILL WASH P Pumps on, UP WT 105K, SO WT 87K. ROT 60 RPM's pumps at 5 BPM - 450 PSI. Wash down through the tight spot at 4947' DPM, mill fell through, continue wash down and tag up at 4968'. Attempt to mill through tight spot with 10 -15K, no success. Straight hard tag with 15K set down weight. Discuss options with town engineer. 01:00 03:15 2.25 4,968 4,968 SLOT DRILL CIRC P Reciprocate drill string while pump safe surf sweep, followed with High visc sweep. Circulate until clean as planned with pumps at 6 BPM - 450 PSI. Note: OA pressure = 475 PSI. Bleed pressure to bleed tank. 03:15 03:30 0.25 4,968 4,968 SLOT DRILL OWFF P Monitor well. Static. Blow down top drive. 03:30 05:30 2.00 4,968 9 SLOT DRILL TRIP P Trip out of the hole with the scraper assembly from 4968' to 9.30'. 05:30 05:45 0.25 9 0 SLOT DRILL PULD P Lay down BHA #1 casing scraper. 05:45 06:15 0.50 0 0 SLOT PERF RURD P Clear and clean rig floor, in preparation for peforating. 06:15 11:00 4.75 0 0 SLOT PERF RURD P PJSM, Remove bell nipple and bell nipple adaptor. Install shooting flange on top of annular. 11:00 12:00 1.00 0 0 SLOT PERF RURD P Pick up E- Line from beaver slide. , Rig up Halliburton E - Line 12:00 13:15 1.25 0 0 SLOT PERF RURD P PJSM with Halliburton E Line crew and rig crew. Continue to rig up electric line equipment. Nipple up E - Line BOPE stack with pump in sub, make up riser and grease head, make up pert gun and nipple up to stump. Flood kill line. 13:15 13:30 0.25 0 0 SLOT PERF PRTS P Pressure test lubricator through kill line to 1000 PSI, Held for 5 mins. No leaks. Bleed off pressure, monitor returns to trip tank. 13:30 14:15 0.75 0 5,075 SLOT PERF ELOG P Run in hole with perforation gun on E - Line @ 175 FPM to 5075' WLM. Correlate and fire guns from 4978' to 4988' WLM depths. 14:15 15:00 0.75 5,075 0 SLOT PERF ELOG P Pull out of the hole with E - Line. 15:00 16:30 1.50 0 0 SLOT PERF RURD P Rig down riser, remove spent perforation gun, monitor well, static, SIMOPS: nipple down E - Line BOP stack, make up short riser to grease head, make up cement retainer to E - Line and make up to stump. 16:30 17:45 1.25 0 4,968 SLOT PERF MPSP P Run in the hole with Baker Cement Retainer on E - Line. 150 FPM. Set @ 4968' WLM 17:45 19:00 1.25 4,968 0 SLOT PERF TRIP P Pull out of the hole with E -Line Page 4 of 30 • Time Logs Date From To Dur S. Depth E. Death Phase Code Subcode T Comment 19:00 19:45 0.75 0 0 SLOT PERF RURD P Rig down Halliburton E - Line equipment 19:45 21:15 1.50 0 0 SLOT PERF NUND P Nipple down shooting flange. 21:15 22:30 1.25 0 0 SLOT PERF NUND P Nipple up bell nipple and riser. 22:30 00:00 1.50 0 1,383 SLOT CEMEN'TRIP P PJSM, Trip in the hole with stand #1. Make up head pin to top single, and lay down in pipe shed. Pick up the double and make uo the cement stinger assembly. Trip in the hole to 1383. Disp= 7.5 BBLs. Actual 8.1 BBIs. 12/14/2011 Pump cement squeeze job. POOH to 20 stands. P/U Storm Packer, set Packer 75 feet down. Nipple down BOP. 10" growth. Spear 7" casing. Set slips with 80K. Cut casing. 00:00 01:00 1.00 1,383 4,952 SLOT CEMEN "TRIP P PJSM, Continue to trip in the hole from 1383' to 4952'. Tag up on retainer. Actual displacement= 28.25, Calculated displacement =28.5 01:00 01:30 0.50 4,952 4,952 SLOT CEMEN" CIRC P Pick up single, Rig up to circulate and pump cement with SLB. 01:30 02:00 0.50 4,952 4,952 SLOT CEMEN' CIRC P Obtain parameters @ 2 BPM = 100 PSI, 3 BPM = 125 PSI. Close Super choke to 7 /8th's and record 200 PSI annular pressure with 3 BPM. Mark gauge. Up Wt =100k, Dn Wt =90k 02:00 02:15 0.25 4,952 4,952 SLOT CEMEN" CIRC P Verified retainer depth. 4952' DPM. Set 10k down, P/U to 9K over to unsnap. Repeat 3x's. 02:15 03:00 0.75 4,952 4,952 SLOT CEMEN" PRTS P Pressure test retainer to 1000 PSI for 5 mins. Charted. Perform injectivity test. Stage pump up to 1 BPM. 10 strokes 1 BBUmin 800PSI 20 1 1300 30 1 1300 40 1 1300 50 1.5 BBL/min 1300 60 1.5 1250 70 1.5 1250 80 2.0 1300 90 2.0 1300 100 2.0 1300 120 3.0 1300 130 3.0 1300 140 3.0 1300 150 3.0 1300 Pumped away 15 barrels. 2.5 barrels bleed back in 20 mins. 03:00 03:15 0.25 4,952 4,952 SLOT CEMEN' PRTS P Bleed off all pressure. Line back up to go through Super Choke. 03:15 03:30 0.25 4,952 4,952 SLOT CEMEN' SFTY P Prejob safety meeting with all crews for Cement Job. 03:30 04:30 1.00 4,952 4,952 SLOT CEMEN' PRTS P Prime up cement truck pumps, lines equipment. Pressure test lines to 3500 PSI. Good. Page 5 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 04:30 06:30 2.00 4,952 4,952 SLOT CEMEN" CMNT P Ratchpri lip 15.8 PPG cement. Pump 10 BBLs water, 20 BBLs Cement. 6 BBLs water, 16 BBLs seawater. Holding 200 PSI on backside. Shut down pumps. Sting into retainer. Close super choke. Close choke side HCR. Place 1000 PSI in annulus. Pump 41 BBLs seawater to displace. Unsting. Drop foam drill pipe wiping ball. Circulate bottoms up 2x's.6.5 BPM, 650 PSI. 2 barrels of cement seen at the shakers. 06:30 07:00 0.50 4,952 4,952 SLOT CEMEN" PRTS P Pressure test casing to 3500 PSI. 30 mins. Charted. good. 07:00 07:30 0.50 4,952 4,952 SLOT DRILL TRIP P Lay down single. Blow down choke and kill lines. Monitor well Static. 07:30 09:15 1.75 4,952 1,856 SLOT DRILL TRIP P POOH from 4952' to 1856'. Actual fill =19 BBLS. Calculated fill = 17.2BBLS. 09:15 10:30 1.25 1,856 1,856 SLOT WHDBO PACK P Pick up Baker Storm Packer. Set 75' down. P/U wt= 60k, S/O wt =58k. Lay down Packer running tool. Test Packer to 500 PSI for 5 mins. good. 10:30 12:00 1.50 1,856 1,856 SLOT WHDBO NUND P PJSM. Drain stack. Nipple down BOPE stack 12:00 13:00 1.00 1,856 1,856 SLOT WHDBO NUND P Continue to nipple down stack and double studed adapter flange. 13:00 14:00 1.00 1,856 1,856 SLOT WHDBO NUND P Break all nuts on tubing spool. Observed growth of casing. 14:00 14:45 0.75 1,856 1,856 SLOT WHDBO NUND P Disassemble tubing spool. 14:45 18:30 3.75 1,856 1,856 SLOT WHDBO NUND P Rig up hydratight tools, SIMOPS: load pipe shed with 16 jts. 4" DP. Grow casing in controlled manner with hydratight tool. 10.5" growth. Rig down hydratight. 18:30 19:30 1.00 1,856 1,856 SLOT WHDBO NUND P Pull 7" Pack off, Pick up Baker spear. SIMOPS: stage tubing spool in cellar. 19:30 22:00 2.50 1,856 1,856 SLOT WHDBO FISH P Make up spear assembly to top drive. Engage 7" casing with spear. Pick up to 100k over block and string weight. Set slips per FMC reps. Set 80k weight on slips. Release spear and lay down. 22:00 00:00 2.00 1,856 1,856 SLOT WHDBO CPBO P Prepare casing head make up WACHS cutter to stump. SIMOPS: load pipe shed with 9 - 4%" DC's, 14 - 4" HWDP. Cut off casing stump 7" casing + Hanger 7 1/4" for a total of 14 1/4". 12/15/2011 Install new packoff and tubing spool. N/U BOPE. Test. Retrieve storm packer. POOH to cement stinger. UD.P /U whipstock. TIH. Begin Milling to 4922' MD. 9 feet. Stop to treat milling fluid. Page 6 of 30 • . Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 03:00 3.00 1,856 1,856 SLOT WHDBO NUND P PJSM, Install new pack off as per FMC rep. Pick up and make up new tubing spool. Test to 3000 PSI form 10 mins. Good 03:00 05:30 2.50 1,856 1,856 SLOT WHDBO NUND P Nipple up double studded adapter flange and BOPE stack 05:30 06:15 0.75 1,856 1,856 SLOT WHDBO BOPE P Rig up to test. 06:15 06:30 0.25 1,856 1,856 SLOT WHDBO BOPE P Test choke line and block flange, tubing head flange. 250 PSI low/ 3500 PSI high for 5 mins. 06:30 07:00 0.50 1,856 1,856 SLOT WHDBO BOPE P Rig down test equipment, drain stack, blow down lines. 07:00 07:30 0.50 1,856 1,856 SLOT WHDBO PULD P Install wear ring and short mousehole. 07:30 08:30 1.00 1,856 1,856 SLOT DRILL TRIP P Pick up storm packer retrieval tool and make up to stand. RIH 75'. Latch up to storm packer. Pull storm packer. Monitor well. Static. POOH with packer. Monitor well. Static. 08:30 09:45 1.25 1,856 0 SLOT DRILL TRIP P Trip out of the hole from 1856 to surface. Lay down cement stinger. Actual fill =11.25 BBLS. Calculated fill 10.8 BBLS 09:45 10:00 0.25 0 0 SLOT DRILL PULD P Clear and clean rig floor. 10:00 12:00 2.00 0 0 SLOT WHPST WPST P PJSM. Pick up whipstock and make up 17' spacer joint of bottom of trip anchor, along with two cross overs. (Baker). Lay down ramp. Pick up joint of HWDP and milling assembly. Make up whipstock to mills. 12:00 14:00 2.00 0 420 SLOT WHPST WPST P PJSM. Continue to make up milling assembly (BHA #11. Orient MWD to face of ramp. Make up 9 - 43/4" spiral drill collars, 9 joints of HWDP. 14:00 14:15 0.25 420 420 SLOT WHPST DHEQ P Shallow pulse test MWD 7 BPM / 750 PSI 14:15 17:15 3.00 420 4,888 SLOT WHPST TRIP P TIH from 420' to 4888'._Pick up single from pipe shed. and make up to top drive. P/U Wt= 100k, S/O Wt= 100k. Displacement = 33 BBLS. Calculated = 34.1 BBLS. 17:15 18:00 0.75 4,888 4,913 SLOT WHPST WPST P Break circulation @ 7 BPM. 1100 PSI. Orient whipstock to 43 right of high side. Make up to next stand from derrick. Confirm tool face orientation and taq up on cement retainer @ 4950'. Set down 15k. observe anchor set. Pick up with 10k over pull to verify anchor set. Slack off to shear bolt with 35k. Pick up 10 feet to clear whipstock face. Page 7 of 30 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 18:00 20:30 2.50 4,913 4,913 SLOT WHPST CIRC P PJSM, Displace well to 9.8 PPG Drill Plex milling fluid @ 1 BPM 1100 PSI due to high vis and high YP of mud system. Pressure increased dramatically to 3300 PSI with 4.5 BPM. Isolate active system to pit #5. Attempt to shear out the mud system Stage pumps up to 5.5 BPM. 3200 PSI. TOW= 4913', BOW= 4926'. 20:30 21:00 0.50 4,913 4,913 SLOT WHPST CIRC P Obtain slow pump rates. #1 @20 SPM 1840 PSI, 30 SPM 2200 PSI. #2@ 20 SPM 1960 PSI, 30 SPM 2460 PSI. MD =4913' / TVD= 4640'. MW =9.7 PPG. P/U Wt =115k, S/O Wt =74k, Rot Wt= 80k. TQ off= 3k. Mud Vis 300+ / YP 159. 21:00 23:00 2.00 4,913 4,922 SLOT WHPST MILL P Mill window as oer Baker Reo. from top of window 4913' to 4922'. W/ 2 to 3k WOB, 80 RPM, 4.5 BPM, 3000 y PSI. 23:00 00:00 1.00 4,922 4,922 SLOT WHPST CIRC T Hole taking fluid. Excessive YP of 1\i'VA) 200 +, VIS 1000. Pick up off bottom and slow pump to 3 BPM, evaluate 1 situation. 12/16/2011 Displace Drill Plex mud out to LSND. Mill Window and 20 feet of new hole to 4946'. Perform FIT to 12.5 PPG <'714 EMW. POOH. RIH with magnets to bottom. POOH for Sperry BHA. 00:00 04:00 4.00 4,922 4,922 SLOT WHPST CIRC T Continue to circ, and attempt to condition milling fluid. No go. Prepare to change out to LSND. Clean pits, take on LSND. 290 BBLS. (Pump rate 1 BPM = 1700 PSI w/ Drill Plex.) 04:00 04:45 0.75 4,922 4,922 SLOT WHPST CIRC P Pump Spacer pill. 30 BBLS. Displace out Drill Plex to LSND. 205 barrels in. 205 barrels to the rock washer. Stage pump up to 6 BPM as the LSND rounded the corner, from 3 BPM. ICP =2000 PSI @ 3 BPM. FCP= 1100 PSI @ 6 bpm. 04:45 05:15 0.50 4,922 4,922 SLOT WHPST CIRC P Clean under shakers and possum belly. Obtain new SPR's 05:15 07:00 1.75 4,922 4,946 SLOT WHPST MILL P Milling the window from 4922' to 4946'. 20 feet of new hole. 90 RPM / 5 -8k TQ / 275 GPM / 1450 PSI. TOW =4913. BOW =4926. Retrieved 200LB's of metal. Expected 200 LB's. 07:00 08:15 1.25 4,946 4,946 SLOT WHPST CIRC P Work mills across ramp, window area. Observed increase in pump pressure @ 4926' when working across the ramp. Went back and forth a few more times and it cleaned up. Pumped High Vis sweep. 70 SPM / 1475 PSI / 100 RPM. Good returns. Minor amount of metal. Page 8 of 30 • • tLtc97 WELL LOG TRANSMITTAL '- 1 CCO To: Alaska Oil and Gas Conservation Comm. December 8, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Radial Cement Bond Log/Cement Retainer Setting/Tubing Cut Record: 1E-24A Run Date: 12/01/2011 - 12/07/2011 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 1E -24A Data in LAS format, Digital Log Image files 1 CD Rom 50- 029 - 20857 -01 Cement Bond Log 1 Color Log 50- 029 - 20857 -01 it. -SNP JUN 0 6 ZO1a 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: 12-129 Al Signed: ROL (.* WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. December 1, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1E -24A OWNS ,JUN 0 5 ZW Run Date: 11/30/2011 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 1E -24A Digital Data in LAS format, Digital Log Image file 1 CD Rom 50- 029 - 20857 -01 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 S i ed: / / Date: EE/E IIIIIIII:::: �1... 4 /...! • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday, December 16, 2011 Jim Regg P.I. Supervisor NI/ 1 ZI ill , SUBJECT: Mechanical Integrity Tests CONOCOPHILLIPS ALASKA INC 1E -24A FROM: John Crisp KUPARUK RIV UNIT 1E -24A Petroleum Inspector Src: Inspector Reviewed By: P.I. Suprv, NON CONFIDENTIAL Comm Well Name: KUPARUK RIV UNIT 1E - 24A API Well Number: 50 029 - 20857 - 01 - 00 Inspector Name: John Crisp Insp Num: mitJCr111212080639 Permit Number: 197 - 187 - Inspection Date: 12/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E -24A ' Type Inj. N TVD IA 100 1800 - 1750 ' 1750 P.T.D 1971870' TypeTest SPT Test psi OA 460 480 480 480 Interval OTHER P/F P - Tubing 1175 1750 - 1725 - 1700 - Notes: CMIT IA xT. Communication from IA to tubing. 1.7 bbls pumped for test. Cement plug verification. Plug depth known in tubing but E Line will run cbl to verify cement in IA to cut the tubing. No packer involved with this test. Friday, December 16, 2011 Page 1 of 1 • • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: DATE: Friday, December 16, 2011 Jim R i� (Z I1 `1 '/( SUBJECT: Mechanical Integrity Tests P.I. Supervisor visor CONOCOPHILLIPS ALASKA INC 1E -24A FROM: John Crisp KUPARUK RIV UNIT 1E -24A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry ::16 Comm Well Name: KUPARUK RIV UNIT 1E -24A API Well Number: 50- 029 - 20857 -01 -00 Inspector Name: John Crisp Insp Num: mitJCr111212072941 Permit Number: 197 - 187 - Inspection Date: 12/6/2011 Rel Insp Num: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 1E -24A 'Type Inj. N TVD IA 0 75 75 75 P.T.D 1971870 ' TypeTest SPT Test psi OA 460 460 470 470 Interval OTHER p/F P - Tubing 75 2580 - 2450 2400 Notes: MIT T for P &A. .9 bbls pumped for test. No communication to IA thru tubing. No packer involved with this MITT. Plug at 5308'. - FEB C'L?JAL Friday, December 16, 2011 Page 1 of 1 • Page 1 of 1 Schwartz, Guy L (DOA) From: Wiese, Tyson M [ Tyson .M.Wiese @conocophillips.com] Sent: Monday, December 05, 2011 3:03 PM p TD r1' 7- / o To: Schwartz, Guy L (DOA) Subject: RE: 1 E -24A Cement Plug Thanks Guy. We did tag and test the first plug, but because it is one continuous plug, we only called Lou to witness the top portion of it. Tyson Wiese ConocoPhillips Wells Engineer � , ;} ' �� � 6 Office 907 - 263 -4250 CeII:1- 907 - 230 -5388 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Monday, December 05, 2011 1:38 PM To: Wiese, Tyson M Cc: DOA AOGCC Prudhoe Bay Subject: [EXTERNAL]RE: 1E -24A Cement Plug I read the proposed sundry procedure after talking to you. The 50' is not required on the second plug as it was not the primary isolating plug for the perforated zone. Did you guys ever pressure test the first cement plug? The sundry procedure did not specifically state a test was to be done but was wondering if you did it anyway. In summary, test both IA and Tubing again, have it witnessed and you are within regulation compliance. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Wiese, Tyson M [mailto: Tyson .M.Wiese @conocophillips.com] Sent: Monday, December 05, 2011 1:28 PM • To: Schwartz, Guy L (DOA) Subject: 1E -24A Cement Plug Guy, Thanks for the help this morning. Did you have a chance to talk with Lou about the second retainer on 1 E -24A? Because the TOC from the first plug is about 1950' above the perfs, we were going to setup a plan forward to perform a MIT -T and MIT -IA with Lou present. If both tests pass, that would give us the go ahead to run a CBL to determine cement top in the IA, and cut the tubing. I just wanted to confirm with you that in this case, the 50 ft of cement on top of the second retainer is not a requirement, as we are a sufficient distance above from the perfs, and the rig is going to be performing a 3rd cement plug /squeeze prior to drilling the window. Thanks Tyson Wiese ConocoPhillips Wells Engineer Office:1- 907 - 263 -4250 CeIl:1- 907 -230 -5388 12/5/2011 • MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: December 04, 2011 P. I. Supervisor FROM: Lou Grimaldi SUBJECT: Plug Verification Petroleum Inspector CPAI KRU 1 E -24A Kuparuk River Field PTD 197 -1870 Saturday, December 03, 2011; I witnessed the tag of cement and attempted pressure test of the cement plug and retainer set in CPAI well KRU 1 E -24A in the Kuparuk River Field. I had been doing some MIT's in the ENI Nikaitchuq facility when I was contacted by Chuck Fitzpatrick (KRU W/L coordinator) advising us that a plug tag verification was required on this well. They were in somewhat of a hurry to do this so being in Kuparuk I agreed to go from ENI to this jobsite although it was known today that weather would be turning bad in the evening. I arrived the location to find HES slickline unit rigged up on the subject well. After speaking with the slickline operator and looking through the procedure they ran in the hole with a 2.75 gauge ring to 5288 where they set down, after a few jar licks they set down at 5290'. Josh Peck HES S/L operator explained that he had correlated his counter at a landing nipple just above this depth and been 17' high. The rig elevation was 28 feet making his depth adjustment understandable and within reason. This placed the TOC at 5307' RKB with the reported depth of the retainer at 5308" RKB. I explained that one foot of cement was not as required and they were going to run a sample bailer to see what was down there. At that time they received a call were told to proceed with the pressure tests which would consist of a 2500 psi test on the tubing then a 1500 psi test of the IA. I observed the following during the first tubing test; Pretest Initial 15 min 30 min IA 160 240 240 250 OA 425 425 425 425 Tubing 40 2520 2360 2310 At this point the weather was starting to get bad and I decided that they did not have a sufficient plug and advised them not to cut the tubing until speaking to Guy Scwartz at the AOGCC. I left location. Attachments: KRU 1 E -24 Pre -rig sidetrack P&A procedure.pdf Non - Confidential Plug Verification KRU 1E -24A 12 -03 -11 LG.doc - -• • i R Interoffice ConocoPhillips Communication Date: November 16th, 2011 File code: Well File 1E-24A Subject: 1E-24A Pre -Rig Side Track P&A Procedure To /Location: Central Wells Group NSK-69 Network Number: 10318951 Activity: ZX52 Prepared By: Tyson Wiese Telephone: 263 -4250 / 230 -5388 Approved By: Howard Gober Telephone: 263 -4220 / 240 -5515 Procedure Justification: 1 E -24 was side tracked in 1997, and completed with a 3.5" cemented liner, single packer, and 3.5" tubing to a TD of 8,167' KB, targeting the A and C Sands. A rig side track is planned for November 2011, as part of the 1E A-Sand redevelopment project. Following the rotary side track, CTD laterals are planned, in conjunction with offset CTD injection wells 1 E- 27 (2011) and 1E-23 (2012 +). On 3/30/2009 an E -line PPROF was performed, indicating 0% flow from the A -Sands and 100% flow split between C -Sand intervals. This well has been waivered since 07/04/2009, due to IA x OA communications. After performing a caliper survey on 3/29/2011, slight buckling was noticed from 5,000' KB to 5,360' KB. On 10/23/2011, the tubing was drifted to 2.31 ". Fill was tagged at 7,838' SLM (7861' KB) and BHP readings were as follows; 2314 psi and 150 F © 6109' TVD with a gradient stop at 6,012' TVD that measured 2279 psi and 150 F. The mid pert A and C sand extrapolated pressure is 2,347 psi @ 6,200' TVD. Per this procedure, a Pre-Rig Sidetrack P&A will be performed to isolate the A and C sand perfs by pumping 12 bbls of 15.8 ppg cement through a cement retainer at 7,000' KB, laying in 14 bbls of cement above the retainer, to a depth of 5,390' RKB. Tubing holes will be punched at 5,350' KB (20ft above the top packer), and 4 bbls of 15.8 ppg cement will be circulated into the IA and tubing, laying in 2 bbls of cement on top of the retainer, to a planned Top of Cement at 5,250' KB. E -line will make a tubing cut at 5,081' KB (about 169 ft above TOC, staying 166 ft below the planned kick off point of 4,915' KB), and verify a good cut by circulating through it. cc: CPA Wells Supt e-mail 1E Pad Engineer e-mail CPF -1 Prod. Engineer a -m0 CPAI Wells Supervisors e-mail Ty Senden, Howard Gober e-mail TW 11/29/2011 • • Job Objective: Abandon the perforations with cement in preparation for a rig sidetrack. Contact AOGCC to witness the tag and pressure test of the top cement plug. Cut the tubing at 5,081' KB, with a planned KOP of 4,915' KB. Well Status: As of 10/27/2011, the well is online and producing 328 BOPD and 2,762 BWPD for a water cut of 89.4 %. Tie in Reference: Tubing Details — 11/14/1997 Well Design Envelope / Job Concerns: CT x Tubing IA OA OOA (backside) Max. Press. (psi) 1400 1400 Fluid (ppg) 8 6 8.6 Depth (TVD) 4996 2398 Max BHP (psi) 3634 2472 Pipe Ratings (psi) 7" 2611 K 55 10 314" 45.511 K " (Burst /Collapse) 4980 4330 _ 3580 1 11 `, Min I.D. • W Nipple} Max. Dev. : 64.9 (11•9 Latest SIBHP & T: . ', , u'+ I v1, Max Dog Leg: 11.2 (113/1f)(111 Latest Surface Press. i ! :x,11 p. >r Last Tag: 1 iI .t,, , Max Pump Rate: 1nr1rl,:(s) Last Drift: 1 ,1 r It Other Notes: . url.a,c 1'ressuros dotOrmined by IA x UA Wiry! r I ' Baker Inflatable Cement Retainer Specs: O.D. = 2.13" Min Setting ID = 2.37" Max Setting ID = 7.03" OAL = 14.60' (w/ spotting valve) Baker Model H -1 Mechanical Cement Retainer Specs: Designed for 3.5" Tubing (5.7# - 9.3#) O.D. = 2.765" OAL = 1.35' TW 11/29/2011 • Procedure: Slick Line / Little Red: A'', Ensure sundry has been received from AOGCC. Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. .3" Communicate with the Pad Operator to ensure that the well has been shut in, and that gas lift is shut down on the IA. .4' MIRU Slick line and PT Equipment. .J: Pull OV CO 4,807' KB. Set Dummy Valves in GLM's @ 3,927' KB and 2,610' KB. fir RU LRS and F.P. the IA to surface, through the open pocket © 4,807' with approx 170 bbls of Diesel. ,7' RIH and set Dummy Valve in the open pocket © 4,807' KB. -e PT the IA to 1,400 psi max. OA may slowly bleed to IA due to past communication. Cone RDMO, Turn well over to Pad Operator or Coiled Tubing Operations. Coiled Tubing: Contact Schlumberger a week before the scheduled P&A date, to allow adequate time for pilot testing of the P&A cement design. (Jimmy Coleman / Fred Kitterman 659 -6121 or 659- 2434). The job is designed for 26 bbls of 15.8# Class G cement with appropriate additives. /Z. Contact Baker (Milo © 907 - 685 -1061) to ensure two cement retainers are available on the slope. Utilize the Baker Cast Iron Retainer for the second cement plug, if we are able to drift to 2.78 ". ,..3 Conduct Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. MIRU CTU and PT Equipment. Notify AOGCC Inspector (659 -2714; pager 659- 3607) of date and time of the P&A operation. ,Er' Bullhead 150 bbls of KWF (seawater) down the 3.5" tubing to kill the well. Monitor IA pressures during well kill. Total Tubing Volume = 69 bbls. Jr: Tie into 11/14/1997 reference tubing details provided below. Use a nipple profile locator to correlate depth off the 2.812" Camco W Nipple © 5,331' KB if available. RIH with Baker 2.13" inflatable cement retainer and set at 7,000' KB, approx. 344 ft above the upper most perforation. 87 Perform injectivity test using 30 bbls of seawater to obtain pressure and rate data. RU Schlumberger Cement Equipment. Pressure Test Equtprnrrnl .irir! • ., t Pressure to he determined by SL13. 1Q Mix 26 bbls of 15.8 ppg cement to be squeezed into the perforations from 7,344' — 7,900', as well as fill the 3.5" tubing from 7,344' - 5,390'. Cement volume for squeeze detailed below: - Tubing Volume (below retainer) = (7,861' — 7,000*(0.00869 bbl/ft) = 7.5 bbls - Squeeze Volume = (7.5 bbls)*50% = 3.75 bbls - Tubing Volume (above Retainer) = (7,000' — 5,390 *(0.00869 bbl/ft) = 14 bbls - Total Volume = 25.3 bbls TW 11/29/2011 0 • 1 Pump schedule below: / a.) 5 bbls Fresh Water Spacer b.) 26 bbls of 15.8# Cement c.) 5 bbls Fresh Water Spacer d.) 45 bbls Biozan Gel e.) Sufficient Diesel volume to lay in from 2,800' KB to Surface while POOH, and freeze protect coil string at surface. 42: Sting out of the cement retainer with 14 bbls of cement remaining in the coil string. )3: Lay in cement from top of retainer to 5,390' KB. Ensure tubing is free of cement from 5,350' to 5,390', as a tubing punch will be shot at 5,350' KB K If pressure is approaching max. pump pressure (specified by SL 13) as perfs squeeze off, unsting early, lay in cement to 5,390' KB, and clean out excess. ,t5. POOH and take retums from the CT x 3.5" Tubing Annulus to tanks. Continue to circulate Biozan for cleanup of residual cement, and Diesel for Freeze Protect of the 3.5" Tubing and the CT String. .Day Slick Line (potentially E -Line) / Little Red: onduct Sim Ops. Safety Meeting and Identify Hazards. Inspect Wellhead and Pad Condition to identify any pre existing conditions. Drift tubing with 2.78" GR (1.5' dummy tool string) and Tag TOC of first cement plug. 3. '"".',,=w- 4. If tubing drifted to 5,300' KB with the 2.78" GR, RU E -line to shoot the tubing holes © 5,350' KB. Skip to step #9. 5. If tubing did not drift to 2.78 ", use Slick Line as planned below to punch holes. 6. MIRU Slick line and PT Equipment. 7. RU and RIH with a braided line brush to locate Camco W Nipple © 5,331' KB, mark depth. Use this mark to correlate the tubing punch depth. 8. RIH with a time delayed 1 9/16" OD Halliburton Titan Tubing Punch. Punch holes in the 3.5" 9.3# L -80 tubing at 5,350' KB (approx. center of last 31.5 ft joint of 3.5" tubing, 19' below Camco W nipple profile). Ilow Tubing, IA, OA to equalize, then POOH. U LRS and pump 190 bbls of sea water through tubing holes to verify injectivity rate, and circulate one bottoms up. ,Pump 100 bbls of diesel down the tubing, jumper the IA and tubing with a short hose, and allow diesel to U -tube from the tubing to IA for freeze protect. If tubing drifted to 2.78 ", utilize E -line to set retainer at 5,300' KB. If tubing did not d ' to 2.78 ", an inflatable retainer will be set by Coil in the following steps. 1 . POOH, RDMO Pre oiD /lice IA I:11 TM; r•;it.1 x'60/ so /vso 15ntan 235() SD / y z5 FL 0,56 ?s: Eu. u - 2sOo /50 /y-s- 15 ". 44 7 ,/y7.51 D. 75 Bbs 1-0 toul TW 11/29/2011 • • Coiled Tubing: 1. RIH with Coiled Tubing, taking returns up the CT x Tubing annulus. 2. If E -line was able to set the mechanical retainer, RU stinger and RIH to retainer CO 5,300' KB, and skip to step 5. If mechanical retainer could not be set due to restrictions in tubing, continue with inflatable retainer setting below. ' 3. Tie into 11/14/1997 reference tubing details provided below, to improve depth correlation. Use a nipple profile locator to correlate depth off the 2.812" Camco W Nipple © Ni le 5,331' KB if available. 4. Set cement retainer at 5300' KB. 5. Close in the CT x Tubing annulus, and line up to circulate up the IA, through the 3.5" tubing holes at 5,350'. 6. Using Diesel, establish adequate circulation rate through holes for cementing. (Here we are trying to keep seawater out of the IA, to mitigate F.P diesel from fingering through the higher density seawater and up the IA during displacement) 7. RU Schlumberger Cement Equipment and PT Lines to 4.500 psi. Max 1 it by SI 13 8. Mix 6 bbls of cement; 4 bbls to be pumped through the retainer (into IA and tubing below), and 2 bbls of cement to be layed in on top of cement retainer. II s•, , .1 ( ;I•►nent through retainer; othc :rwuse I (j+..; ;;', +nn+1 t;ul al desired depth n ; �/ \ Cement Volume for Plug detailed below: 'l/ - Annular Volume = (5370'- 5250') *(0.02639 bb/ft) = 3.2 bbls � - Tubing Volume (below retainer) = (5390'- 5300') *(0.00869 bbls/ft) = 0.8 bbls - Tubing Volume (above retainer) = (5300' - 5070') *(0.00869 bbls/ft) = 2 bbls 9. See pump schedule below: a. 142 bbls of Diesel for IA Freeze Protect. (IA volume to tubing holes) b. 5 bbls Fresh Water Spacer c. 6 bbls of 15.8# Cement d. 5 bbls Fresh Water Spacer e. 45 bbls Biozan Gel f. Sufficient Diesel volume to lay in from 2,800' KB to Surface while POOH, and freeze protect coil string at surface. 10. Sting out of the cement retainer with 2 bbls of cement inside the coil, and lay in cement on top of the retainer to 5,070' KB. 11. Run back in slowly to clean out excess cement, and ensure a TOC in the tubing of 5,250' KB. 12. Continue to POOH and circulate Biozan, taking returns up the CT x 3.5" tubing annulus, cleaning out any cement stringers. 13. Spot Diesel for Freeze Protect of the 3.5" Tubing. 14. Freeze Protect CT String, RDMO. R � TW 11/29/2011 e*-ka Got 1 . 0 4 ii;) • � �} • . • r"-- Lam4-- Slick Line / Little Red: 1. WOC 24 hours. Notify AOGCC Inspector (659 -2714; 659 -3607 pager) of the timing of the post -cement plug tag and PT. 2. MIRU Slick Line Unit and PT Equipment. „ 3. RIH with .66a GR and drift tubing to PBTD. Dr∎ ft -car- a .17 J r O b / 4. RIH with bailer to tag top of cement. PEI 0 TU /7. /z //r : TOC C ,,25'D' 1i?t? P �!'� °ON`"�`�-�► 5. RU LRS and PT the cement plug to 2500 psi on the tubing. Hold for 30 minutes. rn" /4-00 hrs., Record Results. )y0/s' yap f ) ' 6. Perform MIT -IA to ; ' psi. Record Results. 7. Perform a drawdown test by bleeding down the tubing, IA, and OA, pressure to an open top tank. Tubing and IA should bleed down to 0 psi to prove P&A integrity. Record Results. 8. RDMO, Shut in Well, and handover to E -Line for Tubing Cut. E -line / Little Red: Z. 75 " re f C,,, f 1. RIH with the Halliburton 3.5° tubing. 2. Tie into 11/14/1997 reference tubing details provided below. 3. Cut the tubing at 5,081' KB (166' below the planned CTD kick off point). This cut will be located near the middle of the 9` joint of tubing below GLM #3. 4. POOH w/ E -line. 5. Pump 25 bbls of diesel down the tubing, taking returns up the IA. Record rates and pressures to verify a successful cut. 6. Jumper the IA and tubing with a short hose, and all 34r /2J3 /// tubing to IA for freeze protect. 7. Set BPV and Prepare site for the rig. ,4, r . /MT r z- ,- 82 Tc 3 r 8. Shut in Tubing /IA/OA and Notify the Wells Group o 9. Set BPV 24-1+-. W.0. G, is 01/02 . 6ii-u46 mac, 7v 2.78 o FM do ► c,.. rrE t. - b 715? CPI" 6 5ZSD',K13 . ON 6 /TLS o jA�t 7 D. G "2 SnMPii $k/ &w o 7731 T/34/ CM1' Ta ZSVPpsi (34 m•H. MIT) o 44i7 /A 7v /5 02 p a frr 30min, TW • • KUP 1E-24A ConocoPhillips :+ W . - - - sweatIMARNESSMOVVAAMPUM -. Alaska. Inc . 5017292065701 i I IINPROO 65 M r— T ,L'] •• sesr. NIPPLE 130 5/812008 L __ • . , . 7561.0 3252011 Rev Roman. TAG 1 r6r/n 127120 1 M.. (�y [. 1 , L 0 { .�-• -.-- �� 360 112.0 { A�mt��w(�y,,�� ^ .•AVGev.26- CONDUCTOR ® � _ bwo5,1 T.6 / PRODUCTION" 6.1Wi liatilia 6: LINER 3 112 2692 5.360.E ^ 5.1670 ... •• 5.30 L•60 DTC•AIOO Need ... COXDJCT01t ';i1 )��1 t...ew.Gt 4 1 ti ) un2 erlilr�51�161 ®:. Pf 3:" .- Vi . 1 . 7 r 7� " • - 7:11 a'�IIII,II � ���� Y �� i � { S ���� lll 6 ej� ��� . � ��rn+:� � lia1�51Y1511YGI uwittY.�� '. 17 .5 " - . A.MJ :.-'7717# dT ^ ivia s..erACe - 224 NM N © Ei[l ileL L�' hell EUEIROMOD GAS UM 2 Y;mw :•< - T "mow r�a�..:rr - • - " - Nrigga. ITS ITC L Lf31.J ElE M GAG 1177 f 132' VIII IIIfI �... i F ..1 - 11161 °"°.1 eat � 5, `t t.1 " .06 — 7 a .. • n ^ :. . -°—� 1 5.371 1 4555 0 .3 3752 SEAL *557 BAKER 9 . 2 1.22 LOCATOR SEAL ASWASL7 61117 SEALS xe carol[, e.u• li k 11 ®iii®siii 1E -2571 _ ��� Kill .. d.K 77• ®lliiiIiiiii iii ]7 7 7 77 .. I � iiiiiiiiii iiiiii .• •66"5. ''"'"G Iliiilliiiliiiiiiiiiiiiiilliiiiilliiiiittliiiiiiiiiiiill i i i Wig .,, . INL AiLE27 I . �Ii�GW riiil r 1 i .,, , , w •_ 1U2412005 NOTE: WAVERED WELL. NA >r OA COMMUNICATION APMP, - - 412712010 NOTE: MAY SeMlneee *1 Araks Sdism.5c$O , 343-7133 NMI +x0-7113 3 4110 , 4;3 . --..-- 110 , 3424 .432 3404 373 AMU , 1167 3 1 r ...:.:a. -;, :� ..-..11 .,: >; 4 ©G'_"iu'1� ®PI w../ ® 5... ®�HM I6.6.. PI ' t ' 11 111119 i iL igiarg1616.11116i i1111111M1a41i11fWl111•Iri�L'iiJit iii iial•Il fi d111 i 1:6•r'a11111 uJ:Ji 116SMiiiiii1 illdri141raaiaOM /3,oeL ILI�� ;-TI11111�26 1F3III Z �fa i(i � a�♦Gr� =s� 14 I= I II 6�1O111 1iYtl11I Y6Y1r11rY1Y11� 605 IIIIII i IIIMI aM L sxoe,n— ta 1/17.0 TW 11/29/2011 • • 1 E -24A Pre -Rig Sidetrack Plug & Abandonment gerradgemebilea Procos.d Pr -ST P&A J.,......L 2.812' Campo DS Nipple � 10 % 45.5# K -55 Casing 4 GLVs 4 DV's 2,610' I 2.610' 3,927' 3,927' 4,807' 4,807' 5,288' 5.288' Est. ST KOP +1- 4915' RKB I Tbg Cut at -5081' RKB 31/2" 9.3# L-80 Tubing TOC at -5250' RKB Second Cement Retainer d' 5.300' 2.812" Carnes W fipple Tubing Niles Shot 0 5.350' . Baker ZXP Packer 5.370' RKB First Cement Retainer 0 7.000' Al II. T 2611 K-55 Prod. Casing 0 7,395' RKB Sand Pads: 7,341E- 7,550' RKB A Sand Peds: 7,818' - 7,900' RKB t ill: :i:T: Last Fib Tag 0 7,861' RKB TD 0 8,167' RKB TW 11 -07 -11 TW 11/29/2011 • rivaling 1E -24B SIDETRACK 3 , A" TRMAXX -CMT safety valve 2.813" 1D at 1,895' MD TVD Topset 5 - / Liner 10!0' 45.5# K -55 r 41 2,398' MD 1 2.398' TVD Sidetrack KOP 13 :08 6 .1.1 t .:r Vahx Type out window 1 KB02.9 32 Dummy s : �, 4.915' MD 2 KBG2-9 Dummy 3 3030,-9 Dummy 4 KBG2 -9 1 fir, tiding Sleeve ,558' SOV 3-"," 9.3 #, L -80. IBTM w' 3.865" O.D. Special Clearance couplings C amp cmt retailer �...... .. .� it 5.000' MD TOC on +1_ 4.900' MD (above finer top) Squeeze perfs below retainer 3 !," CM1J Sliding Sleeve w' 2.813" DS Profile (closed positron) ?, 6.100' MD 1 5.700' TVD 3 !":" HES "X" selective 3 liner Seal nipple w. 2.813" 'R 6.123' Assembly MD 15,720' TVD 5.371' NW 3 -' i' TOL 5.360' MD 3 -1 z 5 -112" Liner Hanger & Packer 6.200' MD : 5.785' TVD lkrfs 5 -1/2" Hydril 563. 15.5* P d 1 7.344' — 7.. 900' set 6,400' MD ! 5.952' T4D 3 -1 2" 9.3* L -80 3 -1 %2" Hydril 511.9.3* liner 6.167' MD 6.443' TVD set d 6.966' MD ' 6.427' TVD DAN 1026/11 TW 11/29/2011 • • TUBING DETAIL Well: 1E - 24A KRU ARCO Alaska, Inc. DATE: 11/14/97 subsidiary of Atlantic Ft lehliski Company 1 OF 1 PAGES 1 ITEMS COMPLETE DESCRIPTION OF EQUIPMENT RUN 1 LENGTH DEPTH TOPS RIM TO LCKIKDOWNISCREWS, NORDIC 25.80 3 -112" FMC Gen Iii 5000 psltubing hanger w/ 3 -1/2" EUE 8 rd pup 4.04 25.80 3 -1/2", 9.31 L-80 EUE 8rd Mod tubing Pups (10.15',10.15",4.04') 24.34 29.84 15jts 3-1/2". 9.31 L -80 EUE 8rd Mod tubin - 464.91 54.18 3-3-1/2" Camco 'DS' landing nipple w/ 2.812" No -GO profile .96 519.09 64jts 3 -1/2 ", 9.31 L -80 EUE 8rd Mod tubing 2089.95 520.05 GLM 3 -1/2" x 1" McMurry'FMHO' Mandral 6.57 2610.00 42jts 3 -1/2", 9.31 L -80 EUE 8rd Mod tubing , 1310.44 2616.57 GLM 3 -1/2" x 1" McMurry'FMHO' Mandral 6.57 3927.01 28jts 3 -1/2 ", 9.31 L -80 EUE 8rd Mod tubing 873.56 3833.58 GLM 3 -1/2" x 1" McMurry'FMHO' Mandral 6.57 4807.14 15jts 3 -1/2", 9.31 L -80 EUE 8rd Mod tubing 468.07 4813.71 3.1/2", 9.31 1-80 EUE 8rd Mod tubino Pup 8.08 5281.78 GLM 3.1/2" x 1 -1/2" Camco 'MMM' mandral w/ DV and PK latch 8.49 5287.86 3 -1/2", 9.31 L-80 EUE 8rd Mod tubing Pup 5.58 5296.35 1jt 3 -1/2 ", 9.31 1-80 EUE 8rd Mod tubing 29.56 5301.93 3- 3.1/2' Cameo W' landing nipple w/ 2.812" Selective profile 1.92 5331.49 lit 3.1/2 ", 9.31 L -80 EUE 8rd Mod tubing 31.54 5333.41 3 -1/2 ", 9.31 L -80 EUE 8rd Mod tubing Pup 6.17 5364.95 3-1/2" Baker 'GBH -22' locator seal assy 25.83 5371.12 String Weights with Blocks: 50K# Up, 4010 Dn, 6K1 Blocks. Ran 189 joints of tubing. Remarks: Drifted tubing, GLMs, 8 hanger with 2.867" plastic rabbit. Used Arctic Grade API Modified No Lead thread compound on all connections. Tubing is non- coated, Nordic Rig 12 DriNinD S tor: R. W. r TW 11/29/2011 • • I ' % SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Tyson Wiese Wells Engineer ( $ 1/ ConocoPhillips Alaska, Inc. ` I P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E -24A Sundry Number: 311 -358 lid r 0 ZUdE Dear Mr. Wiese: ':,;r',"„s` 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, k g. A � ' Daniel T. Seamount, Jr. Chair DATED this Ita Y of November, 2011. Encl. • EIt �, � • TATE OF ALASKA „� ALASKA OIL AN S CONSERVATION COMMISSION 1l 1 i % . . APPLICATION OR SUNDRY APP OVALS it 20 AAC 25.280 k-14.7` i i & GI Cans. Cvt ini$ t 1. Type of Request: Abandon / %! � +)( it' Plug for Redrill Perf orate New Pool f Re well � ange Ap proved Program r Suspend ! - t Rug Perforations r Perforate r Pull Tubing r Antlittbigens ion Operational Shutdow n r Re -enter Susp. Well r Stimulate r Alter casing r Other: r 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development , Exploratory r 197 -187 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50- 029 - 20857 -01 .. 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 r No J 1E -24A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADL 25651 • 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): 8167 • 6443 • 8070' 6399' Casing Length Size MD TVD Burst Collapse CONDUCTOR 77 16 112' 112' SURFACE 4731 10.75 2398' 2398' PRODUCTION 7363 7 7395' 6101' LINER 2807 3.5 8167' 6443' Perforation Depth MD 7344' - 7390', 7400' - 7420', Perforation Depth TVD (ft): 6076 -6099, 6103 -6113, Tubing Size: Tubing Grade: Tubing MD (ft): 7430 -7440, 7442 -7452, 7460 -7470, 7520 -7550, 6118 -6122, 6123 -6128, 6132 -6136, 6159 -6173, 7818- 7840, 7880 -7900 6291 -6301, 6319 -6327 3.5 L -80 5397 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER 'C -2 ZXP' MECHANICAL ISOLATION PKR MD= 5370 TVD= 4995 NIPPLE - CAMCO DS LANDING NIPPLE MD= 519 TVD= 519 12. Attachments: Description Summary of Roposal jr 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch r Exploratory r Development Service r 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: i _ 11/23/2011 Oil r Gas r WDSPL r Suspended r , iL » 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Tyson Wiese @ 263 -4250 Printed Name Tyson Wiese Title: Wells Engineer Signature r Phone: 263 -4250 Date t1 1 5 —' }b\\ \ / Commission Use Only Sundry Number:31 1- ?-);)- Conditions of approval: Notify Commission so that a representative may witness Plug Integrity r BOP Test lic Mechanical Integrity Test r Location Clearance r Other: 500 S �, cu �-ct Q k,C ...., Q Subsequent Form Required: \0‘—‘ � � t \ � \ ,� \1 9 n APPROVED BY Approved b /41, 4J 4 ' I '' n a! COMMISSIONER THE COMMISSION Date: 1 V\ 11 Form 10 -403 Revised 1/2010 S',,� ttl'At NOV Z 1 1,v1� Submit in Duplicate '`,.� 1 f/, ,, • • 1E-24A Pre Rig ST P &A Permit to Drill #: 197 -187 The objective of the proposed 1 E -24A P &A is to prepare the well for a Rotary Sidetrack, .� followed by Coiled Tubing drilled laterals. Proposed P &A: Slick Line: 1. Bleed down IA and OA pressure to 0 psi. 2. Replace OV and GLV's with Dummy Valves. Coiled Tubing: 1. MIRU CTU and PT Equipment. Notify AOGCC Inspector (659 -2714; pager 659- 3607) of date and time of the P&A operation. 2. RIH and set Retainer @ 7,000' KB. u 3. Mix and Pump 26 bbls of 15.8 ppg cement to be squeezed into the perforations from 7,344' — 7,900', as well as fill the 3.5" tubing above the retainer from 7,000' - 5,390'. Slick Line: 1. RIH with tubing punch and punch holes in the 3.5" tubing at 5,350' RKB. Coiled Tubing: 1. Set cement retainer at 5300' RKB. f 2. Mix 6 bbls of cement; 4 bbls to be circulated into the IA through tubing holes at 5,350', and 2 bbls of cement to be layed in on top of cement retainer. 3. Ensure a TOC in the tubing of 5,250' KB. Slick Line / Little Red: 1. WOC 24 hours. Notify AOGCC Inspector (659 -2714; 659 -3607 pager) of the timing of the post- cement plug tag and PT. 2. RIH with bailer to tag top of cement. 3. RU LRS and PT the cement plug to 2500 psi on the tubing. Hold for 30 minutes. Record Data 4. Perform MIT -IA to 1400 psi. Hold for 30 minutes. Record Data. 5. Perform a drawdown test by bleeding down the tubing, IA, and OA. E -line / Little Red: 1. Cut the tubing at 5,081' (166' below the planned CTD kick off point). 2. Circulate diesel through tubing cut to surface as freeze protect for Doyon 141 RWO. 3. Set BPV and Prepare site for the rig. Prof*d efe ca p w- leg/ r ' a frab%7q / ! e°r�v►/oy�ePr��` -- �� 'he pliyy, 49erith* nee re CO T\f Y ' e mcc f � fef / j , 11/15/2011 • • 1 E -24B Rotary Sidetrack Program Outline (up to window cutting) 1. Move Doyon 141 on 1'E -24 and rig up. 2. Pull BPV and VR plugs. Record tubing, IA, and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low / 3,500 psi high. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 3 -1/2" completion. 5. Run 7" casing scraper to +/- 5,100' MD. 6. Rig up E -line and run gyro /caliper in 7" casing to evaluate for subsidence related issues. 7. Using E -line, perforate 7" casing from +/- 5,010' MD for cement squeeze. 8. With E -line set 7" cement retainer bottom at +/- 5,000' MD. 9. With 5" drill pipe squeeze cement (450') into perforations to assist with kickoff and LOT. 10. Test 7" casing and cement retainer to 3,500 psi, chart for 15 minutes. (Per request of AOGCC) 11. Nipple down BOP stack and tubing head using Hydra -tight system. Pull 7" packoff and expect casing growth. 12. Run 7" casing spear and engage 7" casing with overpull. Cut excess casing and reset slips with casing in tension. 13. Install 7" packoff, nipple up tubing head and BOP stack. Retest same. 14. Test 7" casing and retainer to 3,500 psi, chart for 15 minutes. This will be used as a baseline for the FIT /LOT. 15. Pick up 7" whipstock/milling assembly. Run in hole and displace casing to milling fluid. 16. Set whipstock and mill window in 7" plus 20' of new formation for FIT /LOT. TW 11/15/2011 0 0 1 E -24A Pre-Rig Sidetrack Plug & Abandonment Current Completion Proposed Pre-ST P&A Ai 2 817 Canes DS kfippile 10 14" 45.6# K-55 Casing moo- 4 GLV's 4 DV's 2,610' Z810" 3,92T 3,92T 4,807' 4,80T 5,288' MD 5,288 st. ' E ST KOP -irt- 4915' RKB Tbg Cut at -5081' RKB 3 112" 9.30 L-: 'Tubing IMO TOC at -5250 RKB , 11111 - Second Cement Retainer i§t 5,300' i4 4 11; 2.817 Camco W Nipple Tubing Holes Shot @ 5 350' Baker ZXP Packer 5,370' RKB .22 . gt mmammu 4 First Cement Retainer 44 7,000' --, T 26rit K-56 Pirod. Casing C Sand Perfs: -i 7,344" - 7,550' RKB 1 , ---- A Sand Perfs: 7,818' - 7,900" RKB Last Fill Tag @ 7,861' R.1 TO @ 8,167" RKB TW 11-07-11 TW 11/15/2011 t ti, 11,1P • 1E-24A 1 �1 �3P 0CSS S ∎ ". 5 0 enAPII W I ; KUd NOne RIVER UNIT PROD c 89 Angle MD(f &MD S TD Well Attributes Max � . Wllbore APIIUWI Fold Name W ell Status Inc MD (ftKB) Act Btrn (ftKB) 7,795.51 8,167.0 Gorla - C m ! H25 (ppm) Date Annotation I End Date KB -Grd (ft) Rig Release Date S°ldl COpfi - l 112 239 PM SSSV NIPPLE 130 8/6/2009 'Last WO 3230 12113/1982 rhema11C'.Ausrgt .r, ,m __ Annotation Depth (ftKB) End Date Annotation Last Mod ... End Date Last Tag: SLM 7,861.0 3/25,'2011 Rev Reason TAG ninam 3/27/2011 Casing Strings Casing Description Sting 0... 'String ID Top (ftKB) ,Set Depth (f.. ISet Depth (TVD) String Wt... String .. String Top Thrd HANGER, 28 - , - ;''. ""'' CONDUCTOR 16 15.062 350 ' 1120 112.0 65.00 H - 40 WELDED Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD)... String Wt... String ... String Top Thrd SURFACE 103/4 9.794 317 2398.2 2,398.2 45.50 K - 55 BTC Casing Description String 0... ;String ID ... Top (ft(B) Set Depth (E.. Sat Depth (TVD) ... String WI... String ... String Top Thrd PRODUCTION 7 6.151 31 9 7,394.6 6,100.7 26.00 K BTC Cooing Description String .. String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) St g Wt St ng ... String Top Thrd LINER 3 1, 0. 2 992 5 360 4 8 167 0 9 30 L 80 BTC -MOD Liner Details Top Depth (TVD) Top Inc! I Nomi... CONDUCTOR, 12 _ _ Top (ftKB) ( B) (°) dem Description Comment ID (in) 35 -1 _.. ...__ 5,360.4 4,987.9 37.89 SLEEVE [BAKER HR SETTING SLEEVE 4.187 NIPPLE, 519 -- ° 5,370.4 4,995.7 37.83 PACKER BAKER C -2 ZXP MECHANICAL ISOLATION PACKER 5.000 5,3742 4,998.7 37.80 HANGER BAKER HMC HYDRAULIC LINER HANGER 5.000 5,381 0 5 004.1 37.76 SBE BAKER 80 -40 SEAL BORE EXTENSION w/ XO TO 3 112 ETC -MOD 2.992 SURFACE, ' Tubing Strings 32 -2,398 Tubing Description String 0... String ID ... Top (ftKB) I Set Depth (f... Set Depth (T80) 'String Wt.. String I String Top Thrd TUBING 3 1/2 2.992 25 8 5,396.9 5,017.5 I 9 30 I L-80 EUE8RDMOD D S 1 F j Completion Details 2.810 ;. _... _._ Top Depth (ND) Top Incl Mend... GAS LIFT, ___ T PoCB (RKB) _._. ( °) Kem Description Comment ID (in) 3.927 25.8 25.8 2 97 HANGER FMC GEN III 5000 HANGER 3.500 ,._, z 519.1 519.1 1.49 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 GAS LIFT. _ 4,887 5,331.5 4,965.1 38.08 NIPPLE CAMCO W LANDING NIPPLE 2.812 5371.1 4,996.3 37.82 SEAL ASSY BAKER GBH -22 LOCATOR SEAL ASSEMBLY w/ 10' SEALS 3.000 Perforations & Slots GAS 52 _"-- r Der —._ Shot Top (TVD) Btm (TVD) Dens I T Jell) fin. Kam.. (ttKB) (RKB) Zone Del. (sh... Type Comment 7,344 7,360 6,076.4 6,084.1 C-4, 1E -24A 8/26/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random orient 7,360 7,390 6,084.1 6,098.6 C4, 1E -24A 2/24/2000 4.0 APERF 2 1/2" HC, 180 deg phasing. 90 deg orient 7,400 7,420 6,103.3 6,112.8 C4, 1E -24A 1/25/2000 4.0 APERF 2 1/2" HC, 180 deg phasing, 90 deg va orient C` 7,430 7,440 6,117.5 6,122.2 C-4, C-3, 1E -24A 8/26/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random orient 7,442 7.452 6,123.1 6,127.8 C-3, 1E-24A 7/13/1998 4.0 IPERF 180 deg phasing, 90 deg orient, 2 - 1/2" HC SEAL ASSY, 5,371 7,460 7,470 6,131.5 6,136.2 C 1E - 24A 8/26/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random __ - _ -- orient ' '7,520 7,550 6,159.3 6,173.2 C- 2,C -1, 1E -24A 8/25/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random orient 7,818 7,840 6,291.3 6,301.1 A -5, 1E -24A 8/25/2004 6.0 APERF 2" HSD Guns, 60 deg phase, random - orient 7,880 7,900 6,318_7 6,327.4 A-4, 1E -24A 11/28/1997 4.0 IPERF 180 deg. phasing, 2" Hollow Carrier Notes: General & Safety I, End Date I Annotation 11/24/2004 NOTE: WAIVERED WELL IA x OA COMMUNICA I ION APERF, , 8/27/2010 NOTE: View Schematic w/ Alaska Schematic9.0 7,344 -7,360 APERF, 7,360.7,390 PRODUCTION, — _. 32 -7,395 APERF,_ • 7,400 -7,420 APERF, -.. - 7,430 -7,440 IPERF, - - ^ T _ 7,442 -7,452 APERF,_, , 7,460.7.470 APERF, • 7520 -7,550 Mandrel Details Top Depth Top Port (TVD) Inc( OD Ve va Latch Size TRO Run AP Stn ftKB Top (ftKB) (ftKB) r) Make Model ('n) Seen Ty Type (in) (psi) Run Date Corn... 7,816 - 7,e4o 1 2,6100 2,6100 4.37 McMu... FMHO 1 GAS LIFT GLV BK 0.156 1,269. 01/2/2000 2 3,9270 3,821.2 36.25 McMu... FMHO 1 CAS LIFT GLV BK 0.188 1,309.0 1/212000 IPERF, 3 4,807.1 4,545.0 33.61 McMu... FMHO 1 GAS UFT OV BK 0.250 0.0 10/3/2006 7,680 - 7900 4 5,287.9 4,930 - 8 38.35 CAMCO MMM 1 1/2 GAS UFT OMY RK 0.000 0.0 9/24/2006 LINER, 5,368 -8,167 TD (1 E -24A), " 8,167 . . : • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, 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 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 accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE -D... 11/16/2011 II • WELL LOG TRANSMITTAL PRoAcrivE DiAynosric SERVICES, INC. To: AOGCC Christine Mahnken 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 (907) 659 -5102 RE : Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following : ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 MAY 3 2011 aog3( 1) Caliper Report 29-Mar-11 1E-24A 1 Report / EDE E[i0 1 2) APR 1 9 2011 Signed : 0......r Da ∎ ., . ,. {:. e' V- .0(07 T . Print Name: I e PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)245 -88952 C:\Documents and Settings\Diane Williams \Desktop \CPAI_Transmit.docx I . . Memory Multi- Finger Caliper MINN r 1 ap Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1E-24A Log Date: March 29, 2011 Field: Kuparuk Log No.: 8067207 ZX70 State: Alaska III Run No.: 1 API No.: 50- 029 - 20857 -01 Pipet Desc.: 3.5" 9.3 Ib. L -80 EUE 8RD MOD Top Log Intvll.: Surface Pipet Use: Tubing Bot. Log Intvll.: 5,397 Ft. (MD) I Pipe2 Desc.: 3.5" 9.3 Ib. L -80 BTC -MOD Pipe2 Use: Liner Top Log Intv11.: 5,397 Ft. (MD) Bot. Log Intvll.: 7,863 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection COMMENTS : This caliper data is correlated to SLB Jewelry Log GR/CCL Dated November 21, 1997. I This log was run to assess the condition of the tubing and liner with respect to corrosive and mechanical damage. I The caliper recordings indicate the 3.5" tubing and liner logged appears to be in good condition, with no significant wall penetrations, areas of cross - sectional wall loss recorded outside the perforation intervals. The caliper recordings indicate ovality in the perforation intervals from — 7,360' to — 7,450', restricting the I.D. to a I minimum of 2.16" in joint 236 (7,435'). The caliper recordings indicate deposits from — 7,640' to the bottom of the interval logged, and restrict the I.D. to a minimum of 2.41" in joint 251 (7,852'). A graph illustrating minimum recorded diameters on a joint-by-joint basis is included in this report. 1 The caliper recordings indicate slight buckling from — 5,000' to — 5,360'. This summary report is an interpretation of data provided by Halliburton Well Services. I 3.5" TUBING & LINER - MAXIMUM RECORDED WALL PENETRATIONS: No significant wall penetrations (> 18 %) are recorded outside the perforation intervals. I 3.5" TUBING & LINER - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS: No significant areas of cross - sectional wall Toss (> 7 %) are recorded outside the perforation intervals. 1 3.5" TUBING & LINER - MAXIMUM RECORDED ID RESTRICTIONS: Ovality in Perf. Intvl. Minimum I.D. = 2.16" Jt. 236 @ 7,435 Ft. (MD) I Heavy Deposits Deposits Minimum I.D. = 2.41" Jt. 251 @ 7,852 Ft. (MD) Minimum I.D. = 2.65" Jt. 247 @ 7,741 Ft. (MD) Deposits Minimum I.D. = 2.67" Jt. 246 @ 7,717 Ft. (MD) Deposits Minimum I.D. = 2.70" Jt. 252 @ 7,862 Ft. (MD) 1 1 Field Engineer: J. Conrad Analyst: HY. Yang Witness: J. Condio I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, Tx 77997 Phone: (281) or (888) 565-9085 Fax: (281) 565 -1369 E -mail: PDS ©memorylog.com Prudhoe Bay Field Office Phone: (907) 659 -2307 Fax: (907) 659 -2314 II I ,gq - /Cq 0093/ I • • Correlation of Recorded Damage to Borehole Profile I a Pipe 1 3.5 in (41.6' - 7863.1') Well: 1E-24A Field: Kuparuk I Company: Country: ConocoPhillips Alaska, Inc. USA Survey Date: March 29, 2011 I I ■ Approx. Tool Deviation ■ Approx. Borehole Profile 1 - 45 I 25 - 813 50 1593 I 75 _ 2369 GLM 1 I 100 J 3156 a G LM2 112 c 3937 c Z s a. o p GLM 3 1 50 4713 1 GEM 4 _ — �l 175 0 1111411\ 5557 ..411111111 200 6344 ' 225 A 7105 I 250 '''M 7803 252.1 7863 0 50 100 I Damage Profile (% wall) / Tool Deviation (degrees) I Bottom of Survey = 252.1 I 1 • • 1 Minimum Diameter Profile Well: 1 E -24A Survey Date: March 29, 2011 Field: Kuparuk Tool: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 inches Country: USA Tubing I.D.: 2.992 inches 1 Minimum Measured Diameters (In.) 1.69 1.94 2.19 2.44 2.69 2.94 1 0.1 5 13 1 20 28 36 ' 44 52 60 1 68 76 83 1 91 99 107 Cr 115 E 123 Z 130 1 138 146 153 1 161 167 170 1 178 186 194 1 202 210 218 1 226 234 242 1 250 1 1 I • • I J w PDS Report Overview Body Region Analysis I Well: 1E-24A Survey Date: March 29, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 1 Country: USA No. of Fingers: 24 Analyst: HY. Yang Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.3 ppf L -80 EUE 8RD MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins I 3.5 ins 9.3 ppf L -80 BTC -MOD 2.992 ins 3.5 ins 6.0 ins 6.0 ins 1 Penetration(% wall) Damage Profile (% wall) 3 00 Penetration body WM Metal loss body 0 50 100 250 0 — I 200 150 I 100 50 47 0 =_ I 0 to 20% 20 to 40% 40 to 85% over 85% GLM 1 Number of joints analysed (total = 259) 1 251 5 1 2 97 GLM 2 I Damage Configuration ( body) __ 40 147 y GLM 3 I 30 GLM 4 M 20 I 10 194 0 I Isolated General Line Other Hole / F Pitting Corrosion Corrosion Damage Pos. Hole 244 I Number of joints damaged (total = 38) 38 0 0 0 0 Bottom of Survey = 252.1 I 1 I I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Mod Well: 1 E -24A Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % I mss I.D. Comments (% wall) (Ins.) (Ins.) `% (Ins.) 0 50 100 I 0.1 42 0 0.03 11 0 2.90 Pup ■ 1 45 0 0.03 12 4 2.95 • ■ 1.1 74 0 0.02 9 0 2.91 Pup ■ 1.2 78 0 0.03 10 2 2.93 Pup • 1.3 88 0 0.03 11 4 2.94 Pup ■ I 2 98 0 0.03 11 3 2.94 • 3 129 0 0.03 11 3 2.95 ■ 4 161 0 0.02 9 2 2.94 • 5 192 0 0.03 11 3 2.93 • I 6 222 0 0.03 12 4 2.90 7 253 0 0.02 7 2 2.92 8 285 0 0.03 12 3 2.92 • 9 316 0 0.03 12 2 2.95 IN I 10 347 0 0.03 10 3 2.91 • 11 377 0 0.03 10 3 2.94 • ■ 12 408 0 0.03 10 3 2.89 • 13 440 0 0.03 12 2 2.95 • 14 471 0 0.02 9 3 2.94 • I 15 502 0 0.03 12 3 2.92 15.1 533 0 0 0 0 2.81 Comco DS Landing Nipple No Go 16 534 0 0.03 12 2 2.94 • 17 565 0 0.03 12 4 2.95 • I 18 596 0 0.03 11 2 2.93 • 19 627 0 0.03 11 2 2.93 ■ 20 658 0 0.02 9 2 2.93 21 689 0 0.02 7 2 2.90 I 22 721 0 0.02 9 2 2.92 ■ 23 752 0 0.03 10 3 2.94 • ■ 24 784 0 0.03 12 4 2.93 • 25 813 0 0.03 11 3 2.92 • I 26 844 0 0.02 9 3 2.94 • 27 875 0 0.03 11 3 2.92 • ■ 28 907 (} 0.03 12 5 2.92 II 29 938 () 0.03 11 2 2.94 IN 30 970 1) 0.03 12 2 2.91 • I 31 1001 0 0.03 12 2 2.92 ■ 32 1032 0 0.03 12 5 2.95 ■ 33 1064 0 0.03 10 2 2.94 • 34 1095 0 0.03 12 3 2.93 • I 35 1127 0 0.03 10 3 2.94 • 36 1158 0 0.03 10 2 2.94 ■ 37 1189 0 0.02 9 3 2.94 • 38 1221 0 0.02 8 2 2.90 I 39 1251 0 0.03 11 2 2.92 • 40 1282 0 0.03 12 4 2.93 • ■ 41 1314 0 0.03 12 3 2.93 • 42 1345 0 0.03 11 2 2.90 • 43 1376 0 0.03 12 3 2.91 ■ I 44 1407 0 0.03 11 4 2.92 Slight oval. 45 1439 0 0.02 9 2 2.93 I Penetration Body Metal Loss Body Page 1 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Mod Well: 1 E -24A Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) %, (Ins.) 0 50 100 I 46 1470 0 0.03 12 2 2.95 • 47 1501 0 0.03 11 3 2.92 • ■ 48 1533 0 0.03 11 4 2.93 • 49 1562 0 0.03 12 4 2.94 ■ 50 1593 0 0.03 12 2 2.94 • I 51 1624 0 0.03 11 2 2.92 • 52 1655 0 0.03 10 2 2.94 ■ 53 1686 0 0.03 1 1 2 2.95 • 54 1718 0 0.02 9 2 2.94 • I 55 1749 0 0.02 9 2 2.95 • 56 1780 0 0.03 11 2 2.90 ■ 57 1812 0 0.03 12 4 2.94 • 58 1843 0 0.03 11 4 2.94 • 1 59 1875 0 0.03 12 3 2.94 60 1906 0 0.02 9 3 2.93 61 1936 0 0.03 11 2 2.90 7 62 1968 0 0.02 9 4 2.89 I 63 1999 0 0.03 12 3 2.91 • 64 2028 0 0.03 11 3 2.93 • ■ 65 2059 0 0.03 11 4 2.94 66 2091 0 0.02 9 2 2.90 67 2122 0 0.03 12 5 2.93 I 68 2153 0 0.02 8 2 2.93 69 2185 0 0.03 11 4 2.93 • 70 2216 0 0.03 10 3 2.93 • 71 2245 0 0.03 12 3 2.93 • I 72 2276 0 0.03 11 4 2.93 • 73 2308 0 0.03 12 3 2.93 • ■ 74 2337 0 0.03 12 4 2.93 • 75 2369 0 0.03 11 3 2.92 ■ I 76 2400 0 0.03 11 2 2.89 77 2432 0 0.02 8 2 2.90 78 2462 0 0.03 10 2 2.94 7 79 2493 0 0.02 9 2 2.94 80 2525 0 0.03 13 3 2.96 Shallow Pitting. • I 81 2556 0 0.03 12 2 2.93 • 82 2586 0 0.03 11 4 2.88 • 82.1 2618 0 0 0 0 2.77 GLM 1 (Latch @ 7:30) 83 2627 0 0.04 14 5 2.94 Shallow Pitting. ■ I 84 2656 0 0.03 11 3 2.97 • 85 2687 0 0.03 10 3 2.94 • ■ 86 2718 0 0.03 11 2 2.90 • 87 2750 0 0.02 9 2 2.93 I 88 2781 0 0.03 12 3 2.96 • 89 2812 0 0.03 11 2 2.94 is 2844 0 0.03 11 3 2.94 ■ 91 2875 0 0.03 12 2 2.94 • 92 2906 0 0.03 12 3 2.90 • I 93 2938 0 0.03 12 2 2.92 • 94 2968 0 0.03 13 4 2.93 Shallow Pitting. ra Body I Metal Loss tion Body Page 2 Penet I I • 0 PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Mod Well: 1 E -24A Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % pset Body Loss I.D. Comments (% wall) (Iris.) (Ins.) % (Ins.) 0 50 100 ' 95 2999 0 0.03 11 3 2.92 Slight oval. • 96 3031 0 0.02 9 3 2.94 97 3061 0 0.02 8 3 2.92 98 3092 0 0.03 11 3 2.90 • 99 3124 0 0.03 11 3 2.89 • I 100 3156 O 0.03 12 3 2.92 Slight oval. • 101 3186 0 0.03 11 3 2.92 ■ 102 3218 0 0.03 11 4 2.93 • 103 3249 0 0.03 12 s 2.94 • I 104 3281 0 0.03 12 4 2.94 • 105 3312 0 0.04 15 3 2.91 Shallow Pitting. ■ 106 3344 0 0.04 14 4 2.94 Shallow Pitting. • 107 3375 0 0.04 14 6 2.86 Shallow Pitting. 1 I 108 3406 0 0.03 11 5 2.90 ■ 109 3437 0 0.04 15 3 2.92 Shallow Pitting. • ■ 110 3468 0 0.04 14 4 2.94 Shallow Pitting. ■ 111 3500 0 0.03 12 3 2.93 Shallow Pitting. • I 112 3531 0 0.03 11 3 2.94 • 113 3562 0 0.03 11 3 2.91 • ■ 114 3594 0 0.03 10 4 2.88 • 115 3624 0 0.03 12 3 2.88 ■ 116 3653 0 0.03 12 3 2.89 ■ I 117 3684 0 0.03 10 2 2.90 • 118 3716 0 0.03 10 3 2.88 ■ 119 3747 0 0.03 13 2 2.91 Shallow Pitting. • 120 3775 (1 0.03 11 2 2.93 ■ I 121 3807 0 0.04 15 3 2.90 Shallow Pitting. • 122 3837 O 0.04 16 2 2.93 Shallow Pitting. • ■ 123 3869 0 0.04 17 4 2.97 Shallow Pitting. • 124 3898 O 0.04 18 4 2.92 Shallow Pitting. 124.1 3929 0 0 0 0 2.84 GLM 2 (Latch @ 10:30) i I 125 3937 0 0.03 13 4 2.88 Shallow Pitting. • 126 3968 0 0.03 11 4 2.90 ■ 127 3999 0 0.03 10 2 2.90 • 128 4030 0 0.03 12 1 2.86 r• I 129 4062 0 0.03 10 2 2.86 r. 130 4093 0 0.03 12 4 2.89 ■ 131 4124 0 0.05 18 4 2.89 Shallow Pitting. ■ 132 4156 0 0.04 17 4 2.92 Shallow Pitting. ■ I 133 4184 0 0.04 16 3 2.94 Shallow Pitting. • 134 4216 0 0.03 11 4 2.90 Slight oval. ■ 135 4247 0 0.04 15 4 2.92 Shallow Pitting. • 136 4279 0 0.04 15 6 2.89 Shallow Pitting. ■ I 137 4309 0 0.04 15 7 2.88 Shallow Pitting. ■ 138 4338 0 0.03 12 2 2.86 Shallow Pitting. ■ 139 4369 0 0.04 16 6 2.81 Shallow Pitting. ■ 140 4401 0 0.03 12 3 2.92 Slight oval • 141 4432 0 0.04 17 5 2.93 Shallow Pitting. ■ I 142 4463 0 0.04 16 3 2.88 Shallow Pitting. • 143 4494 0 0.03 12 1 2.88 rat Body I Metal Loss ion Body Page 3 Penet I I I a • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Mod Well: 1 E -24A Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 144 4524 0 0.03 12 4 2.87 Slight oval. • 145 4555 0 0.04 15 5 2.86 Shallow Pitting. • 146 4587 0 0.04 14 5 2.93 Shallow Pitting. ■ 147 4618 0 0.03 1 1 2 2.90 Slight oval. • I 148 4650 0 0.03 11 4 2.89 Slight oval. • 149 4681 0 0.03 11 1 2.88 i• 150 4713 0 0.03 12 3 2.86 7 151 4745 0 0.02 9 3 2.91 152 4775 0 0.03 12 _ 4 2.89 152.1 4807 0 0 0 0 2.87 GLM 3 (Latch @ 11:00) 153 4816 0 0.03 10 4 2.88 ■ 154 4845 0 0.04 17 4 2.91 Shallow Pitting. • 155 4876 0 0.04 14 4 2.88 Shallow Pitting. ■ 156 4908 0 0.03 11 3 2.88 • 157 4938 0 0.03 12 2 2.88 ■ 158 4970 0 0.02 9 2 2.90 ■ 159 5001 0 0.02 9 2 2.89 Slight Buckling. • I 160 5031 0 0.04 17 4 2.84 Shallow Pitting. • 161 5064 0 0.03 13 2 2.85 Slight Buckling. Shallow Pitting. • 162 5094 () 0.03 11 4 2.90 ■ 163 5125 0 0.04 14 4 2.90 Slight Buckling. Shallow Pitting. • 164 5156 0 0.03 12 4 2.91 • I 165 5188 0 0.04 14 3 2.90 Shallow Pitting. • 166 5219 0 0.04 17 4 2.90 Slight Buckling. Shallow Pitting. ■ 167 5251 0 0.03 12 2 2.86 Slight Buckling. 167.1 5281 0 0.01 5 0 2.86 Pup I 167.2 5285 0 0 0 0 2.88 GLM 4 (Latch 12:00) 167.3 5296 0 0.03 12 1 2.89 Pup 168 5301 0 0.02 9 0 2.88 Slight Buckling. 168.1 5331 0 0 0 0 2.81 Comco W Landing Nipple I 169 5333 0 0.03 12 1 2.87 Slight Buckling. • 169.1 5364 0 0.03 11 1 2.88 Pup 169.2 5371 0 0 0 0 3.00 Baker GBH -22 Locator Seal Assembly 169.3 5381 0 0 0 0 2.83 Baker 80-40 SBE w/Cross-over to 3.5" BTC -MO I 170 5403 0 0.02 9 0 2.87 I 171 5431 0 0.02 8 3 2.92 172 5462 0 0.03 11 1 2.85 173 5494 0 0.02 8 1 2.89 174 5525 0 0.02 9 1 2.81 Slight oval. I 175 5557 0 0.02 7 0 2.90 176 5589 0 0.02 8 I 2.91 177 5622 0 0.03 11 I 2.80 Slight oval. • 178 5653 0 0.03 11 1 2.89 . I 179 5685 0 0.03 12 0 2.79 Slight oval. 180 5717 0 0.02 9 0 2.89 no • 181 5748 0 0.03 10 0 2.83 • 182 5780 0 0.03 11 1 2.89 I 183 5812 184 5843 0 0.03 12 4 2.92 0 0.01 4 0 2.83 185 5876 0 0.02 7 2 2.89 Penetration Body I Metal Loss Body Page 4 I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Mod Well: 1 E -24A Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments ( %wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 186 5907 0 0.03 13 I 2.89 Shallow Pitting. • 187 5939 0 0.03 11 O 2.81 ■ 188 5971 0 0.03 12 0 2.82 Slight oval. 189 6003 0 0.03 12 (1 2.81 Slight oval. 190 6034 0 0.02 7 1 2.87 I 191 6063 0 0.04 16 I 2.88 Shallow Pitting. ■ 192 6095 0 0.03 11 0 2.87 • 193 6127 0 0.03 10 1 2.89 • 194 6159 0 0.03 11 0 2.84 • 195 6189 (1 0.03 10 0 2.84 196 6221 0 0.02 7 0 2.84 197 6251 0 0.03 11 0 2.81 Slight oval. ■ 198 6282 0 0.03 12 1 2.80 Slight oval. I 199 6313 0 0.02 7 0 2.84 200 6344 0 0.03 11 1 2.87 201 6375 0 0.03 11 0 2.83 • 202 6406 0 0.03 10 1 2.84 IN I 203 6436 0 0.03 11 0 , 2.84 • 204 6466 0 0.03 11 0 2.84 205 6497 0 0.02 7 0 2.82 206 6528 0 0.02 9 0 2.86 2 207 6559 O 0.03 11 0 2.82 • I 208 6589 0 0.03 10 0 2.85 209 6619 O 0.02 9 0 2.85 210 6652 O 0.03 12 1 2.83 Slight oval. ■ 211 6683 0 0.03 10 0 2.78 Slight oval. IN I 212 6714 0 0.03 10 0 2.85 Slight oval. ■ 213 6744 0 0.03 12 1 2.81 Slight oval. el 214 6776 (1 0.03 11 1 2.89 ■ 215 6806 0 0.03 12 0 2.82 Slight oval. I 216 6837 0 0.02 9 1 2.88 217 6866 0 0.03 11 1 2.89 ■1 218 6898 0 0.02 9 0 2.85 ■: 219 6926 0 0.03 11 1 2.85 ■ 220 6956 0 0.03 10 0 2.85 I 221 6985 0 0.02 7 0 2.82 222 7016 0 0.02 9 0 2.81 223 7045 0 0.02 6 0 2.84 224 7075 0 0.02 7 0 2.87 I 225 7105 0 0.02 7 0 2.87 226 7132 0 0.03 10 1 2.82 227 7161 0 0.01 5 0 2.89 228 7188 0 0.03 10 0 2.84 ■ I 229 7218 0 0.03 11 1 2.87 230 7246 0 0.02 7 0 2.79 231 7275 0 0.03 11 0 2.83 232 7304 0 0.01 5 0 2.86 I 233 7332 0 0.08 30 3 2.85 Perforations. Slight oval. • 234 7361 0 0.23 92 6 2.70 Perforations. 235 7392 0 0.17 66 4 2.80 Perforations. Ovality. rat I Metal Loss ion Body Page 5 Penet I I • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.3 ppf L -80 EUE 8rd Mod Well: 1 E -24A Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: Country: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in USA Survey Date: March 29, 2011 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 236 7421 0 0.34 100 7 2.16 Perforations. Ovality. � 237 7451 0 0.06 22 1 2.85 Perforations. Slight oval. 238 7479 0 0.03 11 2 2.82 Slight oval. Slight oval. • 239 7511 0 0.07 26 1 2.85 Perforations. MI I 240 7539 0 0.09 35 2 2.90 Perforations. 241 7567 0 0.02 9 0 2.88 242 7596 0 0.01 4 0 2.88 I 243 7624 0 0.02 9 0 2.71 Deposits. 244 7656 0 0.03 10 0 2.81 Lt. Deposits. I 245 7671 0 0.01 5 0 2.83 Lt. Deposits. 246 7687 0 0.02 6 0 2.67 Deposits. 247 7718 0 0.02 9 0 2.65 Deposits. • 248 7745 0 0.02 6 0 2.84 Lt. Deposits. II 1 ' 249 7773 0 0.03 13 0 2.76 Shallow Pitting. Deposits. 250 7803 0 0.09 34 2 2.78 Perforations. Deposits. MINE 251 7831 0 0.05 19 1 2.41 Perforations. Heaw Deposits. IN MN 252 7858 0 0.03 11 0 2.70 Deposits. • I 252.1 7863 0 0 0 0 2.99 End of Tubing I Penetration Body Metal Loss Body I 1 I I I I I I Page 6 I I • • I PDS Report Cross Sections I Well: 1E-24A Kuparuk Survey Date: March 29, 2011 Field: Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 BTC -MOD Analyst: HY. Yang I I Cross Section for Joint 251 at depth 7851.580 ft Tool speed = 50 Nominal ID = 2.992 ' Nominal OD = 3.5 Remaining wall area = 98% Tool deviation = 62° 1 ib I 1 I I Minimum I.D. = 2.412 ins Heavy Deposits Minimum I.D. = 2.41 ins HIGH SIDE = UP I I I I I I • 0 I PDS Report Cross Sections I Well: 1E -24A Survey Date: March 29, 2011 Field: Kuparuk Tool Type: UW MFC 24 No. 10000429 (HAL) Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 I Tubing: 3.5 ins 9.3 ppf L -80 BTC -MOD Analyst: HY. Yang I I Cross Section for Joint 247 at depth 7741.330 ft Tool speed = 50 Nominal ID = 2.992 I Nominal ll 3.5 Remaining g wall wall arr ea = 99% Tool deviation = 64° I 1 I ! I 1 I I Minimum I.D. = 2.649 ins Deposits Minimum I.D. = 2.65 ins HIGH SIDE = UP I I I I I I i -----=\ a KUP Conoc 3Pf 11tI1p5 ( w Attributes Angle & MD TD IE -24A 'JAll6ore APCUAI ✓ 9014 taros eil then nu (tH Edit f') MD( B'. tut Dim (INK Edit � °` 500292085701 IKUPARUK RIVER UNIT (PROD 64.83 7,795.5 8,167 i .�oRi comment Edit H Dab L;irt Oonoh 1E l b IF (11t 65Grd ITO Rig Release Edit I ... 555V: NIPPLE 130 8!6/20 Last WO: 32.30 12/13/19 'ITS Annohilwt IDepth(tI1 ) ow Edit Artwhlbn La et Mod e; aid Date (Edit Last Tag: SLM 7,861.0 325 Rev Reason: TAG ninam 3/2712011 Casing Strings Oa 181g Darortpnon Se1ng00.. Sting ID... Top(ttKB) Set Depth it.. Set Depth (11/0... s31ng Wt.. String... String Top 11 I CONDUCTOR 16 15.062 35.0 112.0 112.0 65.00 1440 WELDED Casing Description Siring OD_ String ID... Top (1tHB) Set Depth (t.. Set Depth (lVD)... String Vol.. String... Sting Top 111 SURFACE 103/4 9.794 31.7 2,398.2 2,3982 45.50 K-55 BTC •A Slug Dannp0on sting OD.. String ID... Top (I NES) Set Depth It... Set Depth IUD)... 11ring Wt.. String... String Top 11I PRODUCTION 7 6.151 31.9 7,394.6 6,100.7 26.00 KS5 BTC � ling Description Siring OD.. sting ID... Top iftPBt Set Depth lt.. let Depth ITJD)... String Vol.. 181ng ... String Top ill LINER 312 2.992 5,360.4 8,167.0 930 L-80 BTC - D I Liner Details �' alit Top Depth Top iTJD1 Top ncl Nom l... itti-Bi ittk:el 1 Rem Dare4ptlon c_are m ant 101101 5,360.4 4,987.9 37.89 SLEEVE BAKER HR SETTING SLEEVE 4.187 5,370.4 4,995.7 37.83 PACKER BAKER C-2 MECHANICAL ISOLATION PACKER 5.000 I 5,374.2 4,998.7 37.80 HANGER BAKER HMC HYDRAULIC LINER HANGER 5.000 5,361.0 5,404.1 37.76 SBE BAKER 8040 SEAL BORE EXTENSION w / X0 TO312ETC-MOD 2.992 Tubing Strings Tubing ascription Oblong OD_ String 63... Top(dWn) Set Depth it_ Set depth (WO)... Sting Wt.. Sting ... Sting Top Edrt TUBING 3 2.992 25.8 5,397.0 5,017.5 930 LSD EUE8RD I Completion Details lEdit Top Depth Top i TJDI Top FM Mani... MI' itt00/ i'' mem Ceeenpllon comment ID(In) 25.8 25.8 2.97 HANGER FMC GEN 1115000 HANGER 3.500 519.1 519.1 1.49 NIPPLE CAMCO DS LANDING NIPPLE NO GO 2.812 I 5,331.5 4,965.1 38.08 NIPPLE CAMCO W LANDING NIPPLE 2.812 5,371.1 4,996.3 37.82 SEAL AS SY BAKER GBH-22 LOCATOR SEAL ASSEM BLYw110• SEALS 3.000 Perforations & Slots 1r4 . 0 toot I Dim Top iTsta Ott i_TJUO Deno Top fit! Bi ittk 81 irtHBi ittl:6i mane Cate isI1... T Camm ant 7,344.0 7,360.0 6,076.4 6,084.1 C4, 1E-24A 8262004 6.0 APERF 2 "HSD Guns, 60 deg phase. random orient 7,3600 7,390.0 6,084.1 6,0986 C-4, 1E-24A 2242000 4.0 APERF 212"HC, 180 deg phasing, 90 deg orient I 7,400.0 7,420.0 6,103.3 6,112.8 C4, 1E-24A 1252000 4.0 APERF 212 "HC, 180 deg phasing, 90 deg orient 7,430.0 7,440.0 6,117.5 6,122.2 C4, C3, 1 E-24A 8262004 6.0 APERF 2" HS Guns, 60 deg phase, random orient 7,442.0 7,452.0 6,123.1 6,127.8 C3, 1E-24A 7/1311998 4.0 IPERF 180 deg phasing, 90 deg orient, 2 1/2" I HC 7,460.0 7,470.0 6,131.5 6,136.2 C4, 1E-24A 8262004 6.0 APERF 2" HS Guns, 60 deg phase, random orient 7,520.0 7,550.0 6,159.3 6,1732 C- 2,C -1, 1E-24A 8252004 6.0 APERF 2 "HSD Guns, 60 deg phase, random orient I 7,818.0 7,840.0 6,291.3 6,301.1 A5, 1 E-24A 8252004 6.0 APERF 2" HS Guns. 60 deg phase, random aderd 7,880.0 7,900.0 6,318.7 6,327.4 A4 1 E-24A 11/28/1997 4.0 IPERF 180 deg. phasing, 2" Hollow Carrier Notes: General & Safety Edit Bed Cote Annoeeton I11124/2004 NOTE: WAIVEREDWELL: L4rr OA COMMUNICATION 8272010 NOTE: View Schematic wl Alaska Schematic9.0 I I I I Mandrel Details Edit Top Dept! Port Top 1T,D1 Top DD Lath size TRO Run i Sin itt4 D1 fit. Dl Yid i "i MOO Model hen} Ser•: 'salve Tye T ion) (pt) Run Date Com... I 2,610.0 2,610.0 4.37 MoM... FMHO 1 GAS LIFT GLV BK 0.156 1,269.0 122000 2 3,927.4 3,8212 3625 MeM... FMHO 1 GAS LIFT GLV BK 0.188 1,309.0 122000 3 4,807.1 4,545.0 33.61 IoM... FMHO 1 GAS LIFT OV BK 0.250 0.0 10/32006 ~~ ConocoF~illips a~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~o~~ ,~~~~-~ ~' gStt~St ~~° C11 ~~~'~~~ ~ ~~ ~(c~~8 19'1" ~g~A . e' a4- Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRin. Each of these wells was found to have a void in the conductor. These voids were filled with 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 November 25th 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6th, 7~', 8th 2010. 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, Perry Klem ConocoPhillips Well Integrity Projects Supervisor • ConocoPhillips Alaska Inc. Surtace Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16/10 1A. 1C. 1E PAD 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 bbis ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" Na 11" Na 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" n/a 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1C-03A 50029205350100 2070630 SF n/a 16" n/a 7.7 7/6/2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" n/a 4" Na 2.4 7/7/2010 1 E-06 50029204930000 1800780 12" n/a 12" Na 13.6 7/7/2010 1E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" n/a 1" n/a 1.7 7/7/2010 1E-21 50029208920000 1830020 3" n/a 3" n/a 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" Ma 2" Na 1.7 7!112010 1 E-25 50029208440000 1821700 3" Na 3" Na 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" Na 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" n/a 7" Na 2.5 7/8/2010 11/28/06 Sc~lIImbepgep NO. 4054 Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth NOV (J)) (\ i., ,/ zoO!) [1" Company: Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 I C] ':f- - I <ö7- <,' '¡"~',..., !'C,r~. i-, ~>,.,"'~.¡·~r , uvN"'~'" ,~--~. ,. \: t~¡ '-' Field: Kuparuk Well Job# Color Log Description Date BL CD 3B-13 11415652 PROD PROFILE WIDEFT 11/16/06 1 3&-07 11502019 SBHP SURVEY 11/19/06 1 3S~1 0 11502020 SBHP SURVEY 11/19/06 1 1E-24A 11502021 SBHP SURVEY 11/20/06 1 1 Y -23 11502022 PROD PROFILE WIDEFT 11/23/06 1 1H·17 11502023 SBHP SURVEY 11/24/06 1 1A-17 11502024 SBHP SURVEY 11/24/06 1 3G-09 11486082 SBHP SURVEY 11/25/06 1 3B-08 11486081 SBHP SURVEY 11/25/06 1 Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. ê -Jt- ~ . . Re: IE-24A (PTD 197-187) testing waiver ') ) Subject: Re: 1E-24A (PTD 197-187) testing waiver From: Thomas Maunder <tom - maunder@admin.state.ak.us> Date: Wed, 24 Nov 200407:53:37 -0900 To: "Spenceley, Neil" <Neil.K.Spenceley@conocophillips.com> CC: John D Hartz <jack_hartz@admin.state.ak.us> Neal, Your proposal is acceptable. The technique you propose to employ should provide reasonably accurate allocations for both wells. Keep us advised if there is a need to keep the wells twinned beyond January. Tom Maunder, PE AOGCC Spenceley, Neil wrote: Tom, I am sending you this email as a request for a waiver for the required well testing for the Kuparuk River Unit well 1 E-24A (PTD 197-187) for the months of December and January. We are currently pre-producing the 1 E-114 (PTD 204-171) West Sak well into the 1 E-24A flowline. We are planning on obtaining two single well tests per month for 1 E-114, this will require the shut-in of 1 E-24A for a portion of a day twice a month. In order to get a single well test of 1 E-24A we would have to shut-in 1 E-114 which would cause a significant loss in production and would be operationally difficult. It is anticipated that it would take approximately 3 days to return this well to stable production following a shut-in event. Since 1 E-24A makes approximately 500bopd we would like to avoid a long term shut-in. 1 E-24A's production would be commingled with 1 E-114 and continue to be allocated by its most recent welltest which was November 6, 2004 and by using its flowing tubing pressure to determine daily production. In summary the plan would be to obtain two single well tests per month from 1 E-114 and several combined well tests of 1 E-114 and 1 E-24A combined. This waiver is only required for December and January, 1 E-114 will then be rolled into a dedicated flowline. Please call me at 263-4906 if you have any questions. Thank-you. Neil Spenceley, P. Eng Drillsite Petroleum Engineer ConocoPhillips Alaska - Greater Kuparuk Area phone: (907) 263-4906 fax: (907) 265-1158 email: neiLk.spenceley@conocophillips.com SCANNED DEC 0 1 2004 1 of 1 11/30/20048:01 AM ,-- ~ Mike Mooney Wells Group Team Leader Drilling & Wells ConocÓPhilli ps P. O. Box 100360 Anchorage, AK 99510-0360 Phone: 907-263-4574 September 13, 2004 RECEIVED SEP 2 7 2004 Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 333 West ih Avenue Suite 100 Anchorage, Alaska 99501 Alaska Oil & Gas Cons. Commission Anchorage Subject: Report of Sundry Well Operations for 1 E-24A (APD'-# 197-187) Dear Commissioner: ConocoPhillips Alaska, Inc. submits the attached Report of Sundry Well Operations for the recent perforation operations on the Kuparuk well 1 E-24A. If you have any questions regarding this matter, please contact me at 263-4574. Sincerely, MJ~ M. Mooney Wells Group Team Leader CPAI Drilling and Wells MM/skad OR\G\NAL ~ ~ RECE~-~ '-'~ StP 2 ~ 2dU4 1. Operations Performed: Abandon D RepairWell D Plug Perforations D Stimulate D UII C\I .~ LOW. q,rr,"""S I ". ..J" ",.1 Alter Casing D Pull Tubing D Perforate New Pool D Waiver D T E . ~hofage Ime xtenslon Change Approved Program D Ope rat. ShutdownD Perforate 0 Re-enter Suspended Well D 2. Operator Name: 4. Current Well Status: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Development- 0 Exploratory D 197-187/ 3. Address: Stratigraphic D Service D 6. API Number: P. O. Box 100360, AnchoraQe, Alaska 50-029-20857-01 7. KB Elevation (ft): 9. Well Name and Number: RKB 99' 1 E-24A 8. Property Designation: 10. Field/Pool(s): ADL 25651, ALK 469 Kuparuk River Field / Kuparuk Oil Pool 11. Present Well Condition Summary: Total Depth measured 8167' feet true vertical 6443' feet Plugs (measured) Effective Depth measured 7892' feet Junk (measured) true vertical 6318' feet Casing Length Size MD TVD Burst Collapse Structural CONDUCTOR 112' 16" 112' 112' SUR. CASING 2299' 10-3/4" 2398' 2398' PROD. CASING 7296' 7" 7395' 6094' LINER 2807' 3-1/2" 8167' 6443' Perforation depth: Measured depth: 7360'-7390',7400'-7420',7442'-7452', 7880'-7900', 7460'-7470', 7430'-7440', 7344'-7360' true vertical depth: 6078'-6092',6097'-6106',6116'-6121', 6312'-6321', 6125'-6130', 6111'-6116', 6RE:'Ce IVE 0 Tubing (size, grade, and measured depth) 3-1/2. , L-80, 5371' MD. SEP 2 7 2004 Packers & sssv (type & measured depth) pkr= BAKER 'C-2 ZXP' MECHANICAL ISOLATION PKR pkr= 5370' Alaska Oil & .Gas ComL Commission Cameo 'DS' nipple = 519' 12. Stimulation or cement squeeze summary: -..8 Intervals treated (measured) n/a RBDMS SF L SEP27 7004 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Met Water-Bbl Casinn Pressure Tubinn Pressure Prior to well operation 394 1497 2163 -- 181 Subsequent to operation 1147 1645 2314 -- 222 14. Attachments 15. Well Class after proposed work: Copies of Logs and Surveys run - Exploratory D Development 0 Service D Daily Report of Well Operations _X 16. Well Status after proposed work: oil0 GasD WAGD GINJD WINJD WDSPLD 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Mike Mooney @ 263-4574 Printed Name Mike Mooney Title Wells Group Team leader Signature JJd M ß/JW{ Phone Date ~ J50f Pr,marpd ;.I"'~a;:Z AlIsún-Drak" ::>6.1-41'112 ( I~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS on Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only .-- ~. 1 E-24A Well Events Summary Date Summary 08/25/04 PERFORATING: SHUT IN WEll FOR PERFORATING. TAGGED BOTTOM AT 7878'. FIRED FIRST GUN ON THE INTERVAL 7818'-7840'. FIRED SECOND GUN ON THE INTERVAL 7220-7250'. All SHOTS FIRED, NO CHANGE IN WHP. WEll lEFT SHUT IN. 08/26/04 PERFORATED THE INTERVALS: 7460-7470, 7430-7440, 7344-7360 USING 2.00" HSD GUNS lOADED 6 SPF, 60 DEG PHASING, FIRED AT RANDOM ORIENTATION. All SHOTS FIRED. CORRELATED TO SWS JEWELRY lOG DATED 21 NOV 1997. TI-~ MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON-OR BEFORE J E P L MATE IA L U N D W E R TH IS M ARK E R STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pull tubing _ Alter casing _ Repair well _ 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 171' FSL, 226' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1375' FNL, 2514' FWL, Sec. 22, T11N, R10E, UM At effective depth At total depth 1434' FNL, 2453' FEL, Sec. 22, T11N, R10E, UM Perforate _X Other_ 5. Type of Well: Development __X Exploratory__ St ratig raph Service__ (asp's 550300, 5959763) (asp's 553053, 5958235) (asp's 553367, 5958178) 6. Datum elevation (DF or KB feet) RKB 99 feet 7. Unit or Property name Kuparuk Unit 8. Well number 1 E-24A 9. Permit number / approval number 197-187 10. APl number 50-029-20857-01 11. Field / Pool Kuparuk Oil Pool 12. Present well condition summary Total depth: measured true vertical 8167 feet 6443 feet Effective depth: measured 7883 feet true vertical 6313 feet Plugs (measured) Casing Length CONDUCTOR 112' SURF CASING 2299' PROD CASING 7296' LINER 28O7' Junk (measured) Size Cemented 16" 326 Sx AS II 10-3/4" 1400 Sx AS III, 250 AS I 7" 700 Sx G, 250 Sx AS I 3-1/2" 510 Sx Cl G Tagged PBTD (1/17/00) @ 7883' MD. Measured Depth TrueverticalDepth 112' 112' 2398' 2398' 7395' 6094' 8167' 6443' Perforation depth: measured 7360 - 7390'; 7400 - 7420'; 7442 - 7452'; 7880 - 7900' true vertical 6078 - 6092'; 6097 - 6106'; 6116 - 6121'; 6312 - 6321' RECEIVED F :B 1:5 2001 Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.3#, L-80 Tubing @ 5371' MD. ~,laska 0Il & Gas Con,~. Comn~i~io~ Anchorage BAKER 'C-2 ZXP' MECHANICAL ISOLATION PACKER @ 5370' MD. CAMCO 'DS' NIPPLE NO-GO @ 519' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. OiI-Bbl Prior to well operation 904 Subsequent to operation 862 Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 738 2135 917 2020 Casing Pressure - Tubing Pressure 153 172 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title: Date ~/~/ Prepared by John Peirce 265-6471 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 1E-24A PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED 1/17/00: Drifted & tagged fill w/dummy gun at 7883' MD. 1/25/00: MIRU & PT equipment, RIH w/perforating guns & shot 20' of perforations in the 'C4' sand as follows: Added perforations: 7400 - 7420' MD Used 2-1/2" Hollow carriers & shot the perfs at 4 spf at 180 degree phasing. POOH w/guns. RD. 2/24/00: MIRU & PT equipment. RIH w/perforating guns & shot 30' of perforations in the 'C4' sand as follows: Added perforations: 7360 - 7390' MD Used 2-1/2" Hollow carriers & shot the perfs at 4 spf at 180 degree phasing. POOH w/guns. RD. Returned the well to production & obtained a valid well test. MEMORANDUM TO: THRU: State of Alaska Alaska Oil and Gas Conservation Commission Julie Heusser, Chairman Tom Maunder, P. I. Supervisor DATE: January 4, 2001 FROM: Chuck Scheve; Petroleum Inspector SUBJECT: Safety Valve Tests Kuparuk River Unit 1E Pad Thursday, January 4, 2001' I traveled to the Kuparuk River Field and witnessed safety valve system testing on 1E Pad. As the attached AOGCC Safety Valve System Test Report indicates I witnessed the testing of 9 wells 18 components on 1E pad with 2 failures. The Pilot on well 1E-07 was frozen and the Surface Safety valve on well 1E-24A had a slow leak when pressure tested. A portable heater was brought to location and the above mentioned pilot was thawed out. I requested the portable heater remain on this well until repairs are made on the catalytic heater in the wellhouse. The failed safety valve will be serviced and retested when the grease crew becomes available Earnie Barndt conducted the teSting today; he demonstrated good test procedures and was a pleasure to work with. I also inspeCted the well houses on this pad while Witnessing SVS testing. All the welihouses were clean and the equipment appeared to be in good condition. Summary: I witnesSed the SVS testing at 1E Pad in the Kuparuk River Field. KRU 1E Pad, 9 Wells, 18 components, 2 failure, 11.1% failure rate 16 wellhouse inspections Attachment: SVS KRU 1E Pad 1-4-01 CS X Unclassified Confidential' Confidential (Unclassified if doc. removed ) SVS KRU 1E Pad 1-4-01 CS.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Operator Rep: Eamie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kupamk / KRU / 1E Pad Separator psi: LPS 85 HPS 1/4/01 Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE 1E-02 1800500 85 70 60 P P OIL iE-03 1800560 85 70 45 P P OIL i -0s 800s80 1E-06 1800780 1E-07 18008'00 85! 70 0 2 P OIL , 1E-10 1820360 1E-11 1820510 1E-12 1820600 1E-14 1820790 1E-18 1830160 85 70' 50 P P OIL 1E-19 1830170 1E-20 1830050 85 70 50 P P OIL 1E-21 1830020 1E-23 1821840 1E-24A 1971870 85 70 70! P 4 OIL ~E-26 1821660 1E,28 1821~80 . ' 1E-29 1821540 1E-31 1971380 85 70 65 P P OIL ~E-33. 1971510 1E-34 1971660 85 70 50 P P OIL 1E-36 1982130 85 70 60 P P OIL ,, Wells: 9 Components: Remarks: 18 Failures: 2 Failure Rate: 11.1%~39o Day Pilot on 1E-07 frozen. Portable heater placed on pilot until catalytic repaired Surface Safety on 1E-24A had slow leak, valve to be serviced and retested. 1/9/01 Page 1 of l SVS KRU 1E Pad 1-4-01 CS.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, ~..?--~ Commissioner DATE: July 22, 2000 THRU: Blair Wondzell, ~ SUBJECT: P. I. Supervisor FROM: John H Spaulding,/~ --'~. Petroleum Inspector SVS Tests Pads 1E & 2X Kuparuk River Unit Kuparuk River Field July 22, 2000: I traveled to Philips Alaska Inc.'s Kuparuk Field to witness the SVS Tests on 1E and 2X pads. The AOGCC form is attached for reference. As noted on the test reports a minimal amount of failures were observed (1 on each pad). Ernie Barndt the PAl representative and his helper did an excellent job of testing. SUMMARY: I witnessed the SVS tests on: PAl, KRU, 1E & 1X 1E - 8 wells, 16 components, 1 failure, 9 % failure rate, 12 well house insp. ~2X: ~ 10 :wells, 20 compnents, I failure, 5 % failure rate, 12 well house insp. Attachment: Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kuparuk/Kuparuk R. U./1 Separator psi: LPS 91 HPS 7/22/00 Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code CAS or CYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 1E-07 1800800 91 60 55 P P OIL 1E-10 1820360 1E-11 1820510 1E-12 1820600 SI 1E-14 1820790 1E-18 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60 48 P P OIL 1E-21 1830020 1 E-23 1821840 ~2~24~--:;i~}i i. 1971870 91 70 70 P P OIL 1E-26 1821660 SI 1E-28 1821580 SI 1E-29 1821540 SI 1E-31 1971380 91 70 70 P P OIL 1E-33 1971510 1E-34 1971660 91 70 70 P P OIL 1E-36 1982130 91 70 70 P P OIL Wells: 8 Components: 16 1 Failure Rate: 9.0% ~ 90 var Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru 1 e 7-22-00js.xls Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: Phillips Alaska Inc Operator Rep: E. Bamdt AOGCC Rep: John H. Spaulding Submitted By: John Spaulding Date: Field/Unit/Pad: Kuparuk/Kuparuk R./2X Separator psi: LPS 96 HPS 22-Jul Well Permit Separ Set L/P Test Test Test Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code GAS or C¥CI~ 2X-01 1830840 2X-02 1831030 2X-03 1831090 2X-04 1831180 3000 2000 2000 P P WAG 2X-05 1831070 3000 2000 2000 P 4 WAG 2X-06 1831100 3000 2000 2000 P P WAG 2X-07 1831130 3500 2000 2000 P P WAG 2X-08 1831140 2X-09 1841620 96 70 60 P P OIL '2X-10 18416301 96 70 65 P P OIL 2X- 11 1841640 96 60 - 60 P P OIL 2X- 12A 1951760 2X- 13 1841740 2X-14 1841750 2X-15 1841760 96 70 701 P P OIL 2X- 16 1841720 2X-17 1951710 96 601 50' P P OIL 2X-18 1951600 96 60 50 P P OIL 2X-19 1951750 Wells: 10 20 Failures: 1 Failure Rate: 5.0% ~ 9o oar Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls AOGCC Geological Materials Inventory TD ~ i~ PERMIT 97-187 ARCO Log 8192 DGR/EWR4-MD Data ~'~'~'SpERRY MPT/GR/EWR4 ~ 5360-8167 DGR/EWR4-TVD ~ 5005-6443 MWD SRVY ~SpERRY 5493.-8167. /- .~-407 Completion Date ] [' '~ ? / ~) Are dry ditch samples required? Daily well ops yes ~_.~qo And received? Was the well cored? yes ~ no Are tests required? yes - no Well is in compliance ~ Initial Sent Received 12/3/1997 12/3/1997 12/3/1997 12/3/1997 D 12/3/1997 12/3/1997 D 12/17/1997 12/24/1997 no Comments Analysis description received? Received? ....... - o Box Wednesday, October 13, 1999 Page 1 of 1 STATE OF ALASKA AI_~,,.,,,,A OIL AND GAS CONSERVATION COMMI~,.,.ON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Pull tubing Alter casing Stimulate X Plugging Perforate __ Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 171' FSL, 226' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1288' FNL, 2149' FWL, Sec. 22, T11N, R10E, UM At effective depth 1390' FNL, 2520' FEL, Sec. 22, T11N, R10E, UM At total depth 1 12. 6. Datum elevation (DF or KB) RKB 106 feet 7. Unit or Properly name Kuparuk River Unit 8. Well number 1 E-24A 9. Permit number/approval number 97-187 10. APl number 50-029-20857-01 11. Field/Pool Kuparuk River Field/Oil Pool 411' FNL, 2435' FEL, Sec. 22, T11N, R10E, UM Present well condition summary Total Depth: measured 81 6 7 feet true vertical 6442 feet Plugs (measured) None Effective depth: measured 8070 feet true vertical 6399 feet Junk (measured) None 13. 14. Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 2398' 1 0-3/4" 7395' 2817' measured 7880'-7900' true vertical 6312'-6321' 11 Cemented 326 Sx AS II 1400 Sx AS III & 250 Sx AS I 950 Sx CIG & AS I 510 Sx Class G Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 5371' Packers and SSSV (type and measured depth) Pkr: Baker C-2 XZP @ 5370'; None, nipple @ 511' Stimulation or cement squeeze summary Fracture stimulate "A" sand on 11/29/97. Intervals treated (measured) 7880'-79OO' Treatment description including volumes used and final pressure Measured depth True vertical depth 110' 110' 2428' 2427' 7425' 6736' 8167' 6442' Pumped 132.6 Mlbs of 20/40 and 12/18 ceramic proppant into the formation, fp was 7900 psi. Representative Daily Averag'e Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 1000 349 Subsequent to operation 3 3 6 447 11 971 157 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. · Signed ~~ Form 10- 8 Title Wells Superintendent Date SUBMIT IN DUPLICATE t · ARCO Alaska, Inc. KUPARUK RIVER UNIT '' WELL SERVICE REPORT ~ K1(E-24A(W4-6)) WELL JOB SCOPE JOB NUMBER 1E-24A FRAC, FRAC SUPPORT 1118971355.7 DATE DAILY WORK UNIT NUMBER 11/29/97 PUMP "A" SANDS REFRAC DAY ~DPERATION COMPLETE I SUCCESSFUL KEY PERSON SUPERVISOR 5 (~) Yes O NoI (~) Yes O No DS-GALLEGOS JOHNS ESTIMATE 998687 230DS 1 OEO $1 08,078 $156,717 Initial Tbq Press Final Tb.q Press Initial Inner Ann Final Inner Ann. Initial Outer Ann . Fina,F~ute, Ann 449 PSI 2000 PSI 1000 PSI 1000 PSII 150 PSI 600 PSI DAILY SUMMARY IPUMP INITIAL "A" SANDS FRAC, SCREENED OUT W/132588# PROPPANT TO 9# PPA 12/18 AT PERFS. LEFT 19888# PROPPANT IN I I PIPE. TIME LOG ENTRY 07:00 MIRU DOWELL FRAC EQUIP., LIq-I-LE RED PUMP AND APC VAC. TRUCK. 09:15 HELD PRE JOB SAFETY MEETING. 11:15 PRESSURE TEST TO 9164 PSI. 11:25 PUMP 24 BPM AT 8250, BREAKDOWN AT 30 BPM AND 5900# OF20/40 FOR SCOUR. SHUTDOWN AT 15 BPM AND 5419 PSI. ISIP 2613 PSI. PUMP PULSE TEST. 12:35 PUMP DATA FRAC. WITH 100 BBLS FLUIDS, 15 BPM AND 5089 PSI. 14:39 PUMP 15039# 20/40 PROPPANT AT 2 PPA, 15 BPM AND 5085 PSI. 14:49 PUMP 131389# OF 12/18 PROPPANT, INJECTING 111,000 # 12/18 IN PERFS, LEAVING 19,888# IN PERFS. 15:33 WELL PRESSURED OUT, 7900 PSI MAX. TREATING PRESSURE. SHUT DOWN AND RDM0. SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL $0.00 $20.00 · APC $7,000.00 $21,250.00 ARCO $350.00 $350.00 BAKER OIL TOOLS $0.00 $4,500.00 DIESEL $0.00 $250.00 ,= = DOWELL $98,528.00 $110,405.00 HAL.L!BURTON $0.00 $1,692.00 LI-I-I'LE RED ' $2,200.00 $2,200.00 SCHLUMBERGER $0.00 $16,050.O0 TOTAL FIELD ESTIMATE $1 08,078.00 $1 56,71 8.00 STATE OF ALASKA AL,-,,~KA OIL AND GAS CONSERVATION COMMIb,.,ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown Stimulate Pull tubing Alter casing Repair well 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service Location of well at surface 171' FSL, 226' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1288' FNL, 2149' FWL, Sec. 22, T11N, R10E, UM At effective depth 1390' FNL, 2520' FEL, Sec. 22, T11N, R10E, UM At total depth 1411' FNL, 2435' FEL, Sec. 22, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical Plugging Perforate X Other 6. Datum elevation (DF or KB) RKB 106 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-24A 9. Permit number/approval number 97-187 10. APl number 5o-029-20857-01 1 1. Field/Pool Kuparuk River Field/Oil Pool 81 67 feet Plugs (measured) None 6442 feet Effective depth: measured 8070 feet Junk (measured) None true vertical 6399 feet 13. Casing Length Size Cemented Structural Conductor 8 0' 1 6" 326 SX AS II Surface 2398' 1 0-3/4" 1400 Sx AS III & Intermediate 250 SX AS I Production 7395' 7" 950 Sx Cl G & AS I Liner 2 81 7' 3.5" 510 Sx Class G Perforation depth: measured 7880'-7900' true vertical 6312'-6321' Tubing (size, grade, and measured depth) 3.5", 9.3#/ft., L-80 @ 5371' Packers and SSSV (type and measured depth) Pkr: Baker C-2 XZP @ 5370'; None, nipple @ 511' Stimulation or cement squeeze summary Perforate "A" sand on 11/28/97. Intervals treated (measured) 7880'-7900' Treatment description including volumes used and final pressure 14. Measured depth True vertical depth 110' 110' 2428'. 2427' 7425' 6736' 8167' 6442' Perforated using 2 1/2" HC Guns w/BH charges @ 4 SPF, fp was 449 psi. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 0 0 0 175 349 Subsequent to operation 3 3 6 447 11 175 157 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations X 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed '~ Form 10-4 Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT -~' WELL SERVICE REPORT '~' K1(E-24A(W4-6)) WELL JOB SCOPE JOB NUMBER 1E-24A PERFORATE, pERF SUPPORT 1127971811.9 DATE DAILY WORK UNIT NUMBER 11/28/97 PERFORATE UNIT #1 DAY OPERATION COMPLETE SUCCESSFUL KEY PERSON 'SUPERVISOR 1 (~).Yes O No (~ Yes O No WEINS SCHUROSKY FIELD AFC~ CC~ DAILY COST AOOUM COST SigneC¢/? ESTIMATE 998687 230DS10EO $25,500 .. $25,500 Initial Tb_q Press Final Tbs! Press Initial Inner Ann Final Inner Ann } Initial Outer Anh ~/Final Outer Ann 0 PSI 0 PSI 175 PSI 175 PSII 0 PSII 0 PSI DALLY SUMMARY I PERFORATE 20', FROM 7880' TO 7900' WITH 2" HOLLOW CARRIER GUN, 4SPF 180 DEG. PHASE TIME LOG ENTRY 07:00 MIRU DOWELL COILTBG./E-LINE, SWS LOGGING UNT, HOLD TGSM 08:45 TEST E-LINE TOOLSTRING. 10:15 RIH WITH 2.5" X 20' HOLLOW CARRIER GUN, BIG HOLE, 4 SPF, 180 DEG PHASE. 11:45 TIE IN TO DEPTH / PRESSURE UP TUBING TO OVER BALANCE BY 100 PSI. 12:30 PLACE GUN TO SHOOT AT 7880' TO 7900', SHOT GUN, POOH. 14:00 AT SURFACE WITH TOOLS, GUN DID SHOOT, RDMO SERVICE COMPANY - SERVICE DAILY COST ACCUM TOTAL APC $2,500.00 $2,500.00 DOWELL $14,000.00 $14,000.00 , SCHLUMBERGER $9,000.00 $9,000.00 TOTAL FIELD ESTIMATE $25,500.00 $25,500.00 - -- STATE OF ALASKA ,~ ,~KA OIL AND GAS CONSERVATION COMI, ,;ION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown m Pull tubing Alter casing Stimulate Plugging Perforate X Repair well Other__ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 4. Location of well at surface 171' FSL, 226' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1288' FNL, 2149' FWL, Sec. 22, T11N, R10E, UM At effective depth 1390' FNL, 2520' FEL, Sec. 22, T11N, R10E, UM At total depth 1411' FNL, 2435' FEL, Sec. 22, T11N, R10E, UM 12. Present well condition summary Total Depth: measured true vertical '81 67 feet 6442 feet 6. Datum elevation (DF or KB) RKB 106 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-24A 9. Permit number/approval number 97-187 10. APl number 50-029-20857-01 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 8 0 7 0 true vertical 6399 feet feet Junk (measured) None Casing Structural Conductor Surface Intermediate Production Liner Perforation depth: Length Size 80' 16" 2398' 1 0-3/4" 7395' 7" 2817' 3.5" measured 7880'-7900' true vertical 6312'-6321' Tubing (size, grade, and measured depth) Cemented Measured depth True vertical depth 326 Sx AS II 1 1 0' 1400 Sx AS III & 2428 250 Sx AS I 950 Sx CIG & AS I 7425 510 Sx Class G 81 67 110' 2427' 6736' 6442' "" ;" ?;;7 L/ i - , . ~1 (-'- '-;/-!['.j ,..,;, 3.5", 9.3#/ft., L-80 @ 5371' Packers and SSSV (type and measured depth) Pkr: Baker C-2 XZP @ 5370'; None, nil3ple @ 511' 13. Stimulation or cement squeeze summary Perforate "A" sand on 11/28/97. i ~" ':-'i ..... ;, Intervals treated (measured) 7880'-79OO' Treatment description including volumes used and final pressure Perforated using 2 1/2" HC Guns w/BH charges @ 4 SPF, fl3 was 449 psi. 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure /~nChor~ge ~Ormn/s$io~ Tubing Pressure Prior to well operation 0 0 0 175 349 Subsequent to operation 3 3 6 447 11 175 157 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' _ °, Si~Ined ~ Form 10-4 Title Wells Superintendent Date SUBMIT IN DUPLICATE ARCO Alaska, Inc. KUPARUK RIVER UNIT .~. WELL SERVICE REPORT "~' K1(E-24A(W4-6)) w~.. ,o~ sco~ ,o~.~.' 1E-24A PERFORATE, PERF SUPPORT 1127971811.9 'DATE 'DAILY WORK uNI¢ NUMBER 11/28/97 PERFORATE UNIT #1 c,,,,,.,, b~'E~^T~O. CO~*~_ET~ ~ suCc~ss~u~ ~EV ~E.SO~ SU~E.V,SO. 1 ~ Yes O NoI ~ Yes O No WEINS .SCHUROSKY FIELD AF~ C~ DAILY COST ACCUM COST Sign~ ESTIMATE 998687 230DS 1 OEO $25,500 $25,500 0 PSI 0 PSI 175 PSI 175 PSIOn0 PSI 0 PSI DALLY SUMMARY PERFORATE 20', FROM 7880' TO 7900' WITH 2" HOLLOW CARRIER GUN, 4SPF 180 DEG. PHASE TIME LOG ENTRY 07:00 MIRU DOWELL COILTBG./E-LINE, SWS LOGGING UNT, HOLD TGSM 08:45 TEST E-LINE TOOLSTRING. 10:15 RIH WITH 2.5" X 20' HOLLOW CARRIER GUN, BIG HOLE, 4 SPF, 180 DEG PHASE. 11:45 TIE IN TO DEPTH / PRESSURE UP TUBING TO OVER BALANCE BY 100 PSI. 12:30 PLACE GUN TO SHOOT AT 7880' TO 7900', SHOT GUN, POOH. 14:00 AT SURFACE WITH TOOLS, GUN DID SHOOT, RDMO SERVICE COIV{PANY - SERVICE DAILY COST ACCUM TOTAL APC $2,500.00 $2,500.00 DOWELL $14,000.00 $14,000.00 SCHLUMBERGER $9,000.00 $9,000.00 TOTAL FIELD ESTIMATE $25,500.00 $25,500.00 'ARCO Alaska, Inc. Post Office Box 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 January 7, 1998 Mr. David J. Johnston Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: 1E-24A (Permit No. 97-187,397-170) Well Completion Report Dear Mr. Commissioner: Enclosed is the well completion report for the completion on KRU 1E-24A. If there are any questions, please call 263-4622. Sincerely, W. S. Isaacson Drilling Engineer Kuparuk Development WSl/skad RECEIVE[) f~ Anchorage STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG I Status of Well Classification of Service Well OIL E~] GAS E~ SUSPENDED E~ ABANDONED~ SERVICE 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 97-187 & 397-170 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 9951O-0360 50-029-20857-01 4 Location of well at surface 1375' FNL, 2514' ~L, Sec. 22, T11N, R10E, UM ~.._~ ~ ~, 1E-24A At Total Depth ~,., .... ' :' ~ ~~ 11 Field and Pool 1434' FNL, 2453' FEL, Sec. 22, T11N, R10E, UM~'~~ KUPARUK RIVER 5 Elevation in feet (indicate KB, DF, etc.) ~ 6 Lease D~ignation and Sedal No. Kuparuk River Oil Pool Nordic RKB 99', Pad 67'~ ADL 25651 ALK 469 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp./~ ~°r Aband. 15 WaterNADepth, if offshorefeet MSL 16 No.1 of Completions 17 Total Depth (MD+~D) 18 Plug Back Depth (MD+~D) 19 Dire~ional Su~ey 20 Depth where SSSV set 21 Thickness of pe~afrost 8167' MD & 6442' ~D 8070' MD & 6399' ~D YES ~ NO ~ NA feet MD 1465' APPROX 22 Type Electdc or Other Logs Run 23 CASING, LINER AND CEMENTING RECORD SE~ING DEPTH MD CASING SIZE ~ GRADE TOP BTM HOLE SIZE CEMENT RECORD 16' 62.5~ H-40 SURF. 112' 24' 326 sx AS II 10.75' 45.5~ K-55 SURF. 2391' 13.5' 1400 sx AS III & 250 sx AS I 7' 26.0~ K-55 SURF. 5533' 8.75' 700 sx Class G & 250 sx AS I 3.5' 9.3~ L-80 5350' 8167' 6.125' 510 sx Class G 24 Pedorations open to Production (MD+~D of Top and BoSom and 25 TUBING RECORD inte~al, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3.5' 5371' 5371' 7880'-7900' MD 6312'-6321' ~D 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC 4 spf DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 7880'-7900' pumped 132,588~ proppant to 9~ ppa 1~18 at peals left 19,888~ proppant in pipe 27 PRODUCTION TEST Date First Production1 ~1/97 Method of OperationFiowing(FIowing, gas lift, etc.) Date of T~t Hours Tested PRODUCTION FOI OIL-BBL GAS-MCF WATER-BB[ CHOKE SIZE J GAS-OIL RATIO 1~97 12.10 TEST PERIOI: ~ 192 ]5 176~ 527 Flow Tubing Casing Pressure CALCU~TED OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 162 ] 3~ 24-HOUR RATE: 8] 8 431 30 24° 28 CORE DATA Brief description of lithology, porosi~, fractures, apparent dips and pr~ence of oil, gas or water. Submit core chips. Form 10-407 ~1~-~,~ /:;~ 8lu~ .~¢,.~.I~ d u plicate Rev. 7-1-80 CONIINUED ON REVERSE SIDE 29. 30. GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Kuparuk C 7340' 6068' Base Kuparuk C 7553' 6167' Top Kuparuk A 7803' 6278' Base Kuparuk A 8022' 6377' 31. LIST OF ATTACHMENTS Summary of Daily Drilling Reports, Survey 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Prepared by Name/Number Sharon AIIsup-Drake/263-4612 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and Icg on all types of lands and leases in Alaska. item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 Date: 12/4/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 1 WELL:lE-24A RIG:NORDIC WELL ID: AK8957 TYPE: -- AFC: AK8957 AFC EST/UL:$ 925M/ 1075M STATE:ALASKA AREA/CNTY: NORTH SLOPE EAST FIELD: KUPARUK RIVER UNIT BLOCK: SPUD:Il/05/97 START COMP: WI: 0% SECURITY:0 API NUMBER: 50-029-20857-01 FINAL: 11/14/97 11/02/97 (D1) TD: 7425' (7425) SUPV: DLW DAILY:$ 11/03/97 (D2) TD: 6494' ( SUPV: DLW o) DAILY:$ 11/04/97 (D3) TD: 5740' ( 0) SUPV:DLW DAILY:$ 11/05/97 (D4) TD: 5533' ( 0) SUPV:DLW DAILY:$ 11/06/97 (D5) TD: 5533 ' ( SUPV: DLW o) DAILY:$ 11/07/97 (D6) TD: 0' ( 0) SUPV: DLW DAILY: $ 11/08/97 (D7) TD: 6848' (6848) SUPV: DLW/MC DAILY:$ MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 SAFETY MEETING Turn key move well to well. Accept rig for operation @ 1900 hrs. 11/2/97. 20,170 CUM:$ 20,170 ETD:$ 0 EFC:$ 945,170 MW: 9.4 VISC: 50 PV/YP: 18/18 APIWL: 7.6 SWS RUNNING GAUGE RING Safety meeting. Pump kill fluid. Shut down well dead. N/D tree. N/U BOPE. Test BOPE to 250/3500 psi. Pull tubing to rig floor. 31,940 CUM:$ 52,110 ETD:$ 0 EFC:$ 977,110 MW: 9.4 VISC: 82 PV/YP: 37/51 APIWL: 5.2 CUTTING 7" SECTION @ 5555' Continue to pull tubing. RIH w/7" bridge plug and set @ 5740' Spot pill across 300' from 5740' to 6440' 44,110 CUM:$ 96,220 ETD:$ 0 EFC:$ 1,021,220 MW: 9.4 VISC: 95 PV/YP: 22/53 APIWL: 5.2 RIH W/OPEN ENDED DP Cutout @ 5533', mill section to 5568', pump sweeps, clean hole. Continue to mill section from 5568 to 5583' Work section mill attempt to pull into 7" casing stub. Jar free. Clean out BOPE and flowline. Iron recovered 1540 lbs. 52,882 CUM:$ 149,102 ETD:$ 0 EFC:$ 1,074,102 MW: 9.5 VISC: 59 PV/YP: 17/30 APIWL: 5.3 SLIDING OUT OF 7" SECTION Continue to clean metal cuttings from BOPE and flowline. Perform hesitation squeeze. TOC @ 5348' 92,587 CUM:$ 241,689 ETD:$ 0 EFC:$ 1,166,689 MW: 9.5 VISC: 59 PV/YP: 17/30 APIWL: 5.3 drilling 66,043 CUM:$ 307,732 ETD:$ 0 EFC:$ 1,232,732 MW: 9.7 VISC: 42 PV/YP: 13/16 APIWL: 4.8 DRILLING AHEAD Continue directional drilling 6.125" hole from 5990' to 6848' Spill containment. 52,011 C UM:$ 359,743 ETD:$ 0 EFC:$ 1,284,743 11/09/97 (D8) MW: 11.8 VISC: 48 PV/YP: 21/33 APIWL: 4.0 · TD: 7310' (462) SUPV: DLW/MC DAILY:$ DRILLzNG AHEAD Continue to clean up spill out side of containment. Continue drilling from 6848' to 7102' Perform FIT test to 13.0 ppg EMW. Drilling from 7102' to 7310' 71,594 CUM:$ 431,337 ETD:$ 0 EFC:$ 1,356,337 Date: 12/4/97 ARCO ALASKA INC. WELL SUMMARY REPORT Page: 2 11/lo/97 (D9) TD: 7915' (605) SUPV: DLW/MC DAILY: $ 11/11/97 (D10) TD: 8167' (252) SUPV: RS DAILY:$ 11/12/97 (Dll) TD: 8167' ( 0) SUPV: RS DAILY: $ 11/13/97 (D12) TD: 8167' ( 0) SUPV: RS DAILY: $ 11/14/97 (D13) TD: 8167' ( 0) SUPV: RS DAILY:$ MW: 12.0 VISC: 44 PV/YP: 21/23 APIWL: 4.0 DRILLING Continue directional drilling 6.125" from 7310' to 7340' Began to get connection gas. Raise mud weight from 11.8 to 12.1 ppg. Continue drilling from 7340' to 7576. Service rig #2 engine started broke unable to restart engine. Continue drilling from 7576' to 7915'. 55,362 CUM:$ 486,699 ETD:$ 0 EFC:$ 1,411,699 MW: 12.0 VISC: 45 PV/YP: 19/23 APIWL: 4.0 POH L/D DP, PREP F/LINER Continue drilling 6.125" hole from 7915' to 8167' POH, tight spot @ 6790' Pipe pulling free. Apparent shale or junk @ bit. 56,184 CUM:$ 542,883 ETD:$ 0 EFC:$ 1,467,883 MW: 12.0 VISC: 47 PV/YP: 18/21 APIWL: 3.8 PREPARING FOR COMPLETION Pump cement. Set packer. 54,592 CUM:$ 597,475 ETD:$ 0 EFC:$ 1,522,475 MW: 12.0 VISC: 47 PV/YP: 18/21 APIWL: 4.0 DISPLACING WELL TO SEAWATER Safety meeting. RIH w/3.5" tubing and jewelry. 129,875 CUM:$ 727,350 ETD:$ 0 EFC:$ 1,652,350 MW: 0.0 VISC: 0 PV/YP: 0/ 0 APIWL: 0.0 RIG WHEEL OFF ROAD Finish running completion tubing and jewelry. ND BOPE. NU tree. Test packoff to 5000 psi. Released rig @ 2400 hrs. 11/14/97. 46,605 CUM:$ 773,955 ETD:$ 0 EFC:$ 1,698,955 End of WellSummary for Well:AK8957 ARCO Alaska, Inc. KUPARUK RIVER UNIT WELL SERVICE REPORT K1(1E-24A(W4-6)) WELL 1 E-24A DATE 11/28/97 DAY 1 i JOB SCOPE PERFORATE, PERF SUPPORT DAILY WORK PERFORATE OPERATION COMPLETE ISUCCESSFUL IKEYPERSON YES YES WEINS 'nitialTbgPress IFinalTbgPress JlnitiallnnerAnn JF'nallnnerAnnIoPsl 0PSI 175PSI 175PSI DAILY SUMMARY JOB NUMBER 1127971811.9 UNIT NUMBER UNIT #1 SUPERVISOR SCHUROSKY Initial Outer Ann I Final Outer Ann 0 PSII 0 PSI PERFORATE 20', FROM 7880' TO 7900' WITH 2" HOLLOW CARRIER GUN, 4SPF 180 DEG. PHASE TIME 07:00 08:45 10:15 11:45 12:30 14:00 LOG ENTRY MIRU DOWELL COILTBG./E-LINE, SWS LOGGING UNT, HOLD TGSM TEST E-LINE TOOLSTRING. RIH WITH 2.5" X 20' HOLLOW CARRIER GUN, BIG HOLE, 4 SPF, 180 DEG PHASE. TIE IN TO DEPTH / PRESSURE UP TUBING TO OVER BALANCE BY 100 PSI. PLACE GUN TO SHOOT AT 7880' TO 7900' , SHOT GUN, POOH. AT SURFACE WITH TOOLS, GUN DID SHOOT,RDMO SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 1 ARCO ALASKA INC KRU / 1E-24A 500292085701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/10/97 DATE OF SURVEY: 111197 MWD SURVEY JOB NUMBER: AKMM80002 KELLY BUSHING ELEV. = 99.00 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS MEASD VERTICAL VERTICAL INCLN DEPTH DEPTH DEPTH DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT SECT 5493.30 5086.30 4987.30 37 5 S 37.20 E .00 1103.64S 863.54E 5538.00 5122.06 5023.06 36 38 S 36.84 E 1.14 1125.05S 879.69E 5701.04 5248.14 5149.14 43 1 S 63.73 E 11.18 1189.15S 959.41E 5798.10 5316.71 5217.71 47 10 S 73.11 E 8.07 1214.18S 1023.26E 5895.00 5378.10 5279.10 54 8 S 74.93 E 7.33 1234.74S 1095.27E 1039 1059 1148 1216 1290 .77 .35 .86 .06 .53 5989.07 5429.38 5330.38 59 47 S 79.44 E 7.22 1252.12S 1172.13E 6084.19 5476.76 5377.76 60 28 S 80.25 E 1.03 1266.66S 1253.31E 6179.61 5524.05 5425.05 60 6 S 80.48 E .43 1280.53S 1335.02E 6274.76 5569.80 5470.80 62 23 S 79.87 E 2.46 1294.77S 1417.20E 6368.85 5613.59 5514.59 62 8 S 81.10 E 1.19 1308.54S 1499.33E 1369 1451 1534 1617 1701 .23 .71 .58 .98 .26 6465.16 5659.30 5560.30 61 11 S 81.53 E 1.06 1321.34S 1583.12E 6559.43 5703.33 5604.33 63 7 S 79.60 E 2.74 1335.02S 1665.34E 6654.44 5747.06 5648.06 62 2 S 80.63 E 1.49 1349.50S 1748.43E 6750.48 5792.51 5693.51 61 28 S 81.19 E .79 1362.86S 1831.97E 6844.57 5836.08 5737.08 63 20 S 79.67 E 2.46 1376.73S 1914.18E 1786 1869 1953 2038 2121 .01 .36 .69 .29 .66 6940.82 5879.63 5780.63 62 50 S 79.76 E .54 1392.06S 1998.63E 7035.86 5923.79 5824.79 61 47 S 80.47 E 1.29 1406.51S 2081.54E 7132.92 5969.61 5870.61 61 51 S 79.83 E .59 1421.15S 2165.83E 7227.56 6014.38 5915.38 61 40 S 79.91 E .20 1435.81S 2247.92E 7321.21 6058.92 5959.92 61 31 S 79.47 E .44 1450.56S 2328.97E 2207 2291 2377 2460 2542 .49 .64 .20 .58 .96 7416.48 6104.11 6005.11 61 49 S 80.44 E .95 1465.18S 2411.55E 7511.00 6148.28 6049.28 62 27 S 80.08 E .74 1479.32S 2493.91E 7606.06 6191.58 6092.58 63 21 S 79.95 E .96 1493.99S 2577.25E 7700.71 6233.58 6134.58 63 57 S 80.09 E .64 1508.69S 2660.78E 7795.52 6274.51 6175.51 64 53 S 79.70 E 1.06 1523.70S 2744.97E 2626 2710 2795 2879 2965 .83 .39 .01 .83 .35 7892.91 6317.56 6218.56 62 37 S 79.80 E 2.32 1539.24S 2830.91E 7983.76 6359.30 6260.30 62 40 S 79.83 E .05 1553.51S 2910.34E 8078.82 6402.61 6303.61 63 7 S 79.79 E .48 1568.48S 2993.62E 8167.00 6442.48 6343.48 63 7 S 79.79 E .00 1582.42S 3071.03E 3052.68 3133.37 3217.99 3296.64 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 3454.75 FEET AT SOUTH 62 DEG. 44 MIN. EAST AT MD = 8167 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 99.86 DEG. TIE-IN SURVEY AT 5493.30' MD WINDOW POINT AT 5538.00' MD PROJECTED SURVEY AT 8,167.00' MD ORIGINAL SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA iNC KRU / 1E-24A 500292085701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/10/97 DATE OF SURVEY: 111197 JOB NUMBER: AKMM80002 KELLY BUSHING ELEV. = 99.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES MD-TVD VERTICAL DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 5493.30 5086.30 4987.30 6493.30 5672.74 5573.74 7493.30 6140.09 6041.09 8167.00 6442.48 6343.48 1103.64 S 863.54 E 1325.11 S 1607.56 E 1476.62 S 2478.45 E 1582.42 S 3071.03 E 407.00 820.56 413.56 1353.21 532.64 1724.52 371.31 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPERRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 ARCO ALASKA INC KRU / 1E-24A 500292085701 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/10/97 DATE OF SURVEY: 111197 JOB NUMBER: AKMM80002 KELLY BUSHING ELEV. = 99.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA TOTAL MEASD VERTICAL VERTICAL RECTANGULAR COORDINATES DEPTH DEPTH DEPTH NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5493.30 5086.30 4987.30 1103.64 S 863.54 E 407.00 5509.25 5099.00 5000.00 1111.31 S 869.38 E 410.25 3.25 5635.64 5199.00 5100.00 1166.89 S 922.51 E 436.64 26.39 5772.34 5299.00 5200.00 1208.37 S 1005.47 E 473.34 36.70 5931.67 5399.00 5300.00 1242.09 S 1124.48 E 532.67 59.33 6129.31 5499.00 5400.00 1273.31 S 1292.00 E 630.31 97.64 6337.62 5599.00 5500.00 1304.27 S 1472.06 E 738.62 108.32 6549.91 5699.00 5600.00 1333.51 S 1657.00 E 850.91 112.29 6764.08 5799.00 5700.00 1364.69 S 1843.78 E 965.08 114.17 6983.17 5899.00 5800.00 1398.73 S 2035.69 E 1084.17 119.09 7195.14 5999.00 5900.00 1430.81 S 2219.82 E 1196.14 111.98 7405.66 6099.00 6000.00 1463.60 S 2402.14 E 1306.66 110.52 7622.62 6199.00 6100.00 1496.58 S 2591.82 E 1423.62 116.96 7852.50 6299.00 6200.00 1532.88 S 2795.58 E 1553.50 129.88 8070.82 6399.00 6300.00 1567.21 S 2986.60 E 1671.82 118.33 8167.00 6442.48 6343.48 1582.42 S 3071.03 E 1724.52 52.69 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS 17-Dec-97 AOGCC Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Re: Distribution of Survey Data for Well 1E-24A Dear Lori Taylor: Enclosed are two survey hard copies. Tie-on Survey: Window / Kickoff Survey: Projected Survey: 5,493.00' MD 5,538.00' MD 8,167.00' MD (if applicable) Please call me at 563-3256 if you have any questions or concerns. Regards, William T. Allen Survey Manager Attachment(s) 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 0 I:! I I_1--11M G WELL LOG TRANSMITTAL To: State of Alaska December 3, 1997 Alaska Oil and Gas Conservation Comm. Atm.: Loft Taylor 3010 Porcupine Dr. Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs 1E-24A, AK-MM-80002 The technical data listed below is being submitted herewith. Please address any problems or concems to the attention of~ Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1E-24A: 2" x 5" MD Gamma Ray & Resistivity Logs: 50-029-20857-01 2" x 5" TVD Gamma Ray & Resistivity Logs: 50-029-20857-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (907) 563-3256 , Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMITTAL To.' State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Loft Taylor 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs December 3, 1997 1E-24A, AK-MM-80002 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Yurt Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted Disc with verification listing. - API#: 50-029-20857-01 5631 Silverado Way, Suite G · Anchorage, AJaska 99518 · (907) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company TONY KNOWLES, GOVERNOR ~L~SKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 2. 1997 Michacl Zanghi Drilling Supcrintcndcnt ARCO Alaska. Inc. P O Box 100360 Anchorage, AK 99510-0360 Kuparuk Rivcr Unit I E-24A ARCO Alaska. Inc. Permit No: 97-187 Sur. Loc.: 171'FSL. 226'FEE Sec. 16. TllN. RIOE. UM Btmholc Loc: 1416'FNL. 2524'FEL. Sec. 22. T1 IN. RIOE. UM Dear Mr. Zanghi: Enclosed is thc approvcd application for pcrmit to rcdrill the above rcfcrcnccd well. Thc permit to rcdrill docs not exempt you from obtaining additional permits required bx' law from other governmental agencies, and docs not authorize conducting drilling operations until all other required permitting dcterminations arc made. Blmvout prcvcntion cquipmcnt (BOPE) must bc tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE tcst perforated before drilling below the surfacc casing shoc must be given so that a representative of thc Commission may xvitncss the test. Notice max' be givcn by contacting thc Commission petroleum ficld inspector on thc North Slope pager at 659-3607. David W,,<Johnston Chairman ~ BY ORDER OF THE COMMISSION dllT'enclosures cc: Department of Fish & Game. ttabitat Section xwo encl. Dq>arlment of Environment Conservation w,o encl. . . ,STATE OF ALASKA ALAo~ OIL AND GAS CONSERVATION COMMIS$~.~I PERMIT TO DRILL 20 AAC 25.005 la. Type of Work Drill Redrill X i b Type of Well Exploratory I--~ Stratigraphic Test D Development Oil X Re-Entry ~] Deepen [] Service [] Development Gas [] Slngle Zone X MultlpleZone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 99', Pad 67' feel Kuparuk River Field 3. Address 6. Property Designation Kuparuk River Oil Pool P. O. Box 100360, Anchorage, AK 99510-0360 ADL 25651, ALK 469 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 171' FSL, 226' FEL, Sec. 16, T11N, R10E, UM Kuparuk River Unit Statewide At top of productive interval (@ TARGET ) 8. Well number Number 1359' FNL, 2423' FWL, Sec, 22, T11N, R10E, UM 1E-24A #U-630610 At total depth 9. Approximate spud date Amount 1416' FNL, 2524' FEL, Sec. 22, T11N, R10E, UM 10/06/97 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 1 E-33 8079' MD 2857' @ Target feet 45' @ surface feet 2560 6413' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 2o AAC 25.035(e)(2)) Kickoff depth 5538' feet Maximum hole angle 61.7° Maximum surface 2935 psig At total depth (TVD) 3600 pslg 18. Casing program Setting Depth size Specifications Top Bottom ,,, Quantity of cement Hole Casing Weight Grade Coupling Length lYE) TV~ IVlD 'I'VD llnclude sta~le aais) 6-1/8' 3-1/2' 9.3# L-80 BTC-mo¢ 2696' 5383' 4999' 8079' 6413' 486 sxs Class G 19. PresentT° be completed for Redrill, Re-entry, and Deepen OperationS.well condition summary ORIGINAL Total depth: measured 7420 feet Plugs (measured) true vertical 6733 feet Effective depth: measured 6 650 feet Junk (measured) Unrecoverable completion equipment left in hole true vertica 6053 feet following 1990 Workover Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor 80' 16' 326 Sx AS Il 110' Surface 2398' 1 0-3/4' 1400 sx ASIII, 250 sx AS I 2428' ' Intermediate " ' Production 7395' 7 ' 250 sx AS I, 700 sx Class G 7425' 6736' Perforation depth: measured 6684'-6760', 6850'-6862', 6884'-6897' MD true vertical 6081'-6147', 6226'-6237', 6256'-6267' TVD ~laS~ ~0[[ & ~S 00~lS. C0- 20. Attachments Filing fee X Property plat D BOP Sketch X Diverter Sketch [-] ' ~~gram X Ddlling fluid program X Time vs depth plot D Refraction analysis r~ Seabed report D 20 AAC 25.050 requirements X 21. I hereby certify that/he forego.~ is true and correct to the best of my knowledge (Contact William Isaacson at 263-4022 with questions.)__ Signed M~ [/~/[ Title Drillin~ Superintendent Date ~7-~ ~, / ,/ "~ Commission Use Only L./j AP[~mber _ _ I Approval date / m/-~ ~("~,~, I See cover lamer for Permit, s::;, -/~ 7Number r(~ 5~" ~2_ ~' -- ~ (~ ~"~ ~ '" ~ / I J U/et / -~ } I other requirements Conditions of approval Samples required D Yes .[~ No Mud logr~quir~l D Yes ~ No Hydrogen sulfide measures ~ Yes r~ No Directional survey required '~ Yes ~ No Requimd working pressure for BOPE [~ 2M D 3M D 5M D 1OM ~] 15M Other: {~ byorderof0 ~(~ t~, L~.~..~), Approved by Commissioner the commission Date I ~h i nllr,~t~ Fnrrn lrl-401 R~.v 7.24.R.Cl NORDIC RIG g2 LEVEL 3 WATER TANK /GLYCOL TANK J, , i ' HYDRAUUC 15'-6' 123'--0' REDRILL PLAN SUMMARY Well 1E-24A Type of well (producer/injector): Surface Location: Target Location: Bottom Hole Location- MD: TVD: Rig: Estimated Start Date: Operation Days to Complete: Producer 171' FSL, 226' FEL, SEC 16, T11N, R10E, UM 1359' FNL, 2423' FWL, SEC 22, T11N, R10E, UM 1416' FNL, 2524' FEL, SEC 22, T11N, R10E, UM 8O79' 6413' Nordic Rig 2 10-06-97 12 Drill Fluids Program: Density PV YP Viscosity Initial Gel 10 Minute Gel APl Filtrate pH % Solids Milling Window in 7" casing 9.4 >25 15-35 85-95 20-30 30-40 .. 8.5-9.5 Kick off to weight up 9.4-9.6 5-15 5-8 30-40 2-4 4-8 8-10 9.5-10 4-7% Weight up to TD 11.8 10-18 8-12 35-50 2-4 4-8 4-5 through Kuparuk 9.5-10 <12% Drilling Fluid System: Swaco Geolograph Adjustable Linear Shaker Brandt SMC-10 Mud Cleaner Triflow 600 vacuum Degasser, Poor Boy Degasser Pit Volume Totalizer (Visual and Audio Alarm) Trip Tank Fluid Flow Sensor Fluid Agitators and Jetting Guns Notes: Drilling fluid practices will be in accordance with the appropriate regulations stated in 20 AAC 25.033. Page 1 Casing/Tubing Hole size 6-1/8" Program: Csg/'l'bg 3-1/2", 9.3#, L-80, BTC-Mod Tubing 3-1/2", 9.3~f, L-80, EUE-Mod Length Top (MD/TVD) Btm (MD/TVD 2696' 5383? 4999' 8079? 6413' 5354' 29'/29' 5383'/4999' Cement Calculations: Casina to be cemented: -- 3-1/2" in 6-1/8" open hole Volume = 486 sxs of class G Blend @ 1.19 cu ft/sx Based on: Shoe volume, open hole volume + 48%, & 150' liner lap. Well Control: Well control equipment consisting of 5000 psi working pressure pipe rams, blind rams, and annular preventer will be installed. Maximum anticipated surface pressure is estimated at 2,935 psi and is calculated using a gas column to surface. The expected leak-off at the section cut in the 7" casing is estimated at 14.0 ppg EMW. With an expected formation pressure in the Kuparuk of 3600 psi and a gas gradient of 0.11 psi/E, this shows that formation breakdown would not occur before a surface pressure of 2,935 psi could be reached. Therefore, ARCO Alaska, Inc. will test the BOP equipment to 3500 psi, See attached BOPE schematic. Drilling Hazards: Lost Circulation: Overpressured Intervals: Other Hazards: The suspect lost circulation zones throughout the Kuparuk field are the K- 10 and the K-5 intervals. The sidetrack 1 E-24A, will kick off out of the 7" casing below both the K-10 and K-5 intervals. The 7" casing around the kick-off window will be squeezed with cement pdor to drilling out, which should isolate the K-10 and K-5 from sidetrack operations. If the cement squeeze is unsuccessful at achieving isolation, it is believed that both intervals should be able to handle the expected mud weights to be used for this sidetrack. Recent infill drilling data shows that wells in the area of 1E-24A were drilled to TD through the K-5 and K-10 intervals with mud weights as high as 11.7 ppg and no loses. The kick-off point in 1E-24A is below any zones which would be of pressure concern pdor to weighting up for the Kuparuk interval. None Directional- KOP: Max hole angle: Close approach: 5538' MD / 5122' TVD 61.7° (in sidetrack portion) No Hazards Page 2 38.3© (in original ., Lopping Program: Open Hole Logs: GR/Resistivity Cased Hole Logs: GR/CCL Notes- All ddll solids generated from the 1E-24A sidetrack will be hauled to CC-2A in Prudhoe Bay for gdnd and inject. Incidental fluids developed from ddlling operations will be hauled to the nearest permitted disposal well or to Parker 245 to be disposed by annular pumping into the permitted annulus Parker is connected to at that time. The permitted well will be within the Kuparuk River Unit. Page 3 KRU 1E-24A GENERAL SIDETRACK PROCEDURE PRE-RIG WORK: 1. Establish injection rate into perfs for upcoming cement downsqueeze. , RU CTU. RIH with inflatable cement retainer on CTU. Set inflatable in 3-1/2" tubing tail immediately below production packer. Mix cement. Circulate the cement down coil to immediately above circulating valve on top of retainer. Close circulation valve and down-squeeze cement below retainer into perfs. Use sufficient volume to fill 3-1/2" tubing down through tubing tall and 7" casing from bottom perf to tubing tail, plus excess to squeeze away into perfs if possible. Unsting from retainer and circulate well clean on top of inflatable retainer. RDMO CTU. 3. RU slickline unit. RIH and pull dummy valve from bottom GLM at 6435' MD RKB, leaving an open pocket. WORKOVER RIG WORK: 1. MIRU Nordic Rig 2. Lay hard-line to tree. 2. Vedfy well is dead. Load pits w/water. Circulate well to water. 3. Pressure test wellbore to 2500 psi testing cement squeeze and retainer, to ensure isolation from perforations. Set BPV. 4. ND tree. NU and test BOPE. 5. Screw in landing joint. POOH laying down all tubing and jewelry. . . RU E-line unit. Run gauge dng through bridge plug setting depth. RIH and set permanent bridge plug at 5740' MD-RKB. Pressure test wellbore to 3000 psi to ensure isolation from perforations and wellbore integrity above bridge plug. 8. PU DP and RIH with section mill to top of bridge plug. Circulate well to milling fluid. Spot an 18 ppg balanced mud pill from PBTD to the base of proposed section. 9. Pull up to proposed section top at 5540' and cut a 50' section in the 7" casing from 5540' - 5590'. POOH w/mill. 10. RIH w/open ended DP. Wash down through section and circulate any metal shavings from well. Mix and pump balanced cement kick-off plug f/100' below base of section to 200' above top of section. 11. RIH w/6-1/$" bit, mud motor, MWD / LWD, and steerable ddlling assembly. Dress off cement to top of section. Kick-off well and directionally ddll to total depth as per directional plan. Short trip to section in casing. POOH. 12. Run 3-1/2" liner to TD w/150' of ovedap to top of milled window. 13. Cement liner. Set liner hanger and liner top packer. POOH w/DP. 14. Pressure test casing and liner lap to 3500 psi for state test. Page 4 15. RIH w/completion assembly and sting into polished bore receptacle at top of liner. Space out. Displace well to sea water at max rate. Test tubing and annulus. 16. ND BOPE. NU and test tree. Freeze protect well with diesel. RDMO Nordic. 17. Clean out well to PBTD w/coiled tubing. Perforate through tubing. Lower Limit: 10 days No problems milling window, ddlling new hole, or running completion. Expected Case: 12 days Upper Limit: 18 days Difficulties encountered milling window, or drilling new hole. WSI 9/22/97 Page 5 ~¢. For: B ISAACSON Cate platte0 : 18-Sec-g7 Re(erence is 2(A Vets ~5 (Deo~ Ver[;com OeDths ore r~erence ~KB (Nordic Alaska, Inc iARCO Structure : Pod 1E Well : 24A Field : Kuporuk River Unit Locotion :Norfh Slope, Aloskoj 4600 4800 5000 5200 5400 CL ¢'h. 5600 -- 5800 6000 6200 6400 6600 0SO0 fl 60O Eosf (feet) -> 600 800 1000 i 200 1400 1600 1800 2000 2200 2400 2600 2800 JO00 3200 1000 - .............................. 00.g6 AZIMUTH 2872' (TO TARGET) *~*Plane of Proooscl~-~ TARGET LOCATION: 1559' FNL, 2425' FWL SEC. 22, TI IN, R10E TARGET WD=6251 TM0=7696 DEP=2872 SOUTH ! 550 ~ST 2649 ;8.95 , ~5 71 DLS: 9.00 dee per 100 ft ~"-~ ~9.45 ~ "'~...~ 55.8~ ~OC ~D=5420 7MD=5986 DEP=1366 ~ TD LCCA?,0N: " ~4~6' FNL, 252 % '-. I SEC 22, TI1N, R10E I -. ', "--~ C50 P¢D=5694 TMD=6563 DEP=1875 ANGL~ MAXIMUM ~=7~ 32 0EP=2376 ""-.~ T/ UNIT C4 ~D=6029 TMD=7269 DEP=2~97 % TARGET T/A5 ..... -- T/ UNIT A 7,/D=622' TMD=7674 OEP=2852 i ~ m~ ................. ~ %'~ AA INT ~0=6258 TMD=7752 DEP=2922 1~1 V~%O~ji 'll~% {O~D U~O/~ '"'-~ 8/ KUP eNDS ~0=5518 TMC=7879 CEP=3053 TARGET ANGLE ~ 1.7 DEG 800 i 000 12C0 1400 1600 1800 2000 22C0 2400 2600 2800 3000 3200 3400 3600 Verticom Section (feet) -> SURFACE LOCATION: !71' FSL, 226' FEL Azimuth 99.86 with reference 0.00 N, 0.00 E from slot //24 7-1/16" 5000 PSI BOP STACK ACCUMULATOR CAPACITY TEST I ANNULAR PREVENTER 7 6 PIPE RAM J I 5 BLINDRAM~ I I MUD CROSS4 ~ 3 PIPE RAM I 1. CHECK AND FILL ACCUMULATOR RESERVOIR TO PROPER LEVEL WITH HYDRAULIC FLUID. 2. ASSURETHAT ACCUMULATOR PRESSURE IS 3000 PSI WITH 1500 PSI DOWNSTREAM OF THE REGULATOR. 3. OBSERVE TIME, THEN CLOSE ALL UNITS SIMULTANEOUSLY AND RECORD THE TIME AND PRESSURE REMAINING AFTER ALL UNITS ARE CLOSED WITH CHARGING PUMP OFF. 4. RECORD ON THE IADC REPORT. THE ACCEPTABLE LOWER LIMIT IS 45 SECONDS CLOSING TIME AND 1200 PSI REMAINING PRESSURE. BOP STACK TEST 1. FILL BOP STACK AND MANIFOLD WITH WATER 2. CHECK THAT ALL HOLD-DOWN SCREWS ARE FULLY RETRACTED. PREDETERMINE DEPTH THAT TEST PLUG WILL SEAT AND SEAT IN WELLHEAD. RUN IN LOCK-DOWN SCREWS IN HEAD. 3. CLOSE ANNULAR PREVENTER AND CHOKES AND BYPASS VALVES ON THE MANIFOLD. ALL OTHERS OPEN. 4. TEST ALL COMPONENTS TO 250 PSI AND HOLD FOR 5 MINUTES. INCREASE PRESSURE TO 3500 PSI AND HOLD FOR 5 MINUTES. BLEED TO ZERO PSI. 5. OPEN ANNULAR PREVENTOR AND INSIDE MANUAL KILL AND CHOKE LINE VALVES. CLOSE TOP PIPE RAMS, HCR VALVE ON CHOKE LINE, AND OUTSIDE MANUAL VALVE ON KILL LINE. 6. TEST TO 250 PSI AND 3500 PSI AS IN STEP 4. 7. CONTINUE TESTING AL VALVES, LINES, AND CHOKES WITH A 250 PSI LOW AND 3500 PSI HIGH. TEST AS IN STEP 4. DO NOT PRESSURE TEST ANY CHOKE THAT IS NOT A FULL CLOSING POSITIVE SEAL CHOKE. 8. OPEN TOP PIPE RAMS AND CLOSE BO'I-I'OM PIPE RAMS. TEST BOTTOM RAMS TO 250 PSi AND 3500 PSI. 9. OPEN PIPE RAMS. BACKOFF RUNNING JT AND PULL OUT OF HOLE. 10. CLOSE BLIND RAMS AND TESTTO 3500 PSI FOR 5 MINUTES. BLEED TO ZERO PSI. 11. OPEN BLIND RAMS AND RECOVER TEST PLUG. MAKE SURE MANIFOLD AND LINES ARE FULL OF ARCTIC DIESEL AND ALL VALVES ARE SET IN THE DRILLING POSITION. 12. TEST STANDPIPE VALVES TO 3500 PSI. 13. TEST KELLY COCKS AND INSIDE BOP TO 3500 PSI WITH KOOMEY PUMP. 14. RECORD TEST INFORMATION ON BLOWOUT PREVENTER TEST FORM. SIGN AND SEND TO DRILLING SUPERVISOR. 15. PERFORM COMPLETE BOPE TEST ONCE A WEEK AND FUNCTIONALLY OPERATE BOPE DAILY. 1.11" - 3000 PSI CASING HEAD 2.11"- 3000 PSI x 7-1/16" 5000 PSI TUBING HEAD 3.7-1/16" - 5000PSI SINGLE GATE W/PIPE RAMS 4.7-1/16"- 5000 PSI DRLG SPOOL W/CHOKE & KILL LINES 5.7-1/16"- 5000 PSI SINGLE GATE W/ BLIND RAMS 6. 7-1/16" - 5000 PSI SINGLE GATE W/PIPE RAMS 7.7-1/16"- 5000 PSI ANNULAR PREVENTER NORDIC RIG LEVEL z 7Y-O" 25'-0' STAIRS EUSCO F-800 PUMP EMSCO F-800 TRIPLEX MUD PUMP SPIRAL , STAIRS cONTROL ~CONSOLE 28'-6' 36'-0" 5Y.-O' '-~ ~OVABL~ ~ ENCLOSU~ ]~ORDIC RIG g2 LEVEL 2 123'~ · WELL PERMIT CHECKLIST COMPANY ~"~,,~(__...,~ WELL NAME ,~,¢' //~"'- ~._ ~//,,~ PROGRAM: exp [] dev~'redrll [] serv [] wellbore seg El ann. disposal para req [] FIELD & POOL .~Z 20 /2 ~__.)~___) INIT CLASS .,~to_./_../ /-o,Z~/ 'GEoL AREA ~"~' ~ UNIT# / ///'~"? ON/OFF SHORE ~/t~) ADMINISTRATION , 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. T¢~,~ 12. ,, 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 drilling 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 A~ DATE 14. Conductor string provided ................... ~ N ~ ~~,./,.~ 15. Surface casing protects all known USDWs ........... Y N 16. CMT vol adequate to circulate on conductor & surf csg ..... Y N 17. CMT vol adequate to tie-in long string to surf csg ........ Y N 18. CMT will cover all known productive horizons .......... (~) N 19. Casing designs adequate 'for C, T, B & permafrost ....... (~ N 20. Adequate tankage or reserve pit ................. (~N 21. If a re-drill, has a 10-403 for abandonment been approved... 22. Adequate wellbore separation proposed ............. ~N ./- (/ 23. If diverter required, does it meet regulations ......... 24. Drilling fluid program schematic & equip list adequate ..... ~ N 25. BOPEs, do they meet regulation ................ 26. BOPE press rating appropriate; test to '~ ~--o'~::) psig. 27. Choke manifold complies w/APl RP-53 (May 84) ........ 28. Work will occur without operation shutdown ........... ,~ N 29. Is presence of H2S gas probable ................. ~ N REMARKS GEOLOGY D TE, 30. Permit can be issued w/o hydrogen sulfide measures ..... YvY N,~A 31. Data presented on potential overpressure zones ....... 32. Seismic analysis of shallow gas zones ............. 33. Seabed condition survey (if off-shore) ............ ~ Y N 34. Contact name/phone for weekly progress reports .... ./< . Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION' JDH ~.),,¢-~ RN co (Lo Comments/Instructions' HOWlljt- A:\FORMS\cheklist rev 09/97 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information, of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. Sperry-Sun Drilling Services LIS Scan Utility Wed Nov 26 08:54:27 1997 Reel Header Service name ............. LISTPE Date ..................... 97/11/26 Origin ................... STS Reel Name ................ UNKNOWN Continuation Number ...... 01 Previous Reel Name ....... %TNKNOWN Comments ................. STS LIS Writing Library. Technical Services Tape Header Service name ............. LISTPE Date ..................... 97/11/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Previous Tape Name ....... UNKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Comment Record TAPE HEADER KUPARUK RIVER UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: MWD RUN AK-MM-80002 T. FLYNN D. WESTER ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 1E-24A 500292085701 ARCO ALASKA, INC. SPERRY-SUI~ DRILLING SERVICES 26-NOV-97 16 llN 10E 171 226 99.00 97.50 68.90 WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 6.000 7.000 5533.0 3.500 8078.0 8078.0 1. ALL DEPTHS ARE MEASURED DEPTHS (MD) UNLESS OTHERWISE NOTED. 2. ANNULAR HYDRAULICS ARE CALCULATED USING THE POWER LAW MODEL. 3. MWD RUN 1 IS DIRECTIONAL WITH DUAL GAMMA RAY (DGR) AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR-4). 4. DEPTH SHIFTING/CORRECTION OF MWD DATA IS WAIVED AS PER THE PHONE CONVERSATION BETWEEN ALI TURKER OF SPERRY-SUN DRILLING SERVICES AND BILL ISAACSON OF ARCO ALASKA, INC. ON 19 NOVEMBER, 1997. 5. THIS WELL REACHED A TOTAL DEPTH (TD) OF 8167'MD, 6443'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. $ File Header Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/11/26 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 ROP FET RPD RPM RPS RPX .5000 START DEPTH 5308 5 5360 0 5500 0 5500 0 5500 0 5500 0 5500 0 STOP DEPTH 8115 0 8167 0 8122 0 8122 0 8122 0 8122 0 8122 0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) EQUIVALENT IINSHIFTED DEPTH BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE BIT R UNNO MERGE TOP MERGE BASE MWD 1 5360 . 0 8167 . 0 $ REMARKS: MERGED MAIN PASS. $ Data Format Specification Record Data Record Type 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1 68 GR MWD AAPI 4 1 68 RPM MWD OHPIM 4 1 68 ROP MWD FT/H 4 1 68 RPX MWD OHMM 4 1 68 RPS MWD OHMM 4 1 68 RPD MWD OHMM 4 1 68 FET MWD HOUR 4 1 68 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 Name Min Max Mean Nsam DEPT 5308.5 8167 6737.75 5718 GR 30.7576 524 138.32 5614 RPM 0.8813 2000 10.0721 5245 ROP 3.4952 580.664 70.8587 5615 RPX 0.674 86.3375 6.56039 5245 RPS 0.7837 73.8613 6.66767 5245 RPD 0.31 2000 11.2596 5245 FET 0.5125 11.8539 1.72468 5245 First Reading 5308.5 5308.5 5500 5360 5500 5500 5500 5500 Last Reading 8167 8115 8122 8167 8122 8122 8122 8122 First Reading For Entire File .......... 5308.5 Last Reading For Entire File ........... 8167 File Trailer Service name ............. STSLIB.001 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/11/26 Maximum Physical Record..65535 File Type ........... ~ .... LO Next File Name ........... STSLIB.002 Physical EOF File Header Service ns_me ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/11/26 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 AK/MBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 5308.5 8115.0 ROP 5360.0 8167.0 FET 5500.0 8122.0 RPD 5500.0 8122.0 RPM 5500.0 8122.0 RPS 5500.0 8122.0 RPX 5500.0 8122.0 $ LOG HEADER DATA DATE LOGGED: Il-NOV-97 SOFTWARE SURFACE SOFTWARE VERSION: ISC 5.06 DOWNHOLE SOFTWARE VERSION: DEPII 2.17F DATA TYPE (MEMORY OR REAL-TIME): MEMORY TD DRILLER (FT): 8167.0 TOP LOG INTERVAL (FT) : 5360.0 BOTTOM LOG INTERVAL (FT): 8167.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 36.6 MAXIMUM ANGLE: 64.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 $ ELECTROMAG. RESIS. 4 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): TOOL NUMBER P0875SP4 P0875SP4 6.000 6.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHI~M) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: $ Data Format Specification Record Data Record Type .................. 0 Data Specification Block Type ..... 0 Logging Direction ................. Down Optical log depth units ........... Feet Data Reference Point .............. Undefined Frame Spacing ..................... 60 .lin Max frames per record ............. Undefined Absent value ...................... -999.25 Depth Units ....................... Datum Specification Block sub-type...0 Name Service Order Units Size Nsam Rep DEPT FT 4 1' 68 GR MWD 1 AAPI 4 1 68 RPX MWD 1 OHMM 4 1 68 RPS MWD 1 OHMM 4 1 68 RPM MWD 1 OHMI~ 4 1 68 RPD MWD 1 OHMM 4 1 68 ROP MWD 1 FT/H 4 1 68 FET MWD 1 HOUR 4 1 68 LSND 9.40 44.0 10.5 2000 5.0 1.930 .000 1.910 1.940 .0 Code Offset Channel 0 1 4 2 8 3 12 4 16 5 20 6 24 7 28 8 154.0 Name Min Max Mean DEPT 5308.5 8167 6737.75 GR 30.7576 524 138.32 RPX 0.674 86.3375 6.56039 RPS 0.7837 73.8613 6.66767 RPM 0.8813 2000 10.0721 RPD 0.31 2000 11.2596 ROP 3.4952 580.664 70.8587 FET 0.5125 11.8539 1.72468 First Last Nsam Reading Reading 5718 5308.5 8167 5614 5308.5 8115 5245 5500 8122 5245 5500 8122 5245 5500 8122 5245 5500 8122 5615 5360 8167 5245 5500 8122 First Reading For Entire File .......... 5308.5 Last Reading For Entire File ........... 8167 File Trailer Service name ............. STSLIB.002 Service Sub Level Name... Version Number ........... 1.0.0 Date of Generation ....... 97/11/26 Maximum Physical Record.. 65535 File Type ................ LO Next File Name ........... STSLIB.003 Physical EOF Tape Trailer Service name ............. LISTPE Date ..................... 97/11/26 Origin ................... STS Tape Name ................ UNKNOWN Continuation Number ...... 01 Next Tape Name ........... UNK_NOWN Comments ................. STS LIS Writing Library. Technical Services Reel Trailer Service name ............. LISTPE Date ..................... 97/11/26 Origin ................... STS Reel Name ................ UArKI~OWN Continuation Number ...... 01 Next Reel Name ........... IINKNOWN Comments ................. STS LIS Writing Library. Technical Services Scientific Scientific Physical EOF Physical EOF End Of LIS File
