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Home My WebLink About180-080 • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. May 20, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Perforating Record: 1E-07 Run Date: 5/19/2011 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 -07 Digital Data in LAS format, Digital Log Image file � 1 CD Rom 50- 029 - 20495 -00 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton , x r x Q 1 ' Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907 - 273 -3535 klinton.wood@halliburton.com (, Date: / Signed: 0 K2 e Y • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION a ❑ ❑ OR ❑ R RECO � MPLETIO REPORT I AND LOG 1a. Well Status: Oil ❑ 20AAC 25.105 ‹. 20AAC 25.110 Development 0 Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Service ❑ Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. orAband.: June 14, 2011 180 - 080 / 311 - 153 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 September 23, 1980 50 029 - 20495 - 00 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 893' FSL, 631' FEL, Sec. 16, T11N, R10E, UM October 8, 1980 1E Top of Productive Horizon: 8. KB (ft above MSL): 24' RKB 15. Field /Pool(s): 1173' FNL, 1373' FEL, Sec. 15, T11N, R10E, UM GL (ft above MSL): 105.7' AMSL Kuparuk River Field Total Depth: 9. Plug Back Depth (MD + TVD): 969' FNL, 996' FEL, Sec. 15, T11N, R10E, UM 8609' MD / 6189' TVD Kuparuk River Oil Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 549889 y 5960480 Zone 4 9310' MD / 6711' TVD ADL 25651 TPI: x - 554398 y - 5963725 Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 554774 y- 5963932 Zone 4 1944' MD / 1791' TVD 469 18. Directional Survey: Yes ❑ No Q 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1650' MD / 1570' 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 Surf. 80' Surf. 80' 24" 200 sx Permafrost 10.75" 45.5# K -55 Surf. 3249' Surf. 2678' 13.75" 1500 sx Fondu, 350 sx AS 7" 26.0# K -55 Surf. 9289' Surf. 6697' 8.75" 315 sx Class G 24. Open to production or injection? Yes ❑ No El 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" 8916' 8520' MD / 6117' TVD, perfs plugged off: f 8559' MD / 6149' TVD, 8877' MD / 6400' TVD 8686 MD 6250' - 6365' TVD / 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9106 MD 6567' - 6583' TVD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED 9138' -9175' MD 6590' -6616' TVD 9010' MD sand plug ■ 9010' -8609' cement 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) not applicable plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS -OIL RATIO Test Period - -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. psi 24 -Hour Rate -> 28. CORE DATA Conventional Core(s) Acquired? Yes ❑ No 0 Sidewall Cores Acquired? Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratoryanal tical relyster „5.071. 444 AUG 1 7 2011 NONE B a `:fit "til t. :,r�ftii• 1,.AutttitSStdt vie ri� 1v JUL 2 7 2011 % , . w Yti r I,er >$E Form 10-407 Revised 12/2009 CONTINUED ON REVERSE Submit original only y ?„ ) , g..6,10 6 28. GEOLOGIC MARKERS (List all formations and markers e•itered): 29. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 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 1650' 1570' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: Kuparuk 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: Jill Long @ 263 - 4093 Ja51 II Printed Nam: L. _ any Title: CTD Engineering Supervisor Signature a Q1 . •_ 461 ' one 263 -4021 Date 7l , / //'. Sharon Allsup -Drake INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. 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 _. �.. • KU P , 1E -07 GiHi[15 x Well Attributes / Max Angle & MD TD WellboreAPWWI Field Name Well Staten m ci ( °) MD (ftKB) Act Btm dike) "11X{18 ,. /lia k&' 500292049500 KUPARUK RIVER UNIT (PROD L 56.75 I 3,70000 93100 LSF+[t[tT77 _ - Comment H2S (ppm) D to Annotation End Date KB -Grd (ft) Rig Release Date - SSSV TRDP 80 l 9/152010 Last WO: ... 2/811992 39 49 10/13/1980 _ O ,.. a,97 0 -v20t] 443- Qd.PM�...- -." T _ . , i - _. _ - ..1E d to SGnemego.Artlwl A otabon (Depth (ftK8) (End Date (Annotati ( Last MOO Last Tag: RKB 9,034 0 I l 5/14/2011 Rev Reason ADD LATERALS, GLV C/O nmars I //16/2011 Casing Strings HANGER, 28 f Casing Description String 0... String ID Top (ftK8) Set Depth (f.. Set Depth (ND) .. String Wt... String :String Top Thrd CONDUCTOR 16 15.060 0.0 80.0 800 65.00 11-40 WELDED Casing Description String 0... String ID .. Top (ftlCB) Set Depth (f... Set Depth (ND) ... String Wt... String String Top Thrd _. SURFACE 10 3/4 9.794 31.2 3,249.0 2 678 4 45.50 K-55 BTC CONDUCTOR, _ Casing Description String 0.. String ID Top (RKB) Set Depth (f Set Depth (TVD) .. Siring Wt... String ,String Top Thrd 0 PRODUCTION 7 6.276 31 7 9,289 3 6,697 0 26.00 K-55 B IC SAFETY VLV, Tubing Strings 1,,941 944 Tubing Description p P ' ice . String 0 String ID ... Top (MB) Set Set Depth (i... Set Depth (TVD) .. String Wt... Str ng ._ Siring Top Thrd TUBING j 31/2 2 27.5 8,555.2 6,1454 9.20 J -55 AB MOD -BTC GAS Com l Deta ils ils 2,398 - Top Depth SURFACE, (ND) Top Idol _ - N i... 31 - 3,249 Top (f1KB) (ftK6) (1 Item Description Comment ID (in) 27.5 27.5 -0.18 HANGER FMC GEN I RETROFIT HANGER 3.500 GAS LIFT, 4,489 1,944.2 1,790.7 46.25 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.812 8,467.7 6,076.7 38.40 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 GAS LIFT, 5,662 _ -- ' ' 8,506.1 6,105.5 36.05 PBR BAKER PBR W/ 10' STROKE 3.000 GAS LIFT, .. 8,519.8 6,116.7 36.15 PACKER BAKER HE RETRIEVABLE PACKER 2.890 6,348 8,533.0 6,127.5 36.25 SBR BAKER G-SEAL SBR w/ OTIS PROFILE 2.813 GAS LIFT, 7,069 Tubing �_ I Description String 0... String ID... Top (ftK6 Set Depth f... Set Depth ND String Wt.. ,String ... String Top Thrd 9 ption 8 9 P ) P ( P (TVD) ... 9 Wt. TUBING Or inal 3 1/2 2 992 8 554 3 8,917.9 6 430 7 9 20 , K -55 FL4S LIFT, Completion Details 7,694 Top Depth (ND) Top Inc! Rood... Top (ftK6) (MB) ( °) Item Description Comment ID (In) 8,554.3 6,144.7 36.41 SLICK STICK 3.000 GAS LIFT. 8.453 8, 8,559.3 6,148.7 36.44 PACKER BAKER FIB-1 PACKER 2 890 NIPPLE, 8,468 ,l_ 8,673.5 6,2402 37.37 BLAST RINGS CARBIDE BLAST RING .ITS 2 992 8,876.3 6,399.4 40.78 LOCATOR BAKER LOCATOR SUB 3.000 8,877.2 6,400.0 40.79 PACKER BAKER FB -1 PACKER 4.000 PBR, 8,506 - / 8,879.7 6,401.9 40.84 SBE BAKER SEAL BORE EXTENSION 2.813 PACKER, 6,520 / 8,899.7 6,417.1 4124 NIPPLE CAMCO D NIPPLE NO GO, MILLED OUT TO 2.80, 5/12/2011 2.800 p IF 8,916.3 6,429.5 41.58 SOS BAKER SHEAR OUT SUB 2.992 SBR, 8,533 Other In Hole (Wireline retrievable plugs, valves, pumps fish, etcj_ Top Depth., SLICK STICK, (TVD) Top Inch PACKER, 8,559 --- Top (W(B) IRKS) C) Description Comment Run Date ID (in) 8,876 6,399.2 40.77 WHIPS DOCK 3 5 MONOBORE RETRIEVABLE 6/23/2011 1 I 8,892 6,411.3 41.09 WI ORS I OCK "3.5 MONOBORE RETRIEVABLE 6/12/2011 PRODUCTION, _ +i 8,598 -: 9,010 6,499.5 45.00 PLUG SAND PLUG, 20/40 RIVER SAND 5/14/2010 0.000 9,193 6,628.9 45.00 Fish Arm off OK -1 lost In Rathole 4/12/1987 PRODUCTION, Perforations & Slots 8.667 - -- _. -- Shot Top (TVD) Blm (TVD) Dens Top (ftKB) Bhn (fIKB) (ftK6) (ftK6) Zone Date (sh..- Type Comment IPERF, 8,686 8,832 6,250.1 6,365.2 C -4, C -3, C -2, 8/22/1981 4.0 IPERF SOS ENERJET 0 deg 8,886 - 8,832 - -° 1E -07 lit IPERF. _ 8,855 8,860 6,383.0 6,386.9 5/19/2011 6.0 IPERF 2" x 5' GUNS, 60 DEG PHASE, 11 8,855 - 6,860 PRODUCTION, GM RDX, BH CHARGES 8,860 - 8,877 8,882 6,399.9 6,403.7 5/19/2011 6.0 IPERF 2" x 5' GUNS, 60 DEG PHASE, 11 GM RDX, BH CHARGES 8,892 8,897 6,411.3 6,415.1 5/19/2011 6.0 IPERF 2" x 5' GUNS, 60 DEG PHASE, 11 LOCA 8 - / GM RDX, BH CHARGES PACKER, 8,8 - 6! 9,106 9,128 6,567.4 6,582.9 A-5, 1E-07 822/1981 4.0 IPERF SOS ENERJET 0deg IPERF, 8,877 - 8,882 , _ 'ai11Ba.. " 9,106 9,128 6,567.4 6,582.9 AS, 1E - 07 8127/1993 4.0 RPERF SOS Titan 2 1/2" H.0 _ 5 WHIPSTOCK, 7alalre M• 06E, 0.8880 ' .. ' ' 9,138 9,175 6,590.0 6,616.2 A-4, 1E -07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg °-. 9,138 9,175 6,590.0 6,616.2 A-4, 1E -07 8/27/1993 4.ORPERF SOS Titan 2 1/2" H.0 ti Notes: General & Safety " End Date 1 Annotation IPERF 11/13/2004 NOTE C -SAND LEAK @ 8860', NEAR CSM 8,892 - 6,897 12/5/2010 NOTE: View Schematic w /Alaska Schematic9.0 NIPPLE, 8,900 re' 6/15/2011 NOTE: MILL CEMENT FROM 8609 - 8879 CTMD w/ 2.69" x 2.98" B: CENTER BIT SOS, 8,916 ir __. . WHIPSTOCK, 8,892 Cement Plug, 8,614 PLUG, 9,010 RPERF, 9,106-9,128 IPERF,_ ) . IPERF, \ \ \ \ \ \YYY 9,10& "." 9,138 -9,175 - r RPERF, Mandrel Details _ _ ° 9,136 -9,175 Top Depth Top I I Port (TVD) Inc/ OD - Valve Latch Size TRO Run Stn TopjftKaj (ftKB) (°) Make Model (in) Sere Type Type (i (psi) Run Date Corn... 1 2,398.4 2,106.9 45.25 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 7/92011 Fah, 9,193 2 4,488.6 3,421.6 54.55 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,308.0 7/92011 PRODUCTION, ., _ 32 - 9,289 3 5,662.4 4,171.9 47.81 CAMCO KBUG 1 GAS LIFT DMY BTM 0.250 1,408.0 5!12011 TD (1E - 07), - _ 9,310 4 6,347 4,620.2 50.00 CAMCO KBUG 1 GAS LIFT DMY BK 0.250 0.0 5/7/2011 SLOTS, _ _ 9,171 - 10,364 SLOTS sz ). e'e:. 6, r 5 7,068.6 5,078.9 51.33 CAMCO KBUG 1 GAS LIFT DMY BK - 2 0.000 0.0 2/8/1992 9,228 SLLOTS. OTS, 6 7,693.6 5,497.1 44.03 CAMCO KBUG 1 GAS LIFT DMY BK - 2 0.000 0.0 2/8/1992 10,456 L INER ALI. 7 8,452.8 6,065.1 38.59 OTIS LBX 1 12 GAS LIFT DMY RM 0.000 0.0 1/3/2000 ER I, 8,484 10,e57 ( qtr. 8 8,598.1 6,180 -0 36.74 CAMCO KBUG 1 PROD OPEN 0.000 0.0 522/2011 9 8,667.2 6,235.2 37.34 CAMCO KBUG 1 PROD DMY None 0.000 0.0 225/1992 Closed . 10 8,860.1 6,386.9 40.45 CAMCO KBUG 1 PROD OPEN 0.000 0.0 5/17/2011 LINER AL2 -01, - -- - - - -- 8,872 - 11,090 1 E -07 Well Work Summary DATE SUMMARY 4/27/11 (PRE -CTD) TIFL (PASSED), PT & TEST ON SV (PASSED), SSV (PASSED,V (PASSED), DD TEST ON SSSV (PASSED) 5/6/11 SET CATCHER ASSY @ 8900' RKB. PULLED 1" GLV'S @ 2398', 4488', 5662', & 1" OV @ 6347' RKB. IN PROGRESS 5/7/11 SET 1" DV'S @ 2398', 4488' & 5662' RKB. PULLED CATCHER FROM 8900' RKB. BULLHEAD 180 BBL'S DOWN IA TO FORMATION. SET 1" DV @ 6347' RKB.MITIA FAILED. TAGGED @ 9165' SLM, EST 17' RATHOLE. 5/10/11 MIT -IA (PASSED) 5/12/11.MII L OUT 2.75" D NIPPLE TO 2.80" @ 8900 RKB, WH SHUT IN & FP, IN PROGRESS 5/13/11 PLACE SAND PLUG FROM 9165' RKB TO APPROX 9000' RKB, RETURNING 5/14 FOR TAG / SAND HEIGHT ADJUSTMENT, WH SHUT IN, FP, IN PROGRESS 5/14/11 RIH, TAG SAND @ 9010' CORRECTED CTMD, WH SHUT IN, FP, READY FOR SLICKLINE, IN PROGRESS 5/14/11 TAG TOS (cry, 9026' SLM EST. 9034' RKB, IN PROGRESS. 5/16/11 RIH TO PUMP SAND PLUG, RECIEVED CALL @ 9:00 FROM ANC ENG TOS OK , POOH, WH SHUT IN, READY FOR WIRELINE, IN PROGRESS 5/17/11 SET CATCHER. PULLED DV @ 8860' RKB. MEASURED BHP @ 8759' RKB: 2709 PSI. PULLED CATCHER. ESTABLISHED INJECTIVITY RATE: 1.5 BPM @ 850 PSI. READY FOR E /L. 5/19/11 PERFORATFn INTFRVAI S RR55' - 8860' 8876.5'- 8881.5', 8891.5'- 8896.5'. CORRELATED TO 01JAN2006 PRODUCTION PROFILE LOG. 5/22/11 SET CATCHER. PULLED DV @ 8598' RKB. PULLED CATCHER. READY FOR COIL. 5/23/11 RIH, PUMP CEMENT FOR RIG PREP. ACHIEVED 1000 PSI SQUEEZE PRESSURE, APROX 18 BBL OF CEMENT BEHIND PIPE, CLEAN OUT TO 8,615, POOH MAINTAINING 500 PSI ON WH, FREEZE PROTECT, CEMENT WILL BE READY FOR PRESSURE TEST ON 5/26 @ 12:00, READY FOR SLICKLINE 5/25/11 DRIFTED TBG WITH 3 -1/2" BRUSH & 2.78" GAUGE. TAGGED CEMENT PLUG @ 8577' SLM. TESTED TBG 1000 PSI; LOST 250 PSI IN 10 MIN. LOCATED & TAGGED OPEN GLM @ 8598' RKB / 8566' SLM. RETESTED TBG 1000 PSI; LOST 200 PSI IN 10 MIN. 5/26/11 SET CATCHER ON CMT PLUG @ 8592' SLM. SET DV @ 8598' RKB. TESTED TBG 1000 PSI, GOOD. PULLED CATCHER. READY FOR CTU. 6/5/11 REINSTALL COIL REEL AND INJECTOR @ KCC, MOB UNIT TO 1 E -07, STAB PIPE IN THE INJECTOR AND READY FOR MILL WORK TOMORROW, IN PROGRESS 6/6/11 MILL CEMENT FROM HRD TAG @ 8599 CTMD, CORRECTED TO SL TAG ON 5/25/11, RKB 8609 MD, TERMINATED MILLING FOR THE NIGHT @ 8764 MD, ACHEAVED 155 FT MILLING, WELL SHUT IN & FP, RETURN TOMORROW, IN PROGRESS, 6/7/11 UNABLE TO PERFORM AM MILLING DUE TO CTRI COIL CONTROL UNIT DN & TIME LINE OF CREW CHANGE OUT, CTRI UNIT REPAIRED, READY UNIT FOR RESTART TOMORROW, WELL SHUT IN & FP, IN PROGRESS 6/8/11 MILL 115 FT CEMENT FROM CORRECTED DEPTH OF 8764 CTMD TO 8879 CTMD, GAUGE BIT ?It), GOING IN W/ 2.685" RING, TIGHT, GAUGE AGAIN END OF MILLING 2.65 ", TERMINATE MILLING @ THIS DEPTH AFTER CALLING TOWN ENG, PERFORMED 10 MIN PT ON TUBING W/ 45 PSI %\- LOSS, GOOD TEST, WELL LEFT SHUT IN AND FP, READY FOR BPV, IN PROGRESS 6/9/11 Complete reel swap & wire pressure Bulk head. RDMO 2K -13. * ** Exempt rig move to 1E-07.*** 6/10/11 Spot Rig over well, MIRU, Start BOPE Test. Waived by Matt Herrera, AOGCC 6/11/11 Complete BOPE test, Swap out wing valves, Perform slack mgmt, M/U Coil Connector & BHA #1, RIH to mill cement 6/12/11 RIH and underream cement 8879 to 8930, Run Dummy whipstock to 8930, Run whipstock, Set TOWS @8892, Start OOH 6/13/11 Fi window run Mill 3.5" exit 8892.7 to 8898, Start 2nd mill run to exit 7" @ 8898.5 6/14/11 Completed window milling operations, drill build section to 9190' • • Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 10, 2011 2:34 PM FrD r J6 _ To: 'Long, Jill W Subject: RE: 1E -07 Sundry 311 -153: Additional Perforations Jill, That is a relatively minor change to the proposed procedure. It is approved and I will add this email to the well file to document the change. Regards, Guy Schwartz Senior Petroleum Engineer `* e^ k LUL AOGCC 793 -1226 (office) 444 -3433 (cell) From: Long, Jill W [ mailto: Jill.W.Long @conocophillips.com] Sent: Tuesday, May 10, 2011 2:21 PM To: Schwartz, Guy L (DOA) Subject: 1E -07 Sundry 311 -153: Additional Perforations Guy - This email is in regards to additional pre -rig work planned at well 1 E -07 that would fall under approved Sundry 311 -153. The objectives of the work outlined in the Sundry application have not changed, however, ConocoPhillips would like to add an additional set of perforations in the straddle packer section to assist with cementing the 3.5" x 7" annulus. The original plan had been to circulate cement into the annulus using only the open production mandrel. By adding -5' of perforations directly below the mandrel, there would be an additional point for cement circulation. The perforations will help improve the chances of getting cement in the annulus at that location which could potentially be used as a back -up kickoff point. If you have any questions or concerns with the addition of these perforations please let me know. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907 - 263 -4093 Cell: 907 - 230 -7550 Fax: 918- 662 -6330 5/10/2011 • • SITATE Li[LASIKKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMM SSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Jill Long Wells Engineer 0 ConocoPhillips Alaska, Inc. t D P.O. Box 100360 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1E-07 Sundry Number: 311 -153 Dear Ms. Long: MAY 2011 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, 4 I , Daniel T. Seamou • , Jr. Chair DATED this l day of May, 2011. Encl. • • • a+ ConocoPhillips Alaska P.O. BOX 100360 ANCHORAGE, ALASKA 99510 -0360 RECEIVED May 3, 2011 Commissioner- State of Alaska Alaska Oil & Gas Conservation Commission Mika & Gas Cans. Commission 333 West 7th Avenue Suite 100 Anchorage, Alaska 99501 AnctiqTqc Dear Commissioner: ConocoPhillips Alaska, Inc. hereby submits a Sundry application to perforate and cement off the A -sand and C- ✓ sand perforations in 1E-07 (PTD# 180 -080). This work is being performed in preparation for coiled tubingin ling (CTD) operations scheduled to begin June 1, 2011. The objective of the CTD project is to drill four lateral sidetracks (1 E -07A, 1 E- 07AL1, 1 E- 07AL2, and 1 E- 07AL2- 01) targeting the C2, C3, and C4 sands. Two laterals each will be drilled from two, 3.5" x 7" window exits. Permit to Drill applications for those laterals will be submitted separately from this Sundry application at a later date. In the meantime, a proposed CTD schematic is attached. Attached is an outline of the pre -CTD wellwork planned for 1 E -07 and a brief summary of CTD work. If you have any questions or require additional information please contact me at my office 907- 263 -4093 or on my cell phone 907 -230 -7550. Sincerely, 7 I, Y Jill ong Coiled Tubing Drilling Engin • • STATE OF ALASKA 9LK R `"°•` I ALAS L AND GAS CONSERVATION COMMISSI VIF:, ; f r$2 APPLIC TION FOR SUNDRY APPROVA S 20 AAC 25.280 . Type of Request: Abandon Plug for Re drill AL' `a- � al e A v � a 8 � 1. T y p q �'"` g � P erforate New Pool r R ep air w ell a e Wove g rogram Suspend r Plug Perforations �' ' Perforate r Pull Tubing r A r 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 r Exploratory r 180 - 080 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 029 - 20495 - 00'° 0(3 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 V. 1E -07 • 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): 9310 • 6712 • 9203' 6636' 9193' Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 16 80' 80' SURFACE 3218 10.75 3249' 2678' PRODUCTION 9258 7 , 9289' 6697' Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 8686 8832', 9106' 9128', 9138' - 9175' 6250' - 6365', 6567' 6583', 6590' - 6616' 3.5 J - 8916 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) PACKER - BAKER HB RETRIEVABLE PACKER MD= 8520 TVD= 6118 PACKER - BAKER HB -1 PACKER MD= 8559 TVD= 6149 PACKER - BAKER FB -1 PACKER MD= 8877 TVD= 6400 SAFETY VLV - CAMCO TRDP- 1A -ENC SAFETY VALVE MD= 1944 TVD= 1791 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program r BOP Sketch Exploratory Developmen# Service 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: 5/10/2011 Oil r Gas r WDSPL r Suspended 17 . 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned r Commission Representative: GSTOR r SPLUG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jill Long @ 263 -4093 Printed Name Jill Long Title: Wells Engineer Signature Pho ne: 263 -4093 Date 05/03h, g � i 1 I Commission Use Only Sundry Number: 1 1.- ` 53 Conditions of approval: Notify Commission so that a representative may witness L Plug Integrity r BOP Test O Mechanical Integrity Test r Location Clearance r s t 3 std r osi. So it f r- Other: V /�/� ,,//�� J/ # 2SOC pSL P•t.• .414,0" Ts F 6r`'`Y` p _ A /{er lu ip /4t er•..e.,l cL ,p r�d� 1t Subsequent Form Required: 2 p AAC z S t 7-CO /O -NO`- APPROVED BY Approved by: � / 1 r l ,.....1 - DMS MA 0 4 2Q1 COMMISSIONER THE COMMISSION Date: 3 • << :0. 5 >> - �/ Form 10 -403 Revised 1/2010 R I (� Subm i rt ' Dupl i cate • • Sundry Application for Perforating and Cementing KRU 1E -07 Well History The C -sand production in 1 E -07 has decreased significantly over the past 10 years. Over the same period of rate decline, injection rates in offset injectors has remained fairly consistent leading to the conclusion that the current welibore placement is not optimal for maximizing production. Pressure trends from the C -sand in the area support this conclusion. Therefore, the purpose of the CTD project is to increase throughput and develop the under- produced oil resource in the Kuparuk C -sand by drilling four CTD laterals out of the well. Prior to ✓ drilling, the A sand will be plugged off via a cement squeeze making the welibore a dedica C -sand only n n producer. orbit'. opG�. 11 t"'e CvrnhN,y Prc vees 12-0 o VC✓camPie Operational Outline ci 3 l u" ' duce 5'4 ► "M fo-e ((eaaec 1404 This Par of rf^c AO t __ —/ Pre -Rig Work 1. Changeout all gas lift valves to dummy valves. 2. Mill out the 2.75" D nipple at 8900' RKB to a 2.80" ID. 3. Cover the A -sand perforations with sand. The top of the sand will be loft above the top A -sand perforation but below the tubing tail. 4. Pull the gas lift valve from mandrel #10 at 8860' RKB and leave it open. 5. Perforate the 3.5" tubing tail across from potential CTD kickoff locations. Planned kickoff points are -8888' MD and -8904' MD. 6. Place cement below the 3.5" tubing tail and between the tubing tail and the 7.0" casing. Also, using the open gas lift mandrel, place cement in the straddle packer annulus between the 3.5" tubing and the 7" casing. The top of cement will be left at the top of the C sands (-8680'). 7. Drift and tag the top of the cement. • 8. Cleanout the cement inside the 3.5" tubing down to just above the gas Lift mandrel at 8860' RKB. 9. Set BPV and prepare wellsite for rig arrival. CTD Procedure Overview 1. MIRU Nabors CDR2 -AC rig using 2" coil tubing. NU 7 -1/16" BOPE, test. Ff.. A 2. Cleanout the remaining cement in the 3.5" tubing from -8860' to the tubing tail. Set the lower , whipstock at -8904' MD. Mill a 2.80 ", two-string window exit with high -side orientation off of the A whipstock. 3. 1E-07A Lateral a. Drill 2.70" x 3" bi- center lateral in the C sand b. Load well with kill weight fluid. Run 2 %" slotted liner from TD to the kickoff point for the 1 E- iq 07AL1 lateral with an anchored aluminum billet on top y' /� 4. 1 E -07AL1 Lateral l r � ) a. Drill 2.70" x 3" bi- center lateral in the C sand b. Load well with kill weight fluid. Run 2 %" slotted liner from TD to just inside the window with a deployment sleeve on top 5. Set the upper whipstock at -8888' MD. Mill a 2.80 ", single- string window exit with high -side orientation off of the upper whipstock. 6. 1 E -07AL2 Lateral a. Drill 2.70" x 3" bi- center lateral in the C sand b. Load well with kill weight fluid. Run 2 %" slotted liner from TD to the kickoff point for the 1 E- 08AL2-01 lateral with an anchored aluminum billet on top 7. 1 E -07AL2 -01 Lateral a. Drill 2.70" x 3" bi- center lateral In the C sand b. Load well with kill weight fluid. Run 2'%" slotted finer from TD to up Inside the tubing tail with a deployment sleeve on top 8. Freeze protect. ND BOPE. RDMO Nabors CRD2 -AC. Handover to Production group. 1E-07 Proposed CTD Sidetrack 3 -1/2" Camco TRDP- IA -ENC SSSV @ 1944' MD = 2.812" ID 3 -1/2" 9.3# L -80 EUE 8rd Tubing to surface sssv 3 -1/2" Camco KBUG gas lift mandrels @ 16" 65# H -40 shoe 2398' @ 80' MD 4489' 5662' 6348' 10 -3/4" 45.5# K- 7069' 55 shoe @ 7694' 3249' MD 3 -1/2" OTIS LB gas Lift @ 8453' 3 -1/2" OTIS X Nipple @ 8468' MD (2.813" min ID) Baker 3 -1/2" PBR @ 8506' MD (3" ID) Baker HB (retrievable) Packer @ 8520' MD (2.89" ID) • -- --- Baker G -Seal SBR @ 8533' MD (2.813" ID) Slick Stick @ 8554' MD (3.0" ID) Baker HB -1 Packer @ 8559' MD (2.89" ID) 3 -1/2" Camco KBUG gas lift mandrels @ 8598', 8667' Carbide Blast Rings JTS @ 8673.5' 3 -1/2" Camco KBUG gas lift mandrel @ 8860' Baker FB -1 Packer @ 8877' MD (4.0" ID) Baker SBR @ 8880' MD (2.813" ID) C -sand perfs 8686' , 8832' MD = 731/2c:mcoDNiPPIe NO GO @ 8900' MD (2.75" min ID) Mill out to 2.8" 3-1/2" monobore whipstock @ Baker Shear Out Sub @ 8916' 8888' RKB 8876' E -line 3 -1/2" monobore whipstock @ C • 8904' RKB , TD: 2 111 50' MD (Billet @ 9400' MD I TD: 111 1 E -07AL2 -01 A sand perfs , ' _____________ _____________________________i1 TD: 11150'MD 9106' - 9128' MD al j 9138' 9175' MD \1l�� a_4L (Billet @9450'MDI . I 11E -07A _ ` �� II TD: 10900' MD 7" 26# K -55 shoe @ i L __________ ___ __ _ __ 9289' MD __________________ J 1E -07AL1 - TD: 10850' MD F<U P 1 E 07 C �Ph�! We Attributes Max Angle & MD TD Wellbore API/UWI Field Name Well Status Ind (') IMD (8886) Act Btm (988) ` 500292049500 k11PARUK RIVER UNI7 _ PR00 56./5 3,700 00 9,310.0 (Comment H2S (ppm) '' Date Annotation End Date KB - Card (ft) Rig Release Date ••• .Go0 11 `G 5£ 47 A11 SSSV TROP 70 8/6/2009 Last WO- I 2/8/1992 39.49 10/13/1980 We0. Cap6y J.6b 3R _ !c 2n A,l Annotation Depth (ft88) 'End Date Annotaton z L st Mod ... End Date Last Tag: SLM i 9.15/ 0 1 12/23/2010 ( Rev Reason GLV C /O, TAG, PULL PLUG I Imosbor 1 1/22/2011 Casing Strings Casing Desenption String 0... ;String ID ... Top (kKB) Set Depth (f.,. Set Depth (TVD) ... String Wt... String ...'String Top Thrd HANGER,28 -- i - - i?•` CONDUCTOR 16 15.060 00 80.0 80.0 65.00 H40 WELDED , Casing Description String 0... String ID ... Top (ftKB) Set Depth (L.. Set Depth (ND) ... String Wt... String ... String Top Thrd SURFACE 10 3/4 9.794 31 2 3,249 0 2 678 4 45 50 K BTC ___ ... ,'. Casing Description String 0... String ID ... Top (ftK8) Set Depth (f_. Se[ Depth (TVD) 0 5/ D) ... String Wt _ String ... String Top Thrd ,. iPRODUCTION 7 6.151 31.7 9,289.3 6,697.0 ) 26.00 K -55 BTC CONDUCTOR, Tubing Strings 0-60 II � Tubing Desc pt String 0 String ID ... Top (ftKB) Set Depth (F... Set Depth (TVD) ... String Wt... String String Top Thrd TUBING X 31/2 2992 27.5 8,555.2 6,145.4 9.20 J55 1 AB MOD -BTC SAFETY VLV,_ Completion Details .. I Top Depth lig 1.9m (TVD) Top Inc/ Rani- Top (8KB) (kKB( (1 Item Description Comment ID (in) 27.5 27 5 - 0.18 HANGER FMC GEN I RETROFIT HANGER 3.500 GAS LIFT, - - - -- 2,398 .3,.. 1,944.2 1,790 ,' 46.25 SAFETY VLV CAMCO TRDP-1A-ENC SAFETY VALVE 2.812 SURFACE, : 8,467.7 6,076 ,' 38.40 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 31 8,506.1 6,105.5 36.05 PBR BAKER PBR w/ 10' STROKE 3.000 8,519.8 6,116. 36.15 PACKER BAKER HB RETRIEVABLE PACKER 2.890 GAS LIFT, 4,489 ' 8,533.0 6,127.5 36.25 SBR BAKER GSEAL SBR w/ OTIS PROFILE 2.813 Tubing Description String 0... String ID ... Top (ftKB) (Set Depth (T...ISet Depth (ND) ... String Wt... String ... String Top Thrd TUBING Orq na 3 1/2 2.992 8,554.3 8,917.9 6,430 7 9 20 K -55 FL4S GAS LIFT, : , Completion Details 5,662 .� _ _. - - - ___ -___ -. _ _ ILF Top Depth (TVD) Top Inel Nomi... GAS LIFT, - _ - Top (888) (9IKB) (') Item Description Comment ID (in) 6,348 8,554.3 6,144.7 36.41 SLICK STICK 3.000 GAS LIFT, -_. - __ - 8,559.3 6,148.7 36.44 PACKER BAKER HB -1 PACKER 2.890 7'060 - 8,673.5 6,240.2 37.37 BLAST RINGS CARBIDE BLAST RING JTS 2.992 Ili Mk 8,876.3 6,399.4 40.78 LOCATOR BAKER LOCATOR SUB 3.000 8,877.2 6,400.6 40.79 PACKER BAKER FB -1 PACKER 4.000 7,694 •�e. 9.7 - - - - -- - -. --- - 8,879.7 64f1 0 40.84 SBE BAKER SEAL BORE EXTENSION 2.813 8,899.7 6,41 7 1 41 24 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,916.3 6,429.5 41 S8 SOS BAKER SHEAR OUT SUB 2.992 GAS LIFT, Other In Hole (Vilit retrievable plugs, valves, pumps, fish, etc.) 8,453 Top Depth (TVD) Top Inc! NIPPLE, 8,468 --- - i Top(8KB) (ftK8) . r ) Description Comment Run Data ID (in) 9,193.0 6,6289 45.00 Fish Arm off OK -1 lost in Ratnae 4/12/1987 Perforations & Slots Shot E•___. -_ Top (TVD) Btm (TVD) Dens PBR, 8,506 -- - - -- , Top(8KB Bun 11[8_8)__ - (ftKB) Zone Date (sh... , - Comment 8,686.0 8,832.0 6,250.1 6,365.2 C4, C -3, C -2, 822/1981 4.0 SOS ENERJET 0 deg - , 1E-07 9,106.0 9,128.0 6,567 4 6,582.9 A-5, 1E -07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg t ''.... 9,106.0 9,128.0 6,567.4 6,582.9 A-5, 1E -07 8/27/1993 4.0 REPS... SOS Titan 2 1/2" H.0 SBR, 8,533 - ^ - _ __ _ 9,138.0 9,175.0 6,590.0 6,6162 A-4, 1E -07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg SLICK STICK, 9,138.0' 9,1/5 II 6 590 0 6,616.2 A-4, 1E-07 8/27/1993 I 4.0 REPE_.. SOS Titan 2 1/2" H.0 • 8,554 ` - PACKER, Notes: General _& Safety End Date Annotation ' 1 1/1 3/2004 NOTE: C -SAND LEAK aQ 8860', NEAR CSM 12/5/2010 NOTE: View Schematic w /Alaska Schematic9.0 (2 pages) r 8,598 PRODUCTION, - 8,667 PRODUCTION, LOCATOR, _-__ 8,876 _1!,_ PACKER, 8,877 -- s SBE, 8.880 - NIPPLE. 8,900 -- ASE ,, Mandrel Details SOS, Ind Mate Model ( ) OD ' Sent .__ Pod L YPe 60 SOS, 8,916- _ _ _. �.,;. To /T Depth Top V T S 0e TRO Run Stn Top�ftlCe) (Psi) Run Date Cam... REPERF, 1 2,398.4 2,106.9 4525 CAMCO KBUG 1 GAS LIFT GLV BK 0.156 1,265.0 11/11/2004 8,106 - 9,128 IPERF, 2 4,488 6 3,421.6 54.55 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,306.0 11/11/2004 9,106 - 8,128 REPERF• 3 5,662.4 4,171.9 47.81 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,408.0 1/3/2000 9,138 - 9,175 IPERF, .. _ PERF, 4 6,347.9 4,620.2 50.00 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 1/3/2000 9,138 5 7,068.6 5,078.9 51.33 CAMCO KBUG 1 GAS LIFT DMY BK -2 0.000 0.0 2/8/1992 Fish, 9,193 - - 6 7,693.6 5,497.1 44.03 CAMCO KBUG 1 GAS LIFT DMY BK -2 0.000 0.0 2/8/1992 7 8,452.8 6,065.1 38.59 OTIS L8 1'GAS LIFT DMY RM 0.000 0.0 1/3/2000 8 8,598.1 6,180.0 36.74 CAMCO KBUG 1 PROD 'DMY BK 0.000 0.0 1/5/2011 9 8,6672 6,235.2 37.34 CAMCO KBUG 1 PROD DMY None 0.000 0.0 2/25/1992 Closed PRODUCTION, 32 9,289N _ 10 8,860.1 6,386 9 40.45 CAMCO KBUG 1 PROD DMY BEK 0.000 0.0 11/11/2004 ExtP... TD, 9,310 .. _ ..__..._ Page 1 of 1 • • Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, May 03, 2011 3:51 PM To: 'Long, Jill W Subject: RE: 1 E -07 Sundry Addendum Thanks Jill ... will add this email to the well file and sundry application. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Long, Jill W [ mailto: JiII.W.Long @conocophillips.com] Sent: Tuesday, May 03, 2011 3:39 PM To: Schwartz, Guy L (DOA) Subject: 1E -07 Sundry Addendum Guy - As per our phone conversation earlier, here is the requested data on 1 E -07: Pressures The most recent bottomhole pressure at the lower kickoff point (8892' MD/6306' TVD) is estimated to be 2680 psi. This pressure estimation is based on static bottomhole pressure data acquired in October 2010. Assuming a gas gradient to surface, the maximum surface pressure anticipated is 2050 psi. An additional pressure reading is planned to take place prior to any cementing work. Variance Request In conjunction with the Sundry application for 1E -07, ConocoPhillips requests a variance from 20 AAC 25.112 (c) which requires a cement plug across and above all perforations to be abandoned in cased hole wells. The proposed plugging procedure for the 1 E -07 perforations does meet the overall objective of this section, providing an equally effective plugging of the well to prevent migration of fluids to other hydrocarbon zones or freshwater. A sand plug is planned to be placed over the A -sand perforations prior to cementing off the A -sand perforations as well as the C -sand perforations. The sand plug is being used in this particular situation to help ensure a better cement job can be achieved since cement needs to be placed below the tubing tail but also in the 3.5 "x7" annulus above the lower packer. Please let me know if additional information is needed. Thank you, Jill Long ConocoPhillips Alaska Drilling and Wells Office: 907-263-4093 Cell: 907 - 230 -7550 Fax: 918- 662 -6330 5/3/2011 Page l of l 4110 110 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); Saltrnarsh, 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- DRI... 5/3/2011 • • WELL LOG TRANSMITTAL PROACTIVE DIAgNoslic 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 F�� Fax: (907) 245 -8952 1) Caliper Report 23- Dec -10 1E-07 1 Report / EDE 50 -029- 20495 -00 2) it 206 1 777- '. � 71!L Signed : Date : '' � d Print Name: -Maio aas PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAX: (907)245 -88952 E -MAIL : pdsanchoraae(mernorvloq.Com WEBSITE : www.memCryIoq.CGm C:\Documents and Settings \Diane Williams \Desktop \Transmit Conoco .docx 1 • • 1 5- - Memory Multi - Finger Caliper Log Results Summary 1 Company: ConocoPhillips Alaska, Inc. Well: 1E-07 Log Date: December 23, 2010 Field: Kupar uk Log No.: 7460 State: Alaska I Run No.: 1 API No.: 50-029-20495-00 Pipel Desc.: 3.5" 9.2 Ib. J-55 AB MOD BTC Top Log Intvl1: Surface Pipel Use: Tubing Bot. Log Intvll: 8,916 Ft. (MD) 1 Pipe2 Desc.: 7" 26 Ib. K -55 BTC Pipe2 Use: Production Casing Top Log Intvl2: 8,916 Ft. (MD) Bot. Log Intv12: 9,084 Ft. (MD) Inspection Type : Corrosive & Mechanical Damage Inspection 1 COMMENTS : This caliper data is tied into the top of the shear out sub at 8,916' (Driller's Depth). 1 This log was run to assess the condition of the tubing and production casing with respect to corrosive and mechanical damage prior to CTD sidetrack operations. I The caliper recordings indicate the 3.5" tubing appears to be in good condition with respect to corrosive and mechanical damage, with no significant wall penetrations, areas of cross - sectional wall Toss or I.D. restrictions recorded. I The caliper recordings indicate the 7" production casing logged appears to be in poor condition with respect to corrosive and mechanical damage, with a probable hole recorded in joint 4 (9,049'). Recorded damage appears as a deep line of pits throughout the casing logged. No significant areas of cross - sectional wall loss or I.D. restrictions are recorded throughout the casing logged. A 3 -D log plot of the caliper recordings across I the production casing logged is included in this report. The engineer noted that the pin in the right angle drive sheared, was repaired, and sheared again during I logging operations. Since no additional replacements were available, no depth data could be recorded from - 1,400' to surface; therefore, any depths referenced in this report between surface and - 1,400' are speculative. 1 3.5" TUBING - MAXIMUM RECORDED WALL PENETRATIONS : No significant wall penetrations (> 18 %) are recorded. 1 3.5" TUBING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 4 %) are recorded. 1 3.5" TUBING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded. 1 7" CASING - MAXIMUM RECORDED WALL PENETRATIONS : Probable Hole ( 98 %) Jt. 4 @ 9,049 Ft. (MD) I Line of Pits ( 71%) (59 %) Jt. 3 @ 9,029 Ft. (MD) Line of Pits Jt. 2 @ 8,973 Ft. (MD) Line of Pits ( 55 %) Jt. 1 @ 8,939 Ft. (MD) Line of Pits ( 46 %) Jt. 5 @ 9,084 Ft. (MD) I ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 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 1 1 1 'o0 - otso 3oC5 -0 1 • • I 7" CASING - MAXIMUM RECORDED CROSS - SECTIONAL METAL LOSS : No significant areas of cross - sectional wall loss (> 8 %) are recorded throughout the casing logged. I 7" CASING - MAXIMUM RECORDED ID RESTRICTIONS : No significant I.D. restrictions are recorded throughout the casing logged. 1 1 1 1 i 1 1 1 1 1 1 , 1 Field Engineer: Wm. McCrossan Analyst C. Waldrop Witness: S. Ferguson 1 ProActive Diagnostic Services, Inc. / P.O. Box 1369, Stafford, TX 77497 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 1 1 1 • • PDS Multifinger Caliper 3D Log Plot ' Company : ConocoPhillips Alaska, Inc. Field : Kuparuk Well : 1 E -07 Date : December 23, 2010 1 Description : Detail of Caliper Recordings Across 7" Production Casing Logged. Comments Depth Maximum Penetration Maximum I.D. 3-0 Log Image Map 1ft:280ft 0 % 100 6 inches 7 46° 0° 90° 180° 270° 0° 1 F— Minimum I.D. —I 6 inches 7 Nominall.D. 1 . 6 inches 7 3.5" Tubing b oo, 4 li- 8920 ��- 1 ll , Joint 1 8930 J_ 1 Line of Pits iii 55% Wall 8940 1 — Penetration 1 8950 -- -if — -- i. 1 8960 ,:d - I� i Joint 2 8970 2 — ..,w- 1 ri7. -Line of Pits - ,_ _ _ 89 -- - - - -- - ill - — 1... 59% WaII i Penetration 1 1111 8990 ji .711 le 7. 9000 ' F -w • 1 Joint 3 9010' Line of Pits um 9020 '� "` 71% WaII -- Penetration A �� 9030 -- - Mr O 9040 41 I, — V IF_ - . ---- ---- ,..al � 9050 , -- — Joint 4 , �� Etq mrM IB Probable Hole i . I (9,049') 9060 11 - ill 98 % Wall t ` Penetration 9070 11 qiNe I 9080 I ; .` Joint 5 - 1 1 1 • 0 Correlation of Recorded Damage to Borehole Profile I I I 1 Pipe 1 3.5 in ( -73.7' - 8916.2') Well: 1 E -07 Pipe 2 7. in (8916.2' - 9080.0') Field: Kuparuk Company: ConocoPhillips Alaska, Inc. I Country: USA Survey Date: December 23, 2010 1 1 . Approx. Tool Deviation ■ Approx. Borehole Profile 1 -70 40 1 1174 1 ■. GEM 1 4 80 ill 2499 120 - 3728 I GLM 2 160 ' 4964 a G LM 3 u_ GLM 4 Z 200 6196 a 1 GLM 5 t 240 ' / S 7441 - 1 GLM 6 GEM 7 6Lik4 4 GLM 10 280 8763 1� 8916 5 9080 I 0 50 100 Damage Profile (% wall) / Tool Deviation (degrees) 1 1 Bottom of Survey = 5 1 1 1 1 • • 1 PDS Report Overview w �� Body Region Analysis I Well: 1E-07 Survey Date: December 23, 2010 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 I Country: USA No. of Fingers: 24 Tubing: 3.5 ins 9.2 ppf J-55 AB MOD-BTC Analyst: C. Waldrop Tubing: Nom.OD Weight Grade & Thread Nom.ID Nom.Upset Upper len. Lower len. 3.5 ins 9.2 ppf J -55 AB MOD -BTC 2.992 ins 3.5 ins 6.0 ins 6.0 ins Penetration(% wall) Damage Profile (% wall) I 300 Iwo Penetration body ` Metal loss body 0 50 100 250 0 1 200 150 I 100 A 50 50 0 I O to 20 to 40 to over GLM 1 E] 20% 40% 85% 85% Number of joints analysed (total = 295) 98 °' I 295 0 0 0 GLM 2 148 =. 1 Damage Configuration ( body ) 50 mu _ 40 ---- GLM 3 30 ---- 198 20 ---- GLM 4 _ I 10 ---- GLM 5 0 ---- GLM 6 24 I Isolated General Line Other Hole/ ._ Pitting Corrosion Corrosion Damage Pos. Hole GLM 7 f LM § Number of joints damaged (total = 44) GLM 10 I 44 0 0 0 0 Bottom of Survey = 282.9 1 1 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1 E -07 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. I Nominal I.D.: 2.992 in Country: USA Survey Date: December 23, 2010 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 0.1 -74 0 0.02 9 0 2.94 Pup 1 -70 0 0.03 13 2 2.95 Shallow Pitting. 2 -43 0 0.02 9 2 2.96 3 -14 0 0.03 11 3 2.96 • I 4 15 0 0.03 12 2 2.96 IN 5 47 0 0.03 11 2 2.99 • 6 78 0.03 0.03 12 2 2.94 ■ 7 110 0 0.04 18 2 2.97 Shallow Line of Pits. ■ 8 140 0 0.04 16 2 2.93 Shallow Line of Pits. Lt. Deposits. • I 9 171 0 0.04 14 2 3.00 Shallow Pitting. • 10 202 0 0.03 11 2 2.99 • ■ 11 233 0 0.03 11 2 2.97 • 12 264 0 0.02 9 2 2.95 I 13 294 0 0.02 9 2 3.00 14 326 0 0.03 11 1 3.00 • 15 358 0 0.03 11 2 2.97 ■ 16 390 0 0.03 11 3 2.95 17 420 0 0.02 8 2 2.96 I 18 452 0 0.03 11 2 2.95 l i 19 484 0 0.02 9 3 2.99 20 520 0 0.02 9 2 2.96 21 552 0 0.03 10 2 2.98 I 22 584 0 0.02 9 2 2.94 23 617 0 0.02 8 2 2.97 24 651 0 0.03 12 2 2.94 25 683 0 0.02 9 2 2.96 I 26 717 0 0.03 13 3 2.95 Shallow Pitting. 27 750 0 0.02 9 3 2.95 28 782 0 0.02 9 2 2.97 29 814 0 0.02 9 2 2.95 I 30 845 0 0.03 10 2 2.97 31 878 0 0.02 7 2 2.96 32 911 0 0.02 9 2 2.98 33 943 0 0.02 9 2 2.96 34 976 0 0.03 10 2 2.94 ■ I 35 1008 0 0.03 12 2 2.96 • 36 1041 0 0.03 12 3 2.99 ■ 37 1074 0 0.03 11 2 2.96 38 1107 0 0.02 8 2 2.95 I 39 1141 0 0.02 9 2 3.00 40 1174 0 0.02 8 2 2.97 41 1209 0 0.02 9 1 2.99 42 1236 0 0.02 9 2 2.96 43 1270 0 0.02 9 1 2.98 44 1303 0 0.02 9 2 2.96 45 1338 0 0.02 8 2 2.98 46 1372 0 0.02 9 2 2.96 I 47 1407 0 0.02 6 2 2.97 48 1442 0 0.02 9 2 2.95 49 1476 0 0.02 9 2 3.02 I Metal Loss Body 1 Page 1 Penetration 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1 E -07 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 23, 2010 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 50 1511 0 0.03 12 2 2.95 51 1545 0 0.02 7 2 2.96 52 1578 0 0.02 9 2 2.96 53 1611 0 0.03 10 2 3.00 I 54 1646 0 0.03 10 3 2.94 55 1678 0 0.02 9 2 2.95 56 1711 0 0.02 7 2 2.96 57 1744 0 0.02 9 3 2.94 58 1777 0 0.03 11 2 2.96 I 59 1811 0 0.02 7 2 2.96 60 1845 0 0.03 11 2 2.97 61 1876 0 0.02 9 1 2.98 62 1910 0 0.02 9 2 2.99 I 62.1 1942 0 0.02 9 1 2.99 Pup 62.2 1953 0 0 0 0 2.81 Camco TRDP -1 A -ENC SSSV 62.3 1966 0 0.02 9 1 2.97 Pup 63 1975 0 0.02 7 1 3.00 I 64 2002 0 0.02 7 2 2.97 65 2033 0 0.02 7 1 2.94 66 2064 0 0.02 9 2 2.95 67 2094 0.04 0.03 11 2 2.97 68 212 6 0 0.03 1 1 2 2.98 I 69 2156 0 0.03 11 2 2.97 70 2188 0 0.03 11 2 2.98 71 2217 0 0.02 9 2 2.94 72 2248 0 0.02 9 2 2.95 I 73 2278 0 0.02 8 2 2.96 74 2310 0 0.02 8 3 2.92 Lt. Deposits. 75 2341 0 0.02 8 2 2.93 76 2372 0 0.02 9 2 2.93 I 76.1 2402 0 77 2408 0 0. 0 0 0 2.89 GLM 1 (Latch @ 11:00) 03 12 2 2.95 78 2439 0 0.02 9 2 2.94 79 2469 0 0.02 9 2 2.93 80 2499 0 0.02 9 2 2.98 I 81 2529 0 0.02 8 2 2.95 82 2559 0 0.02 9 3 2.96 83 2590 0 0.03 12 3 2.95 84 2620 0 0.02 8 2 2.97 I 85 2652 0 0.03 11 2 3.00 86 2683 0 0.02 8 2 2.96 87 2714 0 0.03 11 3 2.95 88 2745 0 0.02 9 2 2.96 I 89 2775 0 0.03 10 2 2.96 90 2806 0 0.03 11 2 2.96 91 2836 0 0.03 12 2 2.96 92 2868 0 0.03 12 4 2.96 I 93 2896 0 0.03 10 2 2.97 94 2926 0 0.02 8 2 2.92 Lt. Deposits. 95 2957 0 0.03 12 3 2.96 I rat Metal Loss ion BBoody dy Page 2 Penet 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1 E -07 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: December 23, 2010 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 96 2987 0.03 0.04 14 2 2.96 Shallow Line of Pits. 97 3018 0 0.02 9 2 2.96 98 3049 0 0.03 11 2 2.96 7 99 3078 0 0.02 8 2 2.98 100 3110 0 0.03 11 1 2.96 IN ' 101 3140 102 3171 0 0.03 10 2 2.96 0 0.02 8 2 2.97 103 3202 0 0.03 11 1 2.94 • 104 3232 0 0.03 10 2 2.99 I 105 3263 0 0.02 8 2 2.94 106 3295 0 0.02 7 2 2.95 107 3326 0 0.03 11 2 2.92 Lt. Deposits. 108 3357 0 0.02 7 2 2.94 I 109 3387 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. 110 3417 0 0.02 9 2 2.96 111 3449 0 0.03 11 2 2.93 ■ 112 3481 0.03 0.04 15 3 2.93 Shallow Pitting. • I 113 3511 0 0.03 10 2 2.94 ■ 114 3541 0 0.03 11 2 2.92 Lt. Deposits. ■ 115 3572 0 0.02 9 3 2.96 ■ 116 3603 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. • 117 3635 0 0.03 11 2 2.95 I 118 3666 119 3697 0 0.02 7 2 2.98 0 0.03 10 2 2.99 • 120 3728 0 0.03 11 2 2.95 • 121 3758 0 0.03 11 2 2.93 • I 122 3789 0 0.03 11 2 2.97 123 3820 0 0.02 9 1 2.93 Lt. Deposits. 124 3849 U 0.03 13 3 2.93 Shallow Pitting. • 125 3880 0 0.03 11 2 2.94 ■ I 126 3911 0 0.02 9 3 2.92 Lt. Deposits. 127 3941 0 0.02 8 2 2.93 Lt. Deposits. 128 3972 0 0.02 7 2 2.92 Lt. Deposits. 129 4002 0 0.02 9 2 3.01 I 130 4034 0 0.03 12 2 2.96 131 4064 0 0.02 9 2 2.94 132 4095 0 0.03 10 3 2.92 Lt. Deposits. • 133 4126 0 0.03 12 2 2.91 Shallow Pitting. Lt. Deposits. 134 4156 0 0.02 7 2 2.94 I 135 4186 0 0.03 11 2 2.94 • 136 4217 0 0.03 11 2 2.92 Lt. Deposits. 137 4249 0 0.02 9 2 2.93 138 4279 0 0.03 11 2 2.94 • I 139 4308 0 0.05 18 2 2.92 Shallow Line of Pits. Lt. Deposits. • 140 4339 0 0.04 14 2 2.92 Shallow Line of Pits. Lt. Deposits. • ■ 141 4371 0 0.04 14 3 2.94 Shallow Pitting. • 142 4400 0 0.04 16 3 2.92 Shallow Pitting. Lt. Deposits. • 143 4430 0 0.03 13 3 2.96 Shallow Pitting. ■ ' 144 4461 0 0.03 12 2 2.89 Lt. Deposits. 144.1 4492 0 0 0 0 2.99 GLM 2 (Latch @ 9:00) I rat Metal Loss ion BoBody dy Page 3 Penet 1 t • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1E-07 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: December 23, 2010 I Joint Jt. Depth Pere. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (°/0 wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 145 4498 0.03 0.03 11 2 2.97 ■ 146 4528 0 0.03 11 2 2.96 • 147 4559 0 0.02 9 2 2.94 • 148 4590 0 0.04 17 3 2.95 Shallow Line of Pits. • 149 4621 0 0.03 11 2 3.01 • I 150 4653 0 0.03 12 2 2.94 Shallow Pitting. ■ 151 4684 0.03 0.04 15 2 2.94 Shallow Pitting. w 152 4716 0 0.02 9 2 2.95 153 4746 0 0.04 14 2 2.92. Shallow Line of Pits. Lt. Deposits. ■ I 154 4776 0 0.03 11 2 2.97 • 155 4807 0 0.03 11 2 2.95 ■ 156 4839 0 0.03 11 2 2.96 157 4870 0 0.02 9 2 2.93 Lt. Deposits. I 158 4901 159 4933 0 0.02 7 2 2.94 0 0.02 7 2 2.95 160 4964 0 0.03 11 2 2.95 • 161 4994 0 0.03 11 2 2.98 • I 162 5025 0 0.04 15 2 2.97 Shallow Pitting. ■ 163 5057 0 0.04 14 2 2.94 Shallow Pitting. • 164 5086 0 0.04 17 3 2.92 Shallow Line of Pits. Lt. Deposits. 165 5115 0 0.02 8 2 2.96 166 5146 0 0.02 9 2 2.94 I 167 5177 0 0.02 6 2 2.96 168 5208 0 0.02 9 2 2.93 Lt. Deposits. 169 5238 0 0.02 9 2 2.96 170 5270 0 0.02 7 2 2.99 3 I 171 5301 0.03 0.03 12 2 2.94 • 172 5332 0 0.02 9 3 2.91 Lt. Deposits. • 173 5363 0 0.03 11 2 2.93 • 174 5392 0 0.03 11 3 2.93 • I 175 5423 0 0.03 11 3 2.93 • 176 5454 0 0.02 9 2 2.94 • ■ 177 5484 0 0.03 11 2 2.94 • 178 5514 (1 0.03 11 3 2.97 , • 179 5545 0.03 0.04 16 2 2.96 Shallow Line of Pits. ■ I 180 5576 0 0.03 12 2 2.92 Lt. Deposits. • 181 5605 0 0.03 10 2 2.94 ■ 182 5634 0 0.03 13 2 2.92 Shallow Line of Pits. Lt. Deposits. 182.1 5665 0 0 0 0 2.90 GLM 3 (Latch @ 12:00) I 183 5672 0 0.03 12 3 2.92 Lt. Deposits. • 184 5702 0.03 0.03 11 2 2.99 185 5732 0 0.02 7 3 2.93 Lt. Deposits. 186 5762 0 0.03 11 3 2.89 Lt. Deposits. • I 187 5793 0 0.04 14 3 2.94 Shallow Pitting. • 188 5824 0 0.04 15 2 2.89 Shallow Line of Pits. Lt. Deposits. • ■ 189 5854 0 0.03 12 2 2.93 Lt. Deposits. • 190 5886 0 0.03 13 4 2.95 Shallow Pitting. • 191 5917 0 0.03 11 2 2.98 ■ � I 192 5948 0 0.03 13 3 2.88 Shallow Pitting. Lt. Deposits. • 193 5979 0 0.03 10 2 2.95 I Penetration Body Metal Loss Body Page 4 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1 E -07 Body Wall: 0.254 in Field: Kuparuk Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc I Nominal I.D.: 2.992 in Country: USA Survey Date: December 23, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % L oss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 194 6010 0 0.03 1 2 2 2.94 Shallow Pitting. • 195 6040 0 0.03 10 2 2.94 196 6072 0 0.02 7 2 2.96 il 197 6103 0 0.03 10 3 2.93 ■ 198 6134 0 0.03 11 2 2.96 • I 199 6166 0 0.03 10 2 2.93 Lt. Deposits. • 200 6196 0 0.03 1 2 2 2.96 Shallow Pitting. ■ 201 6227 0 0.03 1 2 2 2.95 Shallow Pitting. • 202 6258 0 0.02 9 1 2.93 Lt. Deposits. • I 203 6288 0 0.03 12 3 2.95 Shallow Line of Pits. • 204 6320 0 0.03 12 2 2.94 Shallow Pitting. 204.1 6350 0 0 0 0 3.08 GLM 4 (Latch @ 7:30) I 205 6356 0 0.04 14 3 2.91 Shallow Line of Pits. Lt. Deposits. 3 I 206 6388 0 0.02 8 2 2.96 207 6420 0 0.02 8 2 2.95 208 6451 0 0.03 10 2 2.96 • 209 6482 0 0.03 10 2 2.93 • 210 6514 0 0.02 9 2 2.96 • I 211 6544 0.04 0.03 11 2 2.95 212 6576 0 0.02 9 2 2.97 213 6606 0 0.03 13 2 2.97 Shallow Pitting. 214 6639 0 0.02 7 2 2.95 I 215 6669 216 6701 0 0.02 9 2 2.88 Lt. Deposits. 0 0.02 9 2 2.92 Lt. Deposits. 217 6731 0 0.03 11 1 2.94 218 6762 0 0.02 9 3 2.91 Lt. Deposits. I 219 6792 0 0.02 8 2 2.95 220 6824 0 0.02 9 2 2.92 Lt. Deposits. 221 6855 0 0.02 9 2 2.92 Lt. Deposits. 222 6885 0 0.02 9 2 2.89 Lt. Deposits. I 223 6916 0 0.02 9 2 2.95 224 6947 0 0.02 9 2 2.95 225 6978 0 0.03 11 3 2.93 Lt. Deposits. • 226 7010 0 0.03 13 2 2.94 Shallow Pitting. 227 7041 0.0 3 0.02 9 2 2.98 I 227.1 7072 0 0 0 0 3.01 GLM 5 (Latch @ 1:00) 228 7077 0 0.03 11 3 2.88 Lt. Deposits. • 229 7109 0 0.03 11 2 2.94 • 230 7139 0.03 0.03 11 2 2.92 Lt. Deposits. • 231 7168 0 0.03 11 2 2.91 Lt. Deposits. • 232 7198 0 0.03 11 3 2.92 Lt. Deposits. 233 7229 0 0.02 9 2 2.95 234 7259 0 0.03 11 2 2.93 Lt. Deposits. • I 235 7291 0 0.03 11 2 2.95 • 236 7322 0. 04 0.03 11 2 2.94 237 7350 0 0.02 9 2 2.90 Lt. Deposits. 238 7381 0 0.02 8 2 2.93 Lt. Deposits. 239 7413 0 0.02 8 2 2.94 I 240 7441 0 0.02 8 2 2.94 241 7472 0 0.02 9 2 2.96 t Bo I Penetra Loss ion Body 1 Page 5 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1 E-07 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: December 23, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) U % pse( Body Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 I 242 7504 0 0.03 13 2 2.92 Shallow Pitting. Lt. Deposits. • 243 7535 0 0.03 10 2 2.94 244 7566 0 0.02 8 2 2.92 Lt. Deposits. 245 7597 0 0.03 10 2 2.90 Lt. Deposits. ■ 246 7628 0 0.04 15 2 2.94 Shallow Line of Pits. Ni I 247 7659 0.03 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. • 247.1 7690 0 0.03 11 2 2.91 Pup Lt. Deposits. 247.2 7695 0 0 0 0 3.01 GLM 6 (Latch @ 6:00) ' 247.3 7702 0.04 0.03 10 1 2.91 Pup Lt. Deposits. • I 248 7707 0 0.02 9 2 2.92 Lt. Deposits. • 249 7738 0 0.03 11 2 2.92 Lt. Deposits. • 250 7770 0 0.02 9 2 2.93 251 7800 0 0.02 9 1 2.90 Lt. Deposits. I 252 7830 0 0.03 11 2 2.96 • 253 7862 0 0.04 14 2 2.97 Shallow Pitting. 254 7894 0 0.02 7 1 2.95 255 7925 0 0.02 9 2 2.92 Lt. Deposits. I ] I 256 7955 0 0.03 12 2 2.92 Shallow Pitting. Lt. Deposits. • 257 7988 0 0.03 10 2 2.91 Lt. Deposits. ■ 258 8018 U 0.02 9 2 2.96 • 259 8048 0 0.03 11 2 2.90 Lt. Deposits. • I 260 8080 0 0.02 9 3 2.91 Lt. Deposits. 261 8110 0 0.02 7 2 2.90 Lt. Deposits. 262 8142 () 0.03 11 2 2.92 Lt. Deposits. 263 8171 0 0.02 7 2 2.95 264 8201 0 0.02 9 2 2.95 I 265 8233 0 0.02 7 3 2.92 Lt. Deposits. 266 8261 0 0.03 11 2 2.92 Lt. Deposits. ■ 267 8294 0 0.04 14 2 2.95 Shallow Pitting. N 268 8324 0 0.02 9 2 2.92 Lt. Deposits. I 269 8356 0.03 0.03 11 2 2.92 Lt. Deposits. • 270 8385 0 0.03 10 2 2.93 so 271 8417 0 0.03 12 2 2.92 Lt. Deposits. • 271.1 8446 0 0.02 8 1 2.92 Pup Lt. Deposits. 1 271.2 8454 0 0 0 0 2.88 GLM 7 (Latch @ 2:00) 271.3 8462 0 0.03 11 0 2.92 Pup Lt. Deposits. 271.4 8468 0 0 0 0 2.81 Otis X Nipple 272 8469 0 0.03 12 2 2.94 Shallow Pitting. 272.1 8499 0 0.02 7 0 2.93 Pup Lt. Deposits. I 272.2 8506 0 0 0 0 0 3.00 Baker PBR Assembly 272.3 8519 0 0 0 2.89 Baker HB Retrievable Packer 272.4 8528 0 0.02 7 0 2.94 Pup 272.5 8534 0 0 0 0 2.81 Baker G -Seal SBR w/ Otis Profile 1 273 8538 0 0.02 7 2 2.93 Lt. Deposits. 273.1 8560 0 0 0 0 2.89 Baker HB -1 Packer 274 8565 0 0.02 9 2 2.91 Lt. Deposits. 274.1 8598 0 0 0 0 2.98 GLM 8 (Latch @ 10:30) 275 8605 0,0. I 0.03 11 2 2.95 276 8637 0 0.02 8 2 2.96 276.1 8668 ) 0 0 l 2.88 GLM 9 (Latch @ 11:00) ' Penetration Body Metal Loss Body Page 6 1 1 1 • • PDS REPORT JOINT TABULATION SHEET Pipe: 3.5 in 9.2 ppf J -55 AB MOD -BTC Well: 1 E -07 Body Wall: 0.254 in Field: Kuparuk I Upset Wall: 0.254 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 2.992 in Country: USA Survey Date: December 23, 2010 I Joint Jt. Depth Pen. Pen. Pen. Metal Min. Damage Profile No. (Ft.) Upset Body % Loss I.D. Comments (% wall) (Ins.) (Ins.) % (Ins.) 0 50 100 277 8673 0 0.02 7 2 2.95 278 8706 0 0.02 7 2 2.94 II 279 8735 0 0.01 6 2 2.93 280 8763 0 0.02 7 2 2.93 O 281 8792 O 0.01 6 2 2.93 Lt. Deposits. 1 I 282 8821 O 0.02 8 2 2.92 Lt. Deposits. C 282.1 8851 0 0.03 11 2 2.93 Pup 282.2 8860 O 0 0 0 2.89 GLM 10 (Latch @ 3:30) 282.3 8867 0 0.02 8 1 2.95 Pup • 282.4 8876 0 0 0 0 4.00 Baker FB-1 Packer 282.5 8883 0 0 0 0 2.81 Baker SBE 282.6 8884 0 0.02 9 2 2.90 Pup Lt. Deposits. • 282.7 8899 0 0 0 0 2.75 Camco D Nipple No Go I 282.8 8902 0 0.01 5 1 2.88 Pup Lt. Deposits. 282.9 8916 0 0 0 0 2.99 Baker SOS I Penetration Body Metal Loss Body 1 1 1 1 1 II 1 i 1 Page 7 1 1 1 • • PDS REPORT JOINT TABULATION SHEET I Pipe: 7. in 26.0 ppf K -55 BTC Well: 1 E -07 Body Wall: 0.362 in Field: Kuparuk I Upset Wall: 0.362 in Company: ConocoPhillips Alaska, Inc. Nominal I.D.: 6.276 in Country: USA Survey Date: December 23, 2010 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 1 8916 0 0.20 55 5 6.22 Top of 7" Production Casing. Line of Pits. 11111M11111111 2 8958 0 0.21 59 5 6.21 Line of Pits. Lt. Deposits. sinow■ 3 8998 0 0.26 71 6 6.17 Line of Pits. Lt. Deposits. Imo 4 9039 0 0.35 98 8 6.22 Probable Hole! iron 5 9080 0 0.17 46 3 6.21 Line of Pits. Lt. Deposits. I I Penetration Body Metal Loss Body 1 1 1 1 1 1 1 1 1 1 1 Page 1 1 1 1 • • 1 PDS Report Cross Sections 1 a I Well: 1E-07 Survey Date: Tool Type: December 23, 2010 Field: Kuparuk UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf K -55 BTC Analyst: C. Waldrop 1 1 Cross Section for Joint 4 at depth 9049.140 ft Tool speed = 47 Nominal ID = 6.276 I Nominal OD = 7 Remaining wall area = 92% Tool deviation = 43° 1 1 1 1 i 1 1 414 110 1 1 Finger = 8 Penetration = 0.353 ins Probable Hole 0.35 ins = 98% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 j • • i VS. PDS Report Cross Sections I Well: 1E-07 Survey Date: December 23, 2010 Field: Kuparuk Tool Type: UW MFC 24 Ext. No. 212330 Company: ConocoPhillips Alaska, Inc. Tool Size: 1.69 Country: USA No. of Fingers: 24 1 Tubing: 7 ins 26 ppf K -55 BTC Analyst: C. Waldrop i 1 Cross Section for Joint 3 at depth 9029.210 ft Tool speed = 46 Nominal ID = 6.276 I Nominal OD = 7 Remaining wall area = 94% /� Tool deviation = 41° f 1 1 li 1 I 1 I I Finger = 6 Penetration = 0.259 ins Line of Pits 0.26 ins = 71% Wall Penetration HIGH SIDE = UP 1 1 1 1 1 I 1,-- I KUP 1E-07 Well bore 0;114 1I Attributes ngle & MD TD AlaSke.Inc bore API/UWI Field Name Well Status Inc! (7 ND ptKB) Act Btm (RKB) , 500292049500 KUPARUK RIVER UNIT PROD 56.75 3,700.00 9,310.0 '"" Comment H2S (ppm) Date Annotation End Date KB•Grd (K) Rig Release Date I Well Coneo. - 1E 12/5/2010 8 39:51 AM SSSV: TRDP Last WO: 2/8 /1992 3949 10/13!1980 SIXlemetA Actual A ast Ta a g : Last Depth (9B) End Date AAnnotation Last MOd... End DDate - ( 9,197.0 6/13/2007 Rev Reason: FORMAT UPDATE Imosbor 12/5/2010 Casing Strings HANGER, 28 Casing Description String 0... String ID ... Top (ftB) Set Depth (f... Set Depth (TVD) ... String Wt... Sting... String Top Thrd f CONDUCTOR 16 15.060 0.0 80.0 80.0 65.00 H - 40 WELDED Casing Description Stung 0... String ID ... Top (MOB Set Depth p... Set Depth (TVD) ... String WL.. String... Sai g Top Thrd - SURFACE 103/4 9.794 31.2 3,249.0 2,678.4 45.50 K - 55 BTC Casing Description String 0... String ID ... Top (MB) Set Depth (f... Set Depth (TVD) ... String Wt.. String... String Top Thrd PRODUCTION 7 6.151 31.7 9,289.3 6,697.0 26.00 K -55 BTC CONDUCTOR, Tubing Strings 0-80 Tubing Description String 0... String ID ... Top (888) Set Depth p... Set Depth (TVD) ... String WL.. String... Stung Top Bird I -- TUBING 3 1/2 2.992 27.5 8,555.2 6,145.4 9.20 J-55 AB MOD -BTC SAFETY vLV, Com . Ietion Details 1,944 Tap Deem (iVD) Top Ind Nomi... Top (RKB) ('B) (°) Item Description Comment ID (In) 27.5 27.5 - 0.18 HANGER FMC GEN I RETROFIT HANGER 3.500 I/ GAS LIFT. zags 1,944.2 1,790.7 46.25 SAFETY VLV CAMCO TRDP- IA -ENC SAFETY VALVE 2.812 SURFACE, 8,467.7 6,076.7 38.40 NIPPLE OTIS X SELECTIVE LANDING NIPPLE 2.813 314249 8,506.1 6,105.5 36.05 PBR BAKER PBR w/ 10' STROKE 3.000 8,519.8 6,116.7 36.15 PACKER BAKER HB RETRIEVABLE PACKER 2.890 Go a 4485 GAS LIFT. # - 8,533.0 6,127.5 36.25 5BR BAKER G - SEAL SBR w/ OTIS PROFILE 2.813 FT I TUBING Description ,n I� IS ID ... I T $ 6 1 54.3 I 8,917.9 9.20 Set Dep D) ... ISti9 0 ..ISmng .. IShing Tops Tint . ,_ Completion Details 5,662 Top Depth (TVD) Top Ina Noml... I GAS LIFT, . - Top (t88) ft ) ( °) hem Descnplon Comment ID (in) 8,554.3 6,144.7 36.41 SLICK STICK 3.000 GAS LFt, i 8,559.3 6,148.7 36.44 PACKER BAKER HB-1 PACKER 2.890 1,069 8,673.5 6,240.2 37.37 BLAST RINGS CARBIDE BLAST RING JTS 2.992 4 8,876.3 6,399.4 40.78 LOCATOR BAKER LOCATOR SUB 3.000 Gas LIFT, 6,400.0 40.79 PACKER 4.000 7 89a 8,879.7 6,401.9 40.84 SBE BAKER FB -1 PACKER BAKER SEAL BORE EXTENSION 2.813 - -� 8,899.7 6,417.1 41.24 NIPPLE CAMCO D NIPPLE NO GO 2.750 8,916.3 6,429.5 41.58 SOS BAKER SHEAR OUT SUB 2.992 GAS Other In Hole ireline retrievable plugs, valves, pumps, fish, etc.) • 0 - Top Depth (TVD) Top and NIPPLE, 8,466 Top (RKB) () (°) Description comment am Date ID fry 9,193.0 6,628.9 45.00 Fish Arm oft OK -1 lost in Rathole 4/12/1987 Perforations & Slots t Shot Dens PBR. 8,506 } Top (Nub) 81m price) Top p1 (TV) 13110 (fig (TVD) Zone Date h Type Comment PACKER, 6.520 8,686.0 8,832.0 6,250.1 6,365.2 C -4, C -3, C-2, 8/22/1981 4.0 IPERF SOS ENERJET 0 deg 1E-07 IM 9,106.0 9,128.0 6,567.4 6,582.9 A-5, 1E-07 8/22/1981 4.0 IPERF SOS ENERJET 0 deg i SER.8,533 9,106.0 9,128,0 6,567.4 6,582.9 A-5, 1E -07 8/27/1993 4.0 REPS... SOS Titan 21/2 "H.0 9,138.0 9,175.0 6,590.0 6,616.2 A-4, 1E-07 8/22/1981 4.0 IPERF SOS ENERJET O deg SLICK STICK, y 9,138.0 9,175 -0 6,590.0 6,616.2 A -0, 1E -07 8/27/1993 4.0 REPS- SOS Titan 21 /2 "HC 8,554 1, PACKER, 8,559 ' Notes: General & Safety i End Date Annotation 1 11/13/2004 NOTE: C -SAND LEAK @ 8860', NEAR CSM 12/5/2010 NOTE: View Schematic w /Alaska Schematic9.0 (2 pages) PRODUCTDN, 8,598 PRODUCTpN, [ 1 i ._4= i ti 8.887 IPERF, 8,686.8,832 I PRODUCTION, 8,860 LOCATOR, I 8.876 PACKER, 8,877 586, 8,880 IMO= NIPPLE, 8,900 a t&ri Mandrel Details 1 Top Depth Top Pon SOS, 8,916 (TVD) Intl 00 Valve Latch Size 150 Run Sin lop (NCB) IRIB) () Make Model 1 Sere Type Type (In) IPSO RIn Date Cam.. .156 1,265.0 11/11/2004 REPERF, 1 2,398.4 2,106.9 45.25 CAMCO KBUG 1 GAS LIFT GLV BK 0 9,106 - 9128 IPERF, 2 4,488.6 3,421.6 54.55 CAMCO KBUG 1 GAS LIFT GLV BK 0.188 1,306.0 11/11/2004 9,106 REPERF, 3 5,662.4 4,171.9 47.81 CAMCO KBUG 1 GAS LIFT GLV BK 0.250 1,408.0 1/3/2000 9,1385,175 IPERF, 4 6,347.9 4,6202 50.00 CAMCO KBUG 1 GAS LIFT OV BK 0.250 0.0 1/3/2000 9,1385175 5 7,068.6 5,078.9 51.33 CAMCO KBUG 1 GAS LIFT DMY BK -2 0.000 0.0 2/8/1992 Fish, 9,193 6 7,693.6 5,497.1 44.03 CAMCO KBUG 1 GAS LIFT DMY BK -2 0.000 0.0 2/8/1992 7 8,452.8 6,065.1 38.59 OTIS LB 1 GAS LIFT DMY RM 0.000 0.0 1/3/2000 8 8,598.1 6,180.0 36.74 CAMCO KBUG 1 PROD DMY BEK 0.000 0.0 1/1/2002 posed 9 8,667.2 6,235.2 37.34 CAMCO KBUG 1 PROD DMY - None 0.000 0.0 2/25/1992 Closed PRODUCTION, TD, 8,310 325,289 10 8,860.1 6,386.9 40.45 CAMCO KBUG 1 PROD DMY BEK 0.000 0.0 11/11/2004 ExtP_. ' ConacoPhillips a P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16~', 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7~' Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: il~~ ~, ~~ ~u~~~ Gd~11SS1011 ~sk~ ~ Gas G ~C~i'~Ta~6 Aga-o8o iE-~7 Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRil). 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 25~' 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6~', 7th, 8~' 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Peny 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 7/16110 1 A. 1 C.1 E PAD r Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft ai 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" Na 4" n/a 2.1 7/8/2010 1 C-01 50029205260000 1801280 SF Na 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" Na 8.5 7/6/2010 1 C-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 1 C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1 E-02 50029204720000 1800500 21" n/a 21" n/a 1.7 7R/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 1 E-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" n/a 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" Na 1" Na 1.7 7/7/2010 1 E-21 50029208920000 1830020 3" Na 3" Na 2.6 7/7/2010 1E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/7/2010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1E-29 50029208280000 1821540 7" n/a 7" n/a 2.5 7/8/2010 SchlumbergBr RECE\\JEO DEC 2, \) îOO~ . J\\IIIiCaOl\ 8. GaS (;OIlS. ~ . . ~ .. ' r~ 2FìÎ\f, . \'i t..\ '2 ~ " . U LI ~ iâ..\t..u'.:;::.·n l Ù. \~ '" U - S4f' A\~~.-..;1g;;~ <0,1 . v-)v Schlumberger -DCS 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well Job# Log Description Date 10-02 ~ 11166733 INJECTION PROFILE 11/30/05 1E-07 ·1D(}D~) 11154107 PROD PROFILE W/DEFT 01/01/06 1E-105 11141240 INJECTION PROFILE 12/30/05 1G-12 11144060 PROD PROFILE W/DEFT 12/28/05 1 L-28 11141239 PROD PROFILE W/DEFT 12/29/05 38-08 11154108 PRODUCTION PROFILE 01/02/06 38-02 11154109 INJECTION PROFILE 01/03/06 NO. 3644 Company: Field: BL 01/05/06 Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 '" 0 cttJ \~b Kuparuk Color 1 1 1 1 1 1 1 S,GNED:ðGrirrtl1av) Please sign and return one copy of this transmittal to Beth at the above address or fax to (907) 561-8317. Thank you. DATE: I~ 9016 CD ~- [goosoo MEMORANDUM TO: Julie Heusser, Chairman State of Alaska Alaska Oil and Gas Conservation Commission DATE: January 4, 2001 THRU: Tom Maunder, ~-~~~ P. I. Supervisor ~'l~,cc~t FROM: Chuck Scheve; SUBJECT: Petroleum Inspector Safety Valve Tests Kuparuk River Unit 1E Pad Thursday~ January 47 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 wellhouses 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: Earnie Barndt AOGCC Rep: Chuck Scheve Submitted By: Chuck Scheve Date: Field/Unit/Pad: Kuparuk / KRU / 1E Pad Separator psi: LPS 85 I-IPS 1/4/01 llllll/l Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GINJ, Number Number PSI PSI Trip Code Code Code Passed cns or CYCLE 1E-02 1800500 85 70 60 P P OIL 1E-03 1800560~ 85 70 45 P P OIL 1E-05 1800580 1E-06 1800780 1E-07 1800800 851 70 0 2 P OIL 1E-10 1820360 1E-11 1820510 1E-12 1820600 1 E- 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 1 E-23 1821840 1E-24A 1971870 85 70 70 P 4 OIL 1E-26 1821660! 1E-28 18215801 1 E-29 1821540 1E-31 1971380 85 70 65 P P OIL 1E-33 1971510 1E-34 1971660 85 70 50' P P OIL 1E-36 1982130 85 70 60 P P OIL Wells: 9 Components: 18 Failures: 2 Failure Rate: 11.1%El 90 var Remarks: Pilot on 1E-07 frozen. Portable heater placed on pilot until catalytic repaired Surface Safer7 on 1E-24A had slow leak, valve to be serviced and retested. 1/9/01 Page 1 ofl 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 John H Spaulding~ Petroleum Inspector FROM: 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, 1 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. Barndt AOGCC Rep: John H. Spaulding Submitted By: John H. Spauld Date: Field/Unit/Pad: Kupmaxk/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 GAS or CYCLE 1E-02 1800500 91 70 65 P P OIL 1E-03 1800560 SI 1E-05 1800580 1E-06 1800780 SI 're-u/--- 1800800 91 60 55 P P OIL 1E-10 1820360 1E-11 1820510 1E-12 1820600 SI 1 E- 14 1820790 1E-18 1830160 91 60 46 P P OIL 1E-19 1830170 1E-20 1830050 91 60 48 P ~ OIL 1E-21 1830020i 1 E-23 1821840 1E-24A 1971870 91 70 70 e p OIL 1 E-26 1821660 SI 1E-28 1821580 SI 1 E-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% ID 90 var Remarks: 8/7/00 Page 1 of 1 svs kuparuk kru le 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/U~ad: Kupantk~uparuk 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 CYCLE 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 30001 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 1841630 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 70 P P OIL 2X- 16 1841720 2X-17 1951710 96 60 50 P P 2X- 18 19516001 96 60: 50 P P OIL 2X-19 1951750! Wells: 10 20 Failures: 1 Failure Rate: 5.0% ~] 90 Day Remarks: 8/15/00 Page 1 of 1 svs kuparuk kru 2x 7-22-00js.xls STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: Operation Shutdown ~ Stimulate X Plugging ~ Pull tubing ~ Alter casing Repair well Perforate Other 2 Name of Operator ARCO Alaska, In(;. 3 Address P. O. Box 100360, Anchorage, AK 99510 5 Type of Well: Development X Exploratory _ Strat~graph~c _ Service Location of well at surface 893' FSL, 631' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1173' FNL, 1373' FEL, Sec. 15, T11N, R10E, UM At effecbve depth 987' FNL, 1028' FEL, Sec. 15, T11N, R10E, UM At total depth 969' FNL~ 996' FEL~ Sec. 15~ T11N~ R10E~ UM 12. Present well condition summary Total Depth: measured true vertical 9 31 0 feet 671 1 feet Plugs (measured) 6. Datum elevation (DF or KB) RKB 105 7. Umt or Property name Kuparuk River Unit 8. Well number 1E-07 9. Permit number/approval number 80-80 feet 10. APl number 5 o-029-20495 11. F~eld/Pool Kuparuk River Field/Oil Pool None 0RIGINA Effective depth: measured 92 5 8 true vertical 6674 feet feet Junk (measured) Arm off OK-1 in rathole Casing Length Size Structural Conductor 8 0' 1 6" Surface 3222' 10 3/4" Intermediate Production 92 62' 7" Liner Perforation depth: measured 8686'-8832', true vertical 6250'-6364', Cemented Measured depth True vertical depth 200 Sx PF 80' 80' 1500 Sx Fondu & 3249' 2680' 350 Sx AS II 315 Sx Class G 9289' 6695' 9106'-9128', 6567'-6583', Tubing (s~ze, grade, and measured depth) 3.5", 9.2#/ft., K-55 w/ tail @ 8906' Packers and SSSV (type and measured depth) 9138'-9175' 6590'-6616' RECEIVED S EP 1994 kt~$ka b~l & Gas Cons. Commission Anch0ra~e PKR: Baker HB @ 8520', Baker HB-1 @ 8559' Baker FB-1 @ 8866'; SSSV: Camco TRDP-1AENC @ 1944' 13. Stimulation or cement squeeze summary Fracture A45 Sands Intervals treated (measured) 9106'-9128', 9138'-9175' Treatment description including volumes used and final pressure 24.5 Mlbs 16/20 & 117.5 Mlbs 12/18 ceramic proppant. Final WHTP 3000 psi. 14. Reoresentative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Subsequent to operation 15. Attachments Cop~es of Logs and Surveys run __ Daily Report of Well Operations X 85 52 4 1200 213 350~-~ 350 4 1200 114 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. S,~lned .Z~(~~ J/~7_ /~~C~_TitIe Wells Form 10-40~ ~Rev 06/15/88(/ Superintendent SUBMIT IN DUPLICATE 'ARC~) Alaska, Inc. ( O KUPARUK RIVER UNIT WELL SERVICE REPORT WELL DATE DAY ! TIME DESCRIPTION OF WORK CONTRACTOR/KEY PERSON OPERATION AT REPORT TIME / I FIELD EST: I~'CCOMPLETE E] INCOMPLETE I $ / Z ~, LOG ENTRY C ACCUMULATED COST $ PAGE 1 OF r--] CHECK THIS BLOCK IF SUMMARY CONTINUED ON BACK Weather OF I Chill Factor Report ITemp' OF[visibility I Wind Vel. knots j Signed_.~_ "z/ miles I AR3B-7031 298-3486 ( STATE OF AI.ASKA ( ALASKA OIL AND GAS ~SERVATION COMMIS~q ~ ? REPORT OF SUNDRY WELL OPERATIONS Operation Shutdown Stimulate Plugging Perforate × Alter casing Repair well Other 1. Operations Performed: Pull tubing 2. Name of Operator ARCO Alaska. Inc. 3. Address P. O. Box 100360, Anchorage, AK 99510 4. Location of well at surface 893' FSL, 631' FEL, Sec. 16, T11N, R10E, UM At top of productive interval 1173' FNL, 1373' FEL, Sec. 15, T11N, R10E, UM At effective depth 987' FNL, 1028' FEL, Sec. 15, T11N, R10E, UM At total depth 969' FNLr 996' FEL~ Sec. 15r T11Nr R10E~ UM 12. Present well condition summery Total Depth: measured 9 31 0 feet true vertical 671 1 feet 5. Type of Well: Development X Exploratory _ Stratigraphic _ Service 6. Datum elevation (DF or KB) RKB 105 feet 7. Unit or Property name Kuparuk River Unit 8. Well number 1 E-07 9. Permit number/approval number 80-80 10. APl number 50-029-20495 11. Field/Pool Kuparuk River Field/Oil Pool Plugs (measured) None Effective depth: measured 9 2 5 8 feet true vertical 6 6 74 feet Junk (measured) Arm off OK-1 in rathole Casing Length Size Structural Conductor 8 0' 1 6" Surface 3222' 10 Intermediate Production 9 2 6 2' 7" Liner Perforation depth: measured 8686'-8832', true vertical 6250'-6364', 3/4" Cemented Measured depth True vertical depth 200 Sx PF 80' 80' 1500 Sx Fondu & 3249' 2680' 350 Sx AS II 315 Sx Class G 9289' 6695' 9106'-9128' 6567'-6583' Tubing (size, grade, and measured depth) 3.5", 9.2#/ft., K-55 w/ tail @ 8906' Packers and SSSV (type and measured depth) 9138'-9175' 6590'-6616' RECEIVED S E P 2 8 Alaska O~l & uas ~,uns. ~,ummisston Anchorage PKR: Baker HB ~ 8520'~ Baker HB-1 ~ 8559' Baker FB-1 ~ 8866'; $SSV: Camco TRDP-1AENC ~ 1944' 13. Stimulation or cement squeeze summary Reperforated "A" sands on 8/27/93 @ 4 spf. Intervals treated (measured) 9106'-9128', 9138'-9175' Treatment description including volumes used and final pressure N/A 14. Re_oresentative Daily Average Production or In!action Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 38 32 31 1400 136 Subsequent to operation 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 89 71 10 1400 137- 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~lned '~~'~' ~~ Title Senior Engineer Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE ARCO Alaska, Inc( ) Sul~ldlaty of Atlantic Richfield Coml~ny CONTRACTOR REMARKS WELL SERVICE REPORT IFIELD - DISTRICT. STATE OPERATI~N AT REPOR.¥ TIME JOAYS I DATE - · CONTINUED ON BACK w....._ I'"'~ .~ ~'"~'~lv,~~ =,,..I~'~'v''' -i~"~~~ REMARKS CONTINUED: DESCRIPTION DAILY ACCUM. TOTAL CAMCO OTIS SCHLUMBERGER DRESSER. ATLAS - DOWELL HALLIBUrtON ARCTIC COIL TUBING FRACMASTE. R B. J. HUGHES Roustabouts I~/~;;;~ j~,~) / ~ ~ Diesel ~ I ' 9 / Methanol Supe~ision Pr~J°b Safety MeetingZ~ ~ R~r~!vrD AFE ~/~ ~ ~ ~ ~ S EP ~ ~ , .' TOTAL FIELD ES~MA~ [ ~~/ /~ ~ ~ / Sign~ ( ORIGINAL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operabons performed: Operation Shutdown __ Pull tubing X Alter camng Stimulate __ Plugging __ Perforate Repair well __ Other__ 2. Name of Operator ARCO Alaska, In~, 3. Address P. O. Box 100360, Anchorage, AK 99510 5. Type of Well: Development X Exploratory _ Strabgraph~c _ Service 4 Location of well at surface 893' FSL, 631 FEL, SEC 16, T11N, R10E, UM At top of producbve interval 1173' FNL, 1373' FEL, SEC 15, T11N, R10E, UM At effective depth 987'FNL, 1028' FEL, SEC 15, T11N, R10E, UM At total depth 969' FNL, 996' FEL, SEC 15, T11N, R10E, UM 12 Present well condition summary Total Depth: measured 931 0' true verhcal 671 1 ' feet feet Plugs (measured) 6. Datum elevabon (DF or KB) RKB 105' 7. Umt or Property name Kuparuk River Unit 8. Well number 1 E-07 9. Permit number/approval number 80-80/Conserv Order ~261 10. APl number 50-029-20495 11. F~eld/Pool Kuparuk River Oil Pool Effective depth: measured 9258' true vertical 6674' feet feet Junk (measured) 13. Casing Length S~ze Structural 8 0' 1 6" Conductor Surface 3222' 1 0-3/4" Intermediate Production 9262' 7" L~ner Perforation depth: measured 8686'-8832', 9106-9128, 9138'-9175' MD true vertical 6250'-6364', 6567'-6583', 6590'-6616' TVD Tubing (s~ze, grade, and measured depth) '3-1/2" 9.2# J-55 @ 8918' Cemented 200 SX PF Measured depth True verbcal depth 80' 80' 1500 Fondu 3249' 2680' & 35O SX AS II 315 SX CLASS G 9289' 6695' RECEIVED J U L - ? 1992 Alaska 0il & Gas Cons. Commissi Packers and SSSV (type and measured depth) BAKER FHL RETR PKR @ 8520' MD,BAKER FB-1 PER @ 8877' MD, CAMCO TRDP-1AENC SSSV @A~40~'~I~ Stimulabon or cement squeeze summary Intervals treated (measured) Treatment descripbon Including volumes used and final pressure 14 Representabve Dally Average Producbon or InJection Dat~ Od-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation Subsequent to operation 15. Attachments ~ 16. Status of well clasmflcabon as: Cop~es of Logs and Surveys run -- I Water Injector __ Dady Report of Well Operations X O~1 X Gas __ Suspended :17. I hereby certify that the foregoing ~s true and correct to the best of my knowledge. Sl~ned ~/~.~,.~ /~;f-~.~/)t £/,~ r, ~..t/ T~tle Area Drillin~l En~l~neer Form 10-404 Rev 05/17/89 Service Date SUBMIT IN DUPLICATE ARCO ALASKA INC. DAILY OPERATION~ PAGE: 1 WELL: BOROUGH: UNIT: FIELD: LEASE: API: PERMIT: 1E-07 NORTH SLOPE KUPARUK RIVER KUPARUK RIVER 50-029-20495 APPROVAL: 80-80 ACCEPT: 02/01/92 01:02 SPUD: RELEASE: 02/08/92 09:02 OPERATION: WORKOVER DRLG RIG: NONE WO/C RIG: NORDIC 1 02/02/92 (1) TD: 0 PB: 9258 02/03/92 (2) TD: 0 PB: 9258 KILLING WELL MW:12.3 WBM MOVE RIG FROM 1E-03 TO 1E-07,ACCEPT RIG AT 13:30 HRS 1-JAN-92,LEVEL RIG,ND LEAKY SWAB VALVE, REPLACE SAME,MU HARD LINE FROM RIG TO PRODUCTION FLOW LINE & TANKS,RU LUBRICATOR & PULL VR PLUG FROM ANNULAR VALVE,MU KILL LINE,RU LUBR., TIGHTEN LEAKING FLANGE ON WING VALVE,ADJUST TIMING ON SURFACE SAFETY VALVE AND PULL BPV, RD LUBR, CHECK PRESS, SITP-0,SIAP=2800,SICP=950,PRESS SSSV LINE TO OPEN SSSV, EQUALIZE TBG AND ANNULUS, SITP=2650,SICP=2700,TEST HARD LINE TO FLOW LINE TO 900 PSI,DISCUSS KILL PLANS WITH DSO AND RIG CREW, BLEED GAS DN FLOW LINE,AT 1 HR ANNULUS AT 670 PSI,TBG AT 2450 PSI,LINE UP TO PUMP SEAWATER DN TBG, BLEED OFF GAS HEAD,PUMP 142 BBLS SEAWATER DN TBG, BLEED GAS OFF ANNULUS TO FLOW LINE, SI & INJECT 25 BBLS DN TBG, CONT CIRC SEAWATER TO SURFACE,TAKE RETURNS THRU CHK ATTEMPT TO INJECT SW INTO FORMATION, PRESS UP TO 2500 PSI,SM LEAK,MONITOR PRESS FREEZE PROTECT FLOW LINE WITH 45 BBL$ DIESEL, CLEAN SW F/PITS, TRANSFER MUD TO PITS,CONDITION MUD TO 12.3 PPG, SITP=l125, SICP=1000,CIRC KILL WT MUD TAKING SW RETURNS THRU CHOKE AND DN FLOWLINE WORK PIPE TO FREE AT TBG CUT MW:12.8 WBM CONT CIRC 12.3 PPG MUD, FREEZE PROTECT FLOW LINE, BRING ON ADDITIONAL MUD,WT UP TO 12.3 PPG,CONT CIRC, SI AND MONITOR, SITP=SICP=45,WT UP MUD TO 12.8,CIRC AT 4 BPM/1400 PSI, RETURNS AT 12.8,SI AND MONITOR WELL, NO FLOW, SET BPV, ND TREE, NU BOPE, TEST BOPE TO 3000 PSI,REPAIR CHECK VALVE ON CHOKE, OK, BOLDS,RU TO PUMP DN TBG, PULL 120K#,UNABLE TO PULL SBR, WORK PIPE WHILE CIRC AT 4 BPM/1400 PSI,WILL NOT PULL FREE, CLOSE ANNULAR, PRESS UP TO 1500 PSI WHILE PULLING 120K~,NO GO, WAIT ON SWS,CONT TO WORK PIPE WHILE WAITING, RU SWS,RIH W/CCL AND JET CUTTER, TIE IN AND MAKE CUT AT 8517' (1 JT ABOVE SBR) WHILE PULLING 120K#,POH W/CUTTER CIRC TOOLS THRU SSSV, PU TBG TO 120K~,TBG NOT FREE,WORK PIPE WHILE CIRC JUL - 7 199 Alaska Oil & Gas Cons. Commission Anchorage WELL : 1E-07 OPERATION: RIG : NORDIC 1 PAGE 2 : 02/04/92 (3) TD: 0 PB: 9258 02/05/92 (4) TD: 0 PB: 9258 02/06/92 (5) TD: 0 PB: 9258 02/07/92 (6) TD: 0 PB: 9258 WAIT ON 5.75" ID SHOE MW: 12.9 WBM SET BPV, ND FLOW NIPPLE AND BOPE,MU C-LINE TO HGR, TEST TO 5K, OPEN SSSV, NU BOPE, TEST FLANGE TO 500 PSI,OK, PULL BPV, RU SWS,RIH W/JET CUTTER/CCL, CUT TBG @ 8520' POH, PU ON TBG, TBG FREE,RD SWS,LD TBG HGR, RU TO CIRC, CIRC DN TBG @ 3 BPM/700PSI RD CIRC HD, POH W/3.5" BTC TBG, DRIFT/TALLY/INSTALLL NEW SEAL RINGS WHILE POH, JT #1 DID NOT DRIFT, LD SAME,REMOVE C-LINE AND SS BANDS,AT 8 STDS PUMP DRY JOB, CPOH,LD JEWELRY, PUMP DRY JOB, CPOH, TBG CUT FLARED TO 5.25",CALL OUT 5.75" OD DRESSING SHOE, RD FLOOR, RU TO RUN DP, SET WEAR RING, TEST BOPE FLANGES TO 3K, OK, RACK AND TALLY FISHING BHA,WAIT ON SHOE RIH W/WASH PIPE BHA MW:12.9 WBM WAIT ON TRISTATE DRESSING SHOE, LOAD/STRP SAME,MU BHA, RIH ON DP TO TBG STUB, PU KELLY AND 3 JTS,CIRC ABOVE TBG STUB @ 8509',DRESS OFF STUB, SET OVERSHOT,WORK PIPE/ATTEMPT TO PULL SBR FREE,PULL 230K# (66K# OVERPULL),NO SUCCESS,WORK BHA FREE OF STUB, TEST KELLY TO 3K, OK, BLOW DN AND STD BK SAME, CBU @ 4 BPM/1700 PSI, WORK PIPE WHILE CIRC,ASPHALTINE RETURNS,MU SINGLE,TAG TBG STUB, POH W/DP&BHA, LD OVERSHOT, RACK/TALLY/MU WASH PIPE BHA, RIH ON DP SLOW POH W/DP,BHA, TBG STUB, SBR MW:13.0 WBM RIH W/DP,DC,WASH PIPE BHA, PUMU KELLY,WASH DN TO 8525'@ 4 BPM/1750 PSI,PUMP DRY JOB, BLOW DN/STD BK KELLY, POH W/DP,DC, BHA, LD TOOLS,RU/RIH W/OVERSHOT ON DP, KELLY UP & TAG STUB AT 8509',UP WT=150K, DN WT=65K, WORK 2' DN OVER STUB, LATCH STUB, PULL 220K,WORK DP,PULL FREE, 7K EXCESS DRAG INDICATES SBR RETR.,CBU WHILE WORKING PIPE AT 4 BPM/1600 PSI, ASPHALTINES ACROSS SHAKER, CONT CIRC HOLE CLEAN, PUMP DRY JOB, BLOW DN/STD BK KELLY, SLIP AND CUT DRLG LINE, POH W/DP, BHA POH W/DP,BHA LAYING DOWN MW:13.0 WBM SERVICE/FUNCTION TEST BOPE/CROWN-O-MATIC, POH W/SBR/TBG STUB, O-SHOT BHA, DC,DP, LD FISHING TOOLS/FISH, RECOVERED 15.20' TBG STUB/SBR, SEND SBR TO BKR TO REDRESS RU RIH W/3-1/2" DP AND WASH PIPE 8535',WASH DN OVER SLICK STICK TO 8546',RU TO BLEED PRESS F/10-3/4" ANNULUS,PUMP DRY JOB, RD CIRC HD, POH, LD 66 JTS DP,MU RTTS W/STORM VALVE, RIH 50',SET SAME, BLEED PRESS F/10-3/4" ANNULUS,ND FLOW NIP. BOP STACK, TBG HD, PULL AND REDRESS PACKOFF,MU TBG SPOOL, BOP,FLOW NIP.,TEST PO TO 5K, OK, TEST BOP TO 3K, OK, RIH AND RELEASE RTTS,POH W/RTTS AND DP,LD DP,CIRC TO HEAT UP MUD, CPOH R 'CEIVED JUL - 7 1992 Alaska Od & Gas Cons. Commission Anchorage WELL : 1E-07 OPERATION: RIG : NORDIC 1 PAGE: 3 02/08/92 (7) TD: 0 PB: 9258 RD WIRELINE, SPACE OUT TBG MW:13.0 WBM SERVICE RIG, POH/LD DP TO 2000',CIRC WARM MUD,CPOH/LD DP & BHA, SEND OUT TRI- STATE TOOLS,BRING IN JEWELRY, RU TO RUN COMP,RIH W/COMP AS PER PROCEDURE,USE FLOW PLUG, PUMP DRY JOB TO BALANCE WELL, CRIH,MU SSSV & C-LINE, TEST C-LINE TO 5K OK, CRIH, TAG SLICK STICK, WORK SBR DN OVER SLICK STICK,VERIFY POSITION W/400 PSI PRESS TBG TO 2500 PSI TO SET PKR, HOLD 15 MIN, PRESS ANN TO 1000 PSI,BLEED PRESS PU/SHEAR PBR @ 102K#, UP WT=68K#,PU OUT OF PBR, BREAK CIRC,OK, RU BYPASS CIRC HD/ SLICKLINE/LUBR, RIH/PUMP DN TOOL TO PULL CV FROM GLM @ 8453', LATCH CV & POH, RD SLICKLINE,PREP TO SPACE OUT COMP 02/09/92 (8) TD: 0 PB: 9258 RIG RELEASED MW: 0.0 Diesel SPACE OUT COMP,MU TBG HGR & C-LINE, TEST C-LINE TO 5K, OK, LAND HGR, RILDS,TEST PKR/CSG TO 2500 PSI F/15 MIN, OK, LD LANDING JT, SET BPV,ND FLOW RISER/BOPE,NU TREE,TEST FLANGE TO 5000 PSI F/15 MIN, OK, SET TEST PLUG, TEST TREE TO 5K, OK, PULL TEST PLUG, MIX HI-VIS SWEEP,RU CIRC JT, KILL LINE,CLEAN PITS,PUMP 50 BBL SWEEP, 138 BBLS WATER, FOLLOWED BY DIESEL @ 3.5 BPM/2500 PSI,DRAIN LINES,LD CIRC JT, BLOW DN MUD LINES, CLEAN CELLAR, SIAP=50 PSI,SICP=0 PSI,SITP=950 PSI,SECURE WELL MOVE OFF RIG, CLEAN AROUND WELLBORE,RELEASE RIG AT 2100 HRS 2/8/92,MOVE TO 3J-3 RECEIVED J U L - ? 199 Alaska Oil & Gas Oons. (;om~SS'~o~ Anchorage TO: THRU: FROM: MEMORAN[ UM St ,e of Alaska ALASK~iOIL AND GAS CONSERVATION COMMISSION Lonnte C. DATE: Feb. 3, 1992 Co~ission~r - FILE NO: DA. 2 3.3 Blair Wondze11 Sr. Petroleum Engineer Doug Aiaos(~~ Petroleum Inspector TELEPHONE NO: SUBJECT: BOPE Test ~-~0,d,c AAI KRU DSIE-7 Permit No. 80-80 Kuparuk Rv. Field Sunday Feb. 2.. 1992: I traveled this date from AAI PBU to AAI's KRU DSIE-7 well to witness the BOPE test on Nordic Rig No. 1. As the attached BOPE Test report indicates, there were two failures during this test, both of which were repaired and retested during the course of this test. In summary, I witnessed the B.OPE test at AAI's KRU DS1E-7 well on Nordic Rig No. 1. The two failures uncovered during this test were repaired and retested by me during the course of this test. This rig was on our Priority BOPE test list. Attachment. 02-00lA (Rev 6/89) 20/Il/MEMO1 PM3 STATE OF ALASKA ALASKA 01L AND CAS CONSERVAT I ON COMM I SS I ON BOP Test Report OPERATION: Drl g.__ Wkvr Operator Location: Sec /~:~ T Drl g contrctr /~)/~) Location (general) Housekeeping (general) Reserve pit I Well sign / Rig, MUD SYSTEMS: Vi sual Audio Trip tank ~0/~ ~, ! ~~ Flow monitor ~g I ~0~ Gas detectors L~ ~ I~ BOPE STACK: Annular preventer Pipe rams Blind rams ~ Choke line valves HCR valve Kill line valves Check valve Test Pressure Rig# DATE Fg:~ Z! //~'~Z. TEST: Initial / Weekly.~ Other Permit # ~VO' ~) _ _ '7 t/ Casing set @ ~ Z~j~ ft ACCUMU~TOR SYSTEM: Full charge pressure ~~ psig Pres, after closure ~~ psig Pump incr clos press 200 psig min ~ s~ Full charge press attained / min ~sec N2 ¢~ ~¢~ ps~g ~ Controls: Has,er ~ Remote KELLY AND FLOOR SAFETY VALVES: Blind switch cover_,~~ 4J~ Kelly ~ / Test pressure ~ Kelly t~ / Test pressure Ball type ~/ j Test pressure Inside BOP ~t~ I Test pressure / /i Choke manifold 'r'¢// Test pressure ~. // Number valves ~ / ~ / 1f Number flanges L,~ .~ II Adjustable chokes / Hydraulically operated choke ! t/ TEST RESULTS: Fai 1 ures ~-- Test ti me ~ hrs Repair or replacement of,failed equipment to be made within __ days. Notify the Inspector, and follow with written/FAXed verification to Commission office. Remarks: D~stribution: orig - AOGCC c - Operator c - Supervisor C.004 (rev 01/92) STATE WITNESS REQUIRED? J yes .,, ~'" no j j24-HR NOTICE GIVEN? Waived by: Witnessed by: Attachment ! ! Page 2 Drill Site 1H gel1 No. IH-3 ~1H-4 ~]H-7 ~lH-8 Log Date 8/16/82 8/13/82 6/21/82 7/20/82 7/22/82 Drill Site Well No. Log Date 1E 1E-IA '"e/]9/8] 1£-2 '-8/17/8:L"-~ _"'1/17/84/ IE-3 ~'10/18/81~,, '"11/7/81/ 1E-5 '-.10/27/81.. 1£-6 -'.10/21/81'% -',,11/12/82/ "~'1E-7 1E-8 '"' 8/28/81'~. ".'11/1/81,/ ]E-12 ""11/28/84 1E-15 "--8/26/82 1E-16 '""8/29/82 1E-17 "-9/]/82 1E-20 '""'5/7/83 1£-24 ",~/17/83 1E-25 '"1/17/83 1E-26 '~-1/13/83 1E-27 "",,~0/31/82 1E-28 '~10/27/82 ~ "~6/13/83 1E-29 ~10/18/82'~ ~7/18/83 / 1£-30 '~-10/16/82 Drill Site 1G Wel 1 No. "~1G-1 '~G-~ '~1G-3 '~1G-4 '~ 1G-8 LOg Date 9/7/82 9/25/8~ 9/28/82 12/8/84/ 10/13/82 11/12/82 3/12/83 1/22/83 Drill Site Well No. LO9 Date 1F '~1F-1 2/19/83 '~1F-2 2/3/83 '"'1F-3 1/31/83 ' ~ "1F-4 5/29/83 ~1F-5 10/25/82 '~1F-6 10/28/82 '~ 1F-7 11/19/82~ ~ ~ 5/7/83/ RECEiVIng"/' . FEB 2 1 1986 Alaska 011 & Gas Cons. Commission Anchorage ARCO Alaska, Inc. ~ Post Office B(~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 June 18, 1985 Mr. C. V. Chatterton Commi ssi oner State of Alaska Alaska Oil & Gas Conservation Commi ss ion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: 1E-7 Dear Mr. Chatterton: Enclosed is a copy of the 1E-7 Workover Well History to include with the Well Completion Report, dated 02/08/85. If you have any questions, please call me at 263-4944. Sincerely, Gruber Associate Engineer JG/tw GRU9/L70 Enclosure ARCO Alaska, Inc ~s a Subs,d,ary of Atlant,cR~chf,eldCompany RECEIVED Alaska Oil & Gas Cons. Commission Anchorage ' ! ' STATE OF ALASKA { ALASK~ , fL AND GAS CONSERVATION CGm. ~IISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classlhcat~on of Serwce Well OIL E~x GAS I--I SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, Inc. 80-80 3. Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20495 4 Location of well at surface 9 Umt or Lease Name 893' FSL, 631' FEL, Sec.16, TllN, R10E, UM Kuparuk River Unit At Top Produc.ng Interval 10 Well Number 1173' FNL, 1373' FEL, Sec.15, TllN, R10E, UM 1E-7 At Total Depth 11 F~eld and Pool 969' FNL, 996' FEL, Sec.15, T11N, R10E, UN Kuparuk River Field 5 Elevation .n feet (~nd,cate KB, DF, etc ) I 6 Lease Des~gnatmn and Serial No Kuparuk River 0i 1 Pool 105.5' RKBI ADL 25651 12 Date Spudded 13 Date T.D Reached 14 Date Comp, Susp or Aband 115. Water Depth, ~f offshore 116 No of Completions 09/23/80 10/08/80 10/13/80I N/A feet MSL 17 Total Depth (MD+TVD) 18.Plug Back Depth (MD+TVD) 19. D~rect~onal Survey 20 Depth where SSSV set I 21 Thickness of Permafrost 9310'MD,6711 'TVD 9203'MD,6636'TVD YES [] NO [] 1973 feet MDI 1450' (Approx) 22 Type Electric or Other Logs Run D IL/GR/BHCS, FDC/NGT/Cal , GR/CBL/CCL, CBL 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65.0# H-40 Surf 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surf 3249' 13-3/4" 1500 sx Fondu & 350 sx Arctic Set 7" 26.0# K-55 Surf 9289' 8-3/4" 315 sx Class G 24 Perforations open to Productmn (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, s~:ze and r~umber) SIZE DEPTH SET (MD) PACKER SET (MD) 8686' - 8832' 3-1/2" 8918' 8559' & 8877' 9106' - 9128' 9138' - 9175' 26 ACID, FRACTURE, CEMENT sQuEEZE, ETC DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27 N/A PRODUCTION TEST --., Date F~r'st Production Method of Operation (Flowing, gas hft, etc ) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL ' CHOKE SIZE GAS-OIL RATIO TEST PERIOD II~ Fl'ow Tubing Casing Pressure CALCULATED.k OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28 CORE DATA Brief description of hthology, porosity, fractures, apparent d~ps and presence of od, gas or water Submit core ch~ps NONE RECEIVED FEB 1 4 1985 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 GRU3/WC64 Submit ~n duphcate Rev 7-1-80 CONTINUED 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 t,me of each phase See or'ig~nal Well ;omplet:~on Repot s N/A dated 11/25/80. 31. LIST OF ATTACHMENTS -- , , 32. I hereby certify that the foregoing is true and correct to the best of my knowledge S,gned t~ ~/'~J~/L~,/ ~_~ ~ Title AssocJ al:e Eng{ neet' Date // INSTRUCTIONS General' This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells' Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 ARCO Oil and Gas Company Well History - Initial Report - Daily Prepare and submit the "l~ti#al Relied" on the flint Wednesday after a well is spudded or work. over operations are staJ'ted Daily wort( I~rtor to sPudding should be summmlzed mt the form giving reclusive dates only DI,trict Alaska Field Ku~aruk River Auth or W O no AFE Exp 304778 ICounty ~ or borough North Slope Borough ADL 25651 or Unit IT,tle Re-Comp let ion State Alaska ell ~ 1E-7 W/0 Pool 102 APl: 50-029-20495 Operator ARCO Alaska, Inc. Spudded or W O begun Workover Date and depth asof 800 am 11/28/84 11/29/84 11/30/84 IDle IHour 11/27/84 12/01/84 thru 12/03/84 12/04/84 The alcove la correct For form preparation and dlatrtbl~on. see Procedures Manual. Section T0. Drilling. Pages 86 and 87 Complete record for each day reported 1800 hrs. 7" @ 9289' 9203' PBTD, Prep to set BPV f/NU BOPE Accept ri~ @ 1800 hrs, 11/27/84. Pull BPV. Bled both tbg & ann to 0 psi. RU to set BPV. IARCO W I Prior status if a W O Pull GLM @ 8473'. IDate 7" @ 9289' 9258' PBTD, RIH w/3½" compl string 11.1NaC1/NaBr POH w/pkr & tailpipe. Rn CBL; good bond. Set BP @ 8550', RU & tst csg above BP to 2500 psi; OK. POH w/DP. ND BOP. ND FMC 3000# head. NU FMC 5000# head. NU & tst BOPE to 250/5000 psi. Pull BP loose. MU bit, RIH, tag fill @ 9117'. Wsh & rm fill 9117'-9194'. Fin drlg FC, POH. RIH w/JB w/6 125" gage ring; stopped @ 9200'. PU Bkr FB-1 pkr & tailpipe assy, set pkr @ 8866'. RIH w/3½" compl string. 7" @ 9289' 9258' PBTD, RIH w/3½" selective single tbg 11.1NaC1/NaBr Screw driver broke, fell dn tbg. RIH w/3½" tbg & seal assy, stab into pkr; OK. RIH w/CCL to 8911'; fsh not in tbg, POH. MU & RIH w/3½" tbg. PU SSSV & tst to 5000 psi; OK. RECEIVED 12/07/84 Drilling Superintendent 7" @ 9289' 9203' PBTD, CBU 11.1NaC1/NaBr RIH to fsh f/pkr, CBU prior to POH w/pkr. 56.24% 7" @ 9289' 9203' PBTD, POH w/3½" tbg Set BPV. ND tree, NU BOPE, pull BPV, tst BOPE. PU 130K, PBR would not shear. Cut tbg @ ±8474', POH, chg to ABM colrs. ARCO Oil and Gas Company Daily Well History-Final Report Instl'Uctloas Prepare and submit the "Final Report" on the first Wednesday after allowable has been asmgned or well ~s Plugged Abandoned or Sold "Filtal Report" should be submitted also wr~en oDerahons are suspended for an ~ndefimte or appreciable length of time On workovers when an off, mai test ~s not required uDon completion, report completion and representative test data ~n blocks provided The 'Final Report" form may be used for reDortlng the entire operahon ~f space ~s available D~strtct ICounty or Pamsh 1 Alaska Field JLease or Umt 1 Kuparuk River Auth or W O no JT~tle AFE Exp 304778/Cap 304786 I Operator ARCO Alaska, Inc. North Slope Borough ADL 25651 Completion API IARCo WI 56.24% IDate 11/27/84 ]Accountmg cost center code State Alaska IWell no 1E-7 W/O I otal number of wells (achve or ~nachve) on th~s DSt center prior to plugging and bandonment of th~s well I our I Prior status if a W O 1800 hrs I Spudded or W O begun Workover Date and depth as of 8 00 a m 12/05/84 Complete record for each day reported 7" @ 9289' 9258' PBTD, RR Kuparuk Crude in ann & tbg w/30 bbls diesel cap in tbg Stab in pkr, lnd tbg, set pkr. PU & shear off "G" seal, relnd tbg. Set BPV. ND BOPE, NU tree, pull BPV, tst tree to 250/5000 psi; OK. Tst pack-off to 250/5000 psi; OK. Open SSSV, tst ann to 2500 psi; OK. Displ dn ann w/30 bbl diesel, followed by Kuparuk crude. Close SSSV. Bleed off tbg press, monitor 15 min; OK. Tst orifice to 2000 psi; OK. Shear out ball @ 4000 psi. Set BPV. RR @ 0300 hrs, 12/5/84. SSSV @ 1973', Bkr FB-1Pkr @ 8877', BOT HB-1 @ 8559', T.T.@ 8918' Old TO Released r~g 0300 hrs Class~flcahons (od, gas, etc ) 0il Produmng method Flowing New TD IPB Depth 9258' PBTD Date ~K~nd of ng 12/05/84 J Rotary Type complehon (single, dual, etc ) Single Ofhmal reservoir name(s) Kuparuk Sands Potenhal test data Well no Date Reservoir Producmg Interval Od or gas Test t~me Production Oil on test Gas per day Pump s,ze. S.M X ,e.gih Ohok~ s,~e T P C P Water % Go. Grav,ty^,,owab,e "~ ~v~ ~-- ~ ~, corrected ' ' Ju ~I 9 The above ,s correct ~Jaska Oil,~~ Tltle -- -.~o COr/S. C01Tlrl3JSSl0r~ S~gnature J Date /'~n~ 12/07/84 For form preparation a see Procedures Manual, Section 10, Dnlhng, Pages 86 and 87 Drilling Superin~a~e ARCO Alaska, Inc./ Post Offlce~ 100360 Anchorage, ~.,,a.~ka 99510-0360 Telephone 907 276 1215 PT:It F'r ;,,r' f"Lr'ITP l.l-;?f.I :", r'l.' r,'F(','l,:¢,'f~.. ' r,:9;'T l' r,':"-:c , r;.., ?',',Hn Cr,'~ !T'.,F I,~,'~,'.'~l F.T ~'~ T "'! FRAE :'TT]HULP, T1Di'~ 'F'OS"T r I, h.t' *,']"i"I,~ i · L r'" ',! "'::' I,!,. ',','~'. :,"~ "'~ b;~ 7.' ' :1:;"., :',..:;: ~ ~ ,, r,i I.T',_ I. i"", ~.-',_ ,, ~J''~le¢'~l ~1'~ I Il/ I ~. t i i Jt I I ARCO Alaska, Inc Is a Subsidiary of AllanhcRichfiel~lCompany ARCO Alaska, I~f Post Office clox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton' Attached in duplicate are subsequent following wells at the Kuparuk River Field notices Well Action Date Performed 1E-6 Fracture 1/26/85 1 E-7 Repe r f 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/13/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3/1 8/85 1Q-1 0 Fracture 3/5/85 1Q-1 2 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 1/27/85 on If you have any questions, please call Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) me at 263-4253. the ARCO Alaska, Inc is a Subsidiary of AtlantlcRmhfteldCompany A(U STATE OF ALASKA O~ ALASK IL AND GAS CONSERVATION C ,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL 2 Name of Operator ARCO ALASKA, ]:NC. 3 Address P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4 Locat,on of Well SURFACE LOCATION' 893' FSL, 631' FEL, SEC. 16, T11N, RIOE, UM 5. Elevation m feet (md,cate KB, DF, etc ) 105.5' (RKB) 12 7 Permit No 80-80 8 APl Number 50- 029-20495 9 Umt or Lease Name KUPARUK RIVER 10 Well Number 1E-7 11 F,eld and Pool KUPARUK 6 Lease Des,gnat,on and Ser,al No KU PARU K ADL 25651, ALK 469 P00I Check Appropriate Box To Indmate Nature of Notme, Report, or Other Data UNIT RIVER FIELD RIVER OIL NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Triplicate) (Submit ~n Dupl,cate) Perforate [] Alter Casing [] Perforations ~ Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) A redesign of the stimulation made it unnecessary to reperforate Kuparuk well 1E-7. This closes out our notice of intent of 1-25-85. RECEIVED APR A'ask~ 0,t & Gas Gens, 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge Signed _.~ T,tle 0P£RAIIONS The space below for Commission use COORDINATOR Conditions of Approval, ~f any 3/28/85 Approved by By Order of COMMISSIONER the Commms~on Date Form 10-403 Rev 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" ~n Duplicate ARCO Alaska, I~ Post Office dox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 April 1, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 Dear Mr. Chatterton. Attached in duplicate are subsequent notices following wells at the Kuparuk River Field. on Well Action Date P~rformed 1E-6 Fracture 1/26/85 1E-7 Reperf 1E-7 Fracture 3/1/85 1E-8 Reperf 1/28/85 1E-11 Reperf 2/1/85 1E-11 Fracture 2/7/85 1E-18 Fracture 3/13/85 1E-20 Stress Frac 3/19/85 1E-20 Fracture 3/23/85 1E-22 Fracture 3/22/85 1E-24 Fracture 3/22/85 1L-6 Fracture 2/2/85 1L-7 Fracture 1/30/85 1Q-9 Fracture 3 / 1 8/85 1Q-1 0 Fracture 3/5/85 1Q-1 2 Fracture 3/5/85 2A-3 Conversion 3/21/85 2A-4 Conversion 3/12/85 2A-5 Conversion 3/12/85 2A-6 Conversion 3/12/85 2A-7 Conversion 3/12/85 2C-4 Reperf 2/23/85 2D-4 Reperf 2/2/85 2V-8A Conversion 2X-8 Perforation 1/27/85 If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (Duplicate) the ARCO Alaska, Inc Is a Subsidiary of Atlanl~cR~chfleldCompany (/ STATE OF ALASKA ~ ALASKA uIL AND GAS CONSERVATION C ,~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL i-X] OTHER [] 2 Name of Operator ARCO ALASKA, INC. 3 Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4 Location of Well SURFACE LOCATION' 893' FSL, 631' T11N, RIOE, UN 5 Elevation ~n feet (~nd~cate KB, DF, etc ) 105,5' (RKB) 12 FEL, SEC. 16, 7 Permit No 80-80 8 APl Number 50- 029-20495 9 Umt or Lease Name KUPARUK RIVER 10 Well Number 1E-7 11 F~eld and Pool KUPARUK RIVER I 6 Lease Deslgnatmon and Serml No KU P ARU K R I V E R ADL 25651, ALK 469 POOL Check Approprmate Box To Indicate Nature of Not~ce, Report, or Other Data UNIT FIELD OIL NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Tnphcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations '] Altering Casing [] Stimulate [] Abandon [] Stimulation ~ Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) On March 1, 1985, the "A" sands of Kuparuk well 1E-7 were hydraulically fractured and propped to improve production. treatment consisted of 327 BBLS of gelled water as pad and fluid and 14,910 LBS of 12/20 sand as proppant. 25 BBLS of diesel was used as a flush. The carrying gelled Prior to pumping, equipment and lines were tested to 5600 psi. RECEIVED APR 1925 n-- Comm:ssmn A'~aska Oil & Gas C 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge ///'/Z~ P,~rv~O..Z,.4JL.. KUPARUK S,gned T,tle OPERATIONS The space below for Commission use COORDINATOR 3/27/85 . ./- Conditions of Approval, if any By Order of Approved by COMMISSIONER the Commission Form 10-403 Date Submit "Intentions" ~n Triplicate Rev 7-1-80 and "Subsequent Reports" ~n Duplicate ARCO Alaska, In(~ Post Office box 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 12, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' 1E-7 Dear Mr. Chatterton- Enclosed is a Well Completion Report for the subject well. I have not yet received the Workover Well History. When I do, I will forward a copy to you. If you have any questions, please call me at 263-4944. Sincerely, · Gruber Associate Engineer JG/tw GRU4/L141 Enclosure RECEIVED FEB 1 ]985 A/aska Oil & Gas Cons. Commission Anchorage ARCO Alaska, Inc ~s a Subsidiary of Atlant~cRtchfleldCompany ! ARCO Alaska, Inc. ~ Post Office B~x 100360 Anchorage, Alaska 99510 Telephone 907 276 1215 February 5, 1985 Mr. C. V. Chatterton Commi ss i oner State of Alaska Alaska Oil & Gas Conservation Commi ssion 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: Subsequent Sundry Reports - Various Wells Dear Mr. Chatterton: Enclosed are Subsequent Sundry Reports for the following wells: 1 If you have Sincerely, -29 any questions, please call me at 263-4944. Gruber Associate Engineer JG/tw GRU4/L121 Enclosures ARCO Alaska, Inc ~s a Subsidiary of AtlanhcR~chheldCompany j STATE OF ALASKA (~ ALASKA ~L AND GAS CONSERVATION C ,,,MISSION SUNDRY NOTICES AND REPORTS ON WELLS I DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator 7 Perm,t No ARCO Alaska, Inc. 80-80 3 Address 8 APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-20495 4. Locat,on of Well Surface: 893' FSL, 631' FEL, Sec.16, TllN, RIOE, UN 5 Elevation in feet (red,cate KB, DF, etc ) 105.5' RKB Lease Deslgnat,on and Serial No ADL 25651 9. Umt or Lease Name Kuparuk River Unit 10 Well Number 1E-7 12. 1 1 F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report. or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF' (Submit ,n Triphcate) (Submit ~n Dupl,cate) Perforate I-1 Alter Casmg [] Perforattons [] Alter,ng Casing Stimulate [] Abandon [] Stimulation [] Abandonment Repair Well [] Change Plans [] Repairs Made [] Other Pull Tub,ng [] Other [] Pulhng Tubing (Note Report multiple complet,ons on Form 10-407 with a submitted Form 10-407 for each complet,on ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ,nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Accepted rig ~ 1800 hfs, 11/27/84. Killed well. ND tree. NU BOPE & tstd - ok. Cut tbg @ 8474' & POH. Recovered pkr & tailpipe. Ran CBL. Set bridge plug ~ 8550'; tstd csg to 2500 psi - ok. Set FB-1 pkr 8 8866'. Ran 3-1/2" completion assy. ND BOPE. NU tree & tstd to 5000 psi - ok. Disp well w/diesel & crude oil. Set BPV. Secured well & released rig ~ 0300 hfs, 12/05/84. RECEIVED o 6 1985 AlasKa 0~1 & Gas Cons. Commission Anchorage 14 I hereby certify that the foregoing ,s true and correct to the best of my knowledge Signed ~J~~ T,tle Associate Engineer The space bel~tw for Commission use Conditions of Approval, ~f any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 GRU3/SN17 Rev. 7-1-80 Submit "Intentions" in Tr~phcate and "Subsequent Reports" ,n Duphcate ! ARCO Alaska, Inc. I~ Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commi ssi on Dear Mr. Chatterton' Attached are our notices of intention Field well 1E-7 and re-perforate wells 1E-20. to fracture Kuparuk 1E-7, 1E-8, 1E-11 and If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) RECEIVED Alaska Oil &.Gas COns. ComtniS~ion ~nChorage ARCO Alaska Inc is a sabsldlar¥ ~f Aflant~cR~ch~eldComp~r~¥ ) STATE OF ALASKA ~ ALASKA IL AND GAS CONSERVATION C ,v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL r~ OTHER [] 2 Name of Operator ARCO ALASKA, INC. 3 Address P. O. BOX 100360, ANCHORAGE, ALASKA 99510 4 Location of Well SURFACE LOCATION' 893' FSL, 631' FEL, SEC. 16, T11N, RIOE, UM 5 Elevation m feet (mdlcate KB, DF, etc ) 105.5' 12 6 Lease Designation and Serial No 7 Permit No 80-80 8 APl Number 50- 029-20495 9 Umt or Lease Name KUPARUK RIVER UNIT 10 Well Number 1E-7 11 Fmld and Pool KUPARUK RIVER FIELD KUPARUK RIVER 0IL (RKB) ADL 25651, ALK 469 POOL Check Appropriate Box To Indmcate Nature of motmce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit m Triplicate) Perforate [] Alter Casmg [] Perforations Stimulate X [] Abandon [] Stimulation Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulhng Tubmg (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for eachcomplet~on) (Submit ~n Duplicate) [] Altermg Casmg [] [] Abandonment [] [] Other [] 13 Describe Proposed or Completed Operations (Clearly state all pertment detads and g~ve pertment dates, mcludmg estimated date of startmg any proposed work, for Abandonment see 20 AAC 25 105-170) It is prop hydraulica treatment sand as th osed that the "A" sand in Kuparuk well 1E-7 be l ly fractured and propped to improve production. The uses gelled water as the pad and carrying fluid and 12/20 e proppant. Gelled diesel will be used as a flush. Lines and equipment will be pressure tested to 5000 psi prior to starting job. Pre-post frac logs are included in the treatment program. Fluid- Gelled water 180 BBLS Gelled diesel 65 BBLS Proppant' 12/20 sand 14,910 LBS ANTICIPATED START DATE- February 1, 1985 RECEIVED JAN 2 5 Alaska Oil & Gas Cons. Commi~ion Anchorage 14 I hereby certify that the foregomg ~s true and correct to the best of my knowledge Signed Title OPERATIONS The space below for Commission use 1/25/85 COORDINATOR Date Conditions of Approval, if any Approved by COMMISSIONER Approved ~,gb]~equent Wor~c l~epor~e~ j Returned - , -~--~ By Order of ~ ~ theCommlsslon Date /- ~-~ [ Form 10-403 Rev 7-1-80 Submit "Intentions" ,n Triplicate and "Subsequent Reports" ,n Duplicate ARCO Alaska, Inc.( Post Office Box 1479 Anchorage, Alaska 99510 Telephone 907 277 5637 January 25, 1985 Mr. C. V. Chatterton, Chairman Alaska Oil and Gas Conservation 3001 Porcupine Drive Anchorage, AK 99501 Commi s sion Dear Mr. Chatterton: Attached are our notices of intention Field well 1E-7 and re-perforate wells 1E-20. to fracture Kuparuk 1E-7, 1E-8, 1E-11 and If you have any questions, please call me at 263-4253. Mike L. Laue Kuparuk Operations Coordinator MLL/kmc Attachment (In Triplicate) ARCO Alaska, Inc IS a subsidiary of AtlantlcRichiJeldCompany STATE OF ALASKA O~ ALASKA OIL AND GAS CONSERVATION C ~v~MISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL DO Name of Operator ARCO ALASKA, INC. 3 Address P. 0. BOX 100360, ANCHORAGE, ALASKA 99510 OTHER [] 4 Location of Well SURFACE LOCATION' 893' FSL, 631' FEL, SEC. 16, T11N, R10E, UM 5 Elevation ~n feet (md,cate KB, DF, etc ) 6 Lease Designation and Serial No 7 PermIt No 80-80 8 APl Number 50- 029-20495 9 Unit or Lease Name KUPARUK RIVER UNIT 10 Well Number 1E-7 11 F~eld and Pool KUPARUK KUPARUK RIVER FIELD RIVER OIL 12 105.5' (RKB) ADL 25651, ALK 469 i POOl Check Appropriate Box To Indicate Nature of mot~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Triplicate) Perforate X]] Alter Casing [] Perforations Stem ulate [] Abandon [] Stem ulat~on Repair Well [] Change Plans [] Repairs Made Pull Tubing [] Other [] Pulling Tubing (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) (Submit ~n Duplicate) [] Altenng Casing [] [] Abandonment [] [] Other [] 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertment dates, ~ncludmg estimated date of startmg any proposed work, for Abandonment see 20 AAC 25 105-170) It is proposed that the "A" sand in Kuparuk well 1E-7 be re-perforated to enhance subsequent stimluation. Procedures call the well to be perforated with a wi reline conveyed gun under a lubricator. Proposed Intervals (MD)' 9106'-9128' (4 SPF) 9138'-9175' ANTICIPATED START DATE' January 26, 1985 for RECEIVED JAN 2 5 1985 Alaska 0il & Gas Cons. Commission Anchorage 14 I hereby certify that the forego!ngj~s true and correct to the best of my knowledge S,gned T~tle OPERATIONS The space below for Commission use COORDINATOR 1/25/85 Date Conditions of Approval, ~f any Approved by 6RIG,HAL SIG~D 81 LONHIE C. SMITH COMMISSIONER Approved Copy Returned By Order of the Commission Form 10-403 Rev 7-1-80 SubmIt "Intentions" m Triplicate and "Subsequent Reports" ~n Duplicate ARCO Alaska, Inc. [ Post Office ~'~ 60 Anchorage, A,aska 99510 Telephone 907 277 5637 Date: 12 '27/84 Transmittal/No: 4939 RETURN TO: ~CO ALAS~, INC. AT~: Records Clerk AT~lllSB P.~ Box 100360 / / _~7°rage' ~ 99510 ~ =.a ~*~and retu~ one signed copy of this transmittal. Dresser CBL F INAL-S _- _ 7 Acoustic "VDL/Signature/GR" 11/S0/84 Run 1 8074-9100 /cat Receipt Acknowledged: DISTRIBUTION Date: a~oo,.~ ~ .... ........ ,,,, ~ uss Cons. Commission Anchorage B. Currier BPAE Chevron Drilling Mobil W. Pasher G. Phillips Phillips Oil Sohio Union D&M J. Rathmell Well Files ARCO Alaska Inc i$a subsidiary of Atlant;cRichhelc~Company ARCO Alaska, I( Post Offl~= ctox 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 October 9, 1984 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK. 99501 SUBJECT: 1E-7 Dear Mr. Chatterton: Enclosed is a Sundry Notice for the subject well. We propose to convert 1E-7 to a selective single completion. Since we expect to start this work on October 20, 1984, your earliest approval will be appreciated. If you have any questions, please call me at 263-4970. Sincerely, . Kewi n Area Drilling Engineer JBK/JG/tw GRU1/L81 Enclosures ~,l~sKa 0il & Gas ConS. commiSS~On Anchorage ARCO Alaska, Inc ~s a Subsidiary of AtlanhcR~chfleldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATIO ,vlMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WE LLx~ OTHER [] 2 Name of Operator 7 Permit No ARCO Alaska, Inc. 80-80 3 Address P. 0. Box 100360, Anchorage, AK 99510 4 Location of Well Surface: 893' FSL, 631' FEL, Sec.16, T11N, R10E, UM 5 Elevation m feet (~nd~cate KB, DF. etc ) RKB 105.5' 12 Lease Designation and Serial No ADL 25R~1 8 APl Number 50- 029-20495 9 umt or Lease Name KuP~r,,k River liner 10 Well Number 1F-7 11 Field and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO. SUBSEQUENT REPORT OF' (Submit m Tr~phcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate [~ Abandon [] Stimulation [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [~] Pull Tubing ~ Other ~ Pulhng Tubing /r (Note Report mult,ple completions on Form 10-407 wroth a submmtted Form 10-407 for each completion ) 13 Descr,be Proposed or Completed Operations (Clearly state all pertmnent details and g~ve pertinent dates, including estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc., proposes to convert well 1E-7 to a selective single completion. The procedure will be as fo l 1 ows: 1. Well will be killed with brine. Weight to be determined after running pressure bomb. 2. Current completion assembly will be pulled. 3. A retrievable packer will be run to test for zone isolation between the A and C sand, and to test casing integrity. 4. The well will be completed as a selective single and 5000# wellhead equipment will be installed. 5. After the rig is released, an acid and/or frac job will be done. A 13-5/8", 5000psi, SRRA BOP stack will be used on well work. BOP equipment will be tested weekly and operationally tested each trip. A non-freezing fluid will be left in all uncemented annuli within the permafrost interval. A 5000 psi WP wireline lubricator will be used and tested on all wireline work. The subsurface safety valve will be installed and tested upon conclusion of the job. Estimated Start: October 20, 1984 14 I hereby cer~tv thj~t~he foregoing ,s true and correct to the best of my knowledge S~gned ' ~ ~10 Title Area Drilling Engineer The space below for Commission use RECEIVED Alaska 0ii & Gas Cons. C0mmissinn Anchorage , Date l 0//~0/~[~ ! ! Conditions of Approval, mf any Approved Copy Returned By Order of the Commission Date Form 10-403 Rev 7-1-80 GRU1/SN72 Submit "Intentions" ~n Tr~phcate and "Subsequent Reports" ~n Duphcate 'internal Correspondence Company/Iocahon · Compan~n~ /~oo ~ ~~ Subject Date -~es(age '7 F~m -rtt~ ~rr'~m & Z./~. t bO ~e,E_ THe_ ~%~'~m ~¥oz- AR3B-1389-C 'Internal Correspondence i, To Company/Iocahon From Company/Iocahon Subject Date Message ,q~ O,~t~ OO~Tr~ Ar- 007- AR3B-1389-C TO' William Van Allen FROM' D. W. Bose/Shelby J. Matthews Transmitted herewith are the following. PLEASE NOTE' BL - BLUELINE, $ - SEPIA, F - FILM, T - TAPE,~C - PH~ RECEIPT ACKNOWLEDGED' r~/~PLEASE RETURN RECEIPT TO' ARCO ALASKA, INC. ATTN' SHELBY j. MATTHEWS - AFA/311 P.O. BOX 360 ANCHORAGE, AK. 99510 TO: William VanAlen [ ' Transmitted herewith are the following: D. W. Bose/Lor~e L. Johnson PI.VASE NOTE: BL - BI/fELINE, S - SEPIA, F - FII/~, T - TAPE, ~ - PH /b -/ ARCO ALASKA, INC. AT1/q: LORIE L. JOHNSON - AFA/3110~i ~'~ .~- !, -- P. O. BOX 360 ANCHCJRkGE, AK. 99510 -' / STATE OF ALASKA j(r" ~ ALASKA(' ,L AND GAS CONSERVATION C,~-,- .,,IlSSION ,WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Class,hcat~on of Serwce Well OIL IX] GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2 Name of Operator 7 Permit Number ARCO Alaska, :[nc. 80-80 3 Address 8 APl Number P.0.Box 360, Anchorage, AK 99510 50- 029-20/+95 4 Locat~on of well at surface 893'FSL, 63I'I-EL, Sec 16, IllN, RIOE. UM 9 Umt or Lease Name Kuparuk 25651 AtTopProduc,nglnterval 1173'FNL, 1373'FEL, Sec 15, T11N, R10E, UM 10WellNumber 1E-7 At Total Depth 969'FNL, 996'FEL, Sec 15, T11N, R10E, UH 1~ Fleld and Pool Kuparuk River Field 5 Elevation ~n feet (~nd~cate KB, DF, etc ) I 6 Lease Designation and Serial No 105.5 RKB [ ADL 25651 Kuparuk River 0il Pool 12 Date Spudded 13 Date T D Reached 14 Date Comp, Susp or Aband [ 15 Water Depth, ~f offshore ] 16 No of Completions 9/23/80 10/8/80 10/13/80 I -- feetMSL] 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 D~recuonal Survey I 20 Depth where SSSV set 21 Thickness of PermafroSt 9310' 67117 92037 66367 YES E~ NO [] I 1787 feet MD 1650' (approx.) 22 Type Electric or Other Logs Run DIL/GR/BHCS, FDC/NGT/CAL, GR/CBL/CCL _ 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT PER FT GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 1~;" ~;5 H-/+O Surf. 80' 2/+" 200 ~X Permafrost t~0 surface 10 ~//~" /+5.5~ K-55 Surf. 32/+9' 13 3//+ 1,500 SX Fondu & 3,50 ,SX Arcticset .to surface 7" 26~t K-~,5 Surf. 9289' 8 3//+" 315 sx Class G emt 24 Perf(~r~it~ons ol~en.,,t~l~duct~on (MD+TVD of Top and Bottom and 25 TUBING RECORD mterval, s~ze and number) SIZE DEPTH SET (MD) PACKER SET (MD) 3 1/2 8,598 8529 8686 ' -8832 ' 9106 ' -9128 ' 26 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 9138'-9175' w//+ SPF DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 8686'-8832' ,512/+ gal, 12% HC1 91067_91287 9! ]8 , -9175 7 _ 27 PRODUCTION TEST I ' Date F~rst Production Method of Operation (Flowing, gas I~ft, etc ) 12 / 15/81 Flowi~g Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 1O/2R/R1 1¢;.¢; TESTPERIOD I~ 1390 5/+1 -- 9¢,/~;/+I 389 Flow'-I-ub~g Casmg Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL OIL (~RAVITY-API (corr) Press 170 24-HOUR RATE J~ 1911 7/+/+ -- 28 COR E DATA Brmf description of I~thology, porosity, fractures, apparent d~ps and presence of o~1, gas or water Submit core ch~ps MA,~ 1 5 }982 'Nas!m Oil & Gas Cons. A-16 Form 10-407 Submit m duphcate Rev 7-1-80 CONTINUED ON REVERSE SIDE - v. 29 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 Kupacuk 8682 ' Form. 8682' 6247 ' Base Kuparuk River Form. 9231, 6644, , · 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge ., Signed ~ (~ ~a~------", - - //r Title Area Ope' Engr' Date INSTRUCTIONS ' General' This form is designed for submitting a complete and correct well completion report ~nd log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiFJle 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- lng and the location of the cementing tool. ~lO,',Tn %LO?E ~,GI;,EERIi;G TRAilq~!ITM .. J. J. Pa'.:eleL1;'nn Simonsen DATE /,.~ ~3 ~/ WELL "~" · . Transmir:~d here~:itn are the following' PLEASE I:OTE' GL - BLUEL!ilE, S - SEPIA, F - FILM, T - TAPE EECE ~. PT DATE: Alaska 0~1 ~, ~c,,m Anc.horago ARCO ,,~_,,~,, I''~ · ' ..... ATT~ A,,,, S I,.,u,~,, - AFA/311 P.O. DOX 360 A:~"n~'~ AK 9c510 STATE OF ALASKA ALASK ,IL AND GAS CONSERVATION VIMISSION SUNDRY OTHER 1 DRILLING WELL COMPLETED WE L L:~i 2 Name of Operator 7 Permit No. ARCO Alaska, Inc. 80-80 3 Address 8 APl Number P. O. Box 360, Anchorage, AK 99510 50-029-20495 4. Locat,on of Well 893' FSL, 631' FEL Sec. 16, TllN, R10E Surface Location: 5 Elevat,on m feet (md,cate KB, DF, etc ) KB = 105.5 12. 6 Lease Designation and Serial No. ADL 25651 9 umt or Lease Name Kuparuk 25651 10 Well Number E-7 11. F~eld and Pool Kuparuk River Field Kuparuk River Oil Pool Check Appropriate Box To Indmate Nature of Not~ce, Report, or Other Data NOTICE OF INTENTION TO SUBSEQUENT REPORT OF: (Submit m Tr,phcate) (Submit m Duplicate) Perforate [] Alter Casing [] Perforations [] Altering Casing [] Stimulate ~ Abandon [] Stimulation [] Abandonment J'"l Repair Well [] Change Plans [] Repairs Made [] Other Pull Tubing [] Other [] Pulhng Tubing [] (Note Reportmultlplecomplet~onson Form 10-407 wlthasubm~tted Form 10-407 for each completion) 13 Descr,be Proposed or Completed Operations (Clearly state all per~ment details and give pertinent dates, ~ncludmg estimated date of startang any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska, Inc. proposes to cleanout drilling fluids in cased hole which cover the Lower Kuparuk Sands. The work will be done using a coiled tubing unit with BOP assembly tested to 4000 psi. The well will be acidized after clean- out if an acceptable flow rate is not achieved. All circulated and flowed fluids will be diverted to tankage on location. The well will be tested after cleanout and/or acidization. Expected start date is October 19, 1981. RECEIVED OCT 2 0 ]98] Alaska 0/i & Gas Cons. Commis,~iort Anchorage 14 I hereby cert,fy/~,that jl:ke~orego,ng ,s lrue and correct to the best of my knowledge S,gned ~..~kj~. ~kJ~~~'~ Title Area Operations Engineer Date The space ~w for Commission Cond~t~ons~ Approvdl ~f any ~' - r ~rov~ Copy / / Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "lnJen~lons" in Trlphcate and "Subsequent Reports" ~n Duphcate TRA~IS::ITTAL : F~,u,'~. j.J. Pa,.,,el eK/Ann Simon~-'~_n ~ATE' ~- Z~- ~/ WELL . · Transmitted here,,v~th are the fol]c'.,'~ng' PLEASE NOTE' BL - BLUELI;IE, S - SEPIA, F - FILM, T - TAPE RECEIPT AC~,, -- '" - -. ~/PLEASE RETU2;I RECEIPT TO: A~CO At_ASr~, ILC. Al~sk~OIJ&Gasgons. Gommission ATT~' A~;~l SI~'~' ~l Anchorage ,.,,~,IS E - AFA/3] P.O. BOX 360 ~ AK o~10 A~ STATE OF ALASKA ~ ALASK ,L AND GAS CONSERVATION C .,iMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WELL OTHER [] 2 Name of Operator ARCO Alaska, 3 Address Inc. P.O. Box 360, Anchorage, 4 Location of Well AK 99510 Surface location: 893' FSL, 631' FEL, Sec. 16, TllN, R10E 5 Elevation m feet (indicate KB, DF, etc ) 105.5 12 Lease Designation and Serial No ADL 25651 7 Permit No 80-80 8 APl Number 50- 029-20495 9 Umt or Lease Name Kuparuk 25651 10 Well Number E-7 11 F~eld and Pool Kuparuk River Field Kuparuk River Oil Check Appropriate Box To Indicate Nature of Not~ce, Report, or Other Data P°°iI NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tr~phcate) (Submit ~n Duplicate) Perforate [] Alter Casing [] Perforations E~ Altering Casing [] Stimulate [] Abandon [] St~mulauon [] Abandonment [] Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Report multiple completions on Form 10-407 w~th a submitted Form 10-407 for each completion ) 13. Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of starting any proposed work, for Abandonment see 20 AAC 25 105-170) Began operations on 7/11/81. Tagged fill over area to be perf'd. RU CTU & test to 4000 psi. Circ. in hole w/diesel. Circ thru fill 9203'. Circ until clean, total 199 bbl pumped. RU perf unit & test lub to 3000 psi. Perf'd intervals 9138'-9175', 9106'-9128', 8793 '-8832', 8757 '-8793', 8721 '-8757', & 8686 '-8721' w/Schlumberger 2 1/8" Enerjet w/4 SPF. RIH with HP, Gradio, Temp & Spinner Tools. Flowed well @ rate of Ran production logs. well on 8/24/81. to 1222 BOPD. GOR=387, FTP=100 psi, FBHP=1602 psi. SI well f/PBU. Final BHP=3162 psi. Secured NOTE: HP tool set at 6117' ss SEP '2 ¥ ~_~5¢2~ 0ii & Gas Cons. C0mmis 14 I hereby certify that the foregoing ~s true and correct to the best of my knowledge S,gned./1 /1 ~': % '(~~ T,tle Area O]~eratio_ns Engineer The space ~<~ow for Commlsslon/~e Conditions of Approval ~f any By Order of Approved by COMMISSIONER the Commission Date Form 10-403 Rev 7-1-80 Submit "IntentIons" ~n Triplicate and "Subsequent Reports" ~n Duplicate ..... .TTTA: ~'6 6'~ · J. J. Pa::ele:-,/Ann S~mon:en Trans.mit~ed herev:ltn are ~h.. foilo:.:in§ PL=~CE :,O:E' BL - BLUEL!,,E, S - SE?=A, F - FILM, T - TAPE RECEIVED DATE' ,qFP_. - 4 ]noouj Alaska Oil & Gas Cons. Commission Anchorage STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION C MMISSION SUNDRY NOTICES AND REPORTS ON WELLS 1 DRILLING WELL [] COMPLETED WE LI_X2] OTHER 2 Name of Operator 7 PermltNo ARCO Alaska Inc. 80-80 3 Address 8 APl Number Box 360 Anchorage, Alaska 99510 50-029-20495 4 LocatIon of Well Surface Location: 5 Elevation m feet (md~cate KB, DF, etc ) - KB elevation =105:5' 12. 893' FSL¢ 631 FEL,, Sec 16, TllN, R10E 6 Lease Des~gnanon and Serial No AnT. 25651 9. Unit or Lease Name Kuparuk 25651 10 Well Number E-7 11 F~eld and Pool Kuparuk River Field Kt]Daruk River Oil Check Approprmte Box To Indicate Nature of Not~ce, Report, or Other"Data POO NOTICE OF INTENTION TO SUBSEQUENT REPORT OF (Submit ~n Tr~plmate) (Submit m Duplicate) Perforate [~ Alter Casing [] Perforations [] Altering Casing [] Stimulate [] Abandon [] Stimulation [] Abandonment r'~ Repair Well [] Change Plans [] Repairs Made [] Other [] Pull Tubing [] Other [] Pulhng Tubing [] (Note Reportmult~plecomplet~onson Form 10-407w~thasubm~tted Form 10-407 for each compleuon ) 13 Describe Proposed or Completed Operations (Clearly state all pertinent detads and g~ve pertinent dates, ~nclud~ng estimated date of start,rig any proposed work, for Abandonment see 20 AAC 25 105-170) ARCO Alaska Inc. 8686-8832, 9106-9128, and 9138-9175 of the upper and lower Kuparuk Sands. All wire line work will be done through a 3000 psi lubricator which will be pressure tested after being installed on the wellhead. proposes to perforate and slow test selected intervals of RECEIVED Expected start date 7/20/81 JUL 1 4 1981 0ii & Gas Cons. C0mmiss~on Anchorage 14 I hereby/~rt~fy tha/~e // ~- The space below fg6 C(~hmlss~on foregoing {s true and correct to the best of my knowledge Kuparuk Startup Director Date 7/10/81 Condlt,ons of Approval, if any Approved by. ORIGINAl. SIGNED BY LON;4IE C. SMITH Approved 'opy Returned By Order of COMMISSIONER the Commission Date '7//4/0°/ Form 10-403 Rev 7-1-80 Submmt "1 ntentlons" {O Trmpllcate and "Subsequent Reports" ,n Duplicate NORTH SII)PE ENG~ Transmitted herewith are the following- From: J. J. Pawelek / Leo Lash Please note: RL - Blueline, S - Sepia, F - Film, T - Tape ARCO Alaska, Inc. Attn. Leo Lash / AFA-311 P. O. Box 360 Anchorage, AK 99510 RECEIVED FEB ? 7 ]~81 gJ~ska Oii& G~s Cu.s. 6ommlssiot~ Anchorag~ DATE' NORTH SLOPE DISTRICT ENGINEERING ~ J___l. R~s ,.,: ~, TRANSMITTAL # -~~ J~NG _ L_L!_ENG FROM' Jerry/ J Pawelek/Leo Lash ~.]_GEOL---- WELL NAME' ~lA J) I~ ~ tA ~ c=--- ._~ T~'- Transmitted herewith are the following for the subject well' DATE SCALE XEROX SEP IA _~ STA_~ BL FILF: ',-'"~ LINE FILM BHC Sonic/Gamma Ray Log Io-II-I~) Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Mul ti -shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density i~)-I~-~) Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log ! / I RECEIPT ACKNOWLEDGED FOR' DATE: LE/ASE RETURN RECEIPT TO' REEEIVEB- ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360- Rm. #311-FAB Anchorage, AK 99510 December 1, 1980 Mr. P. A. Van Dusen District Drilling Engineer Arco Oil and Gas Comapny P.O. Box 360 Anchorage, Alaska 99510 Re .' P.B.U. DS 2-17 P.B.U. DS 11-14 P.B.U. DS 17-4 Kuparuk D-6 Kuparuk D-7 K upa Kuparuk We have checked our files and do not find Completion Reports (form 10-407) on the subject wells. We understand the report on P.B.U. DS 2-17 was waiting for a final directional survey to be received. Available information indicates the other wells have been drilled and were completed as unperforated oil wells during October, 1980. Please check your transmittals to confirm that the forms have been sent. If they have not, send the appropriate 10-407 forms at this time. Please let us know if it is necessary to delay the final reports until receipt of directional surveys on any of the wells. Sincerely, , John A. Levorsen Petroleum Geologist JAL ~ mm ARCO Oil and Gas .c.-'~mpany~ North Slope( tnct Post Ofhce Bux 360 Anchorage Alaska 99510 Telephone 907 277 5637 November 26, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: DS 17-4 Permit #80-85 DS 5-2 Permit #74-36 DS 2-4 Permit #70-17 DS 17-5 Permit #80-96 DS 1 5-10 Permit #80-88 DS 15-21 Permit #80-91 DS 14-9 Permit #80-89 Kuparuk E-7 Permit #80-80 D-6 Permit #79-96 D-7 Permit #79-112 D-5 Permit #79-95 E-4 Permit #80-57 E-8 Permit #80-81 D-3 Permit #79-84 Dear Sir: Enclosed please find: 1. A completion report, drilling history and a gyroscopic multishot survey for wells; DS 17--4, E-7, D-6, D-7 & E-8. 2. A Sundry Notice of subsequent report for wells; DS 5-2, DS 2-4, D-3, D-5 & E-4. (An updated Completion Report will be filed, for D-3, D-5 & E-4 as soon as produc- tion test data becomes available.) 3. A monthly report of drilling for wells; DS 17-5, DS 15-10, DS 15-21, DS 14-9,.E-8 & D-7. Very truly yours~ , ~, P. A. VanDusen District Drilling Engineer PAV:sp Enclosures FJ £ C':: 4t.~ska 0,I ,.S ,3],. ARCO 011 and Gas Company is a Division of AtlanticRlchfleldCompany Form ( SUBMIT IN DUY ,E* STATE OF ALASKA (see ot.er structlons on reverse side) OIL AND GAS CONSERVATION COMMITTEE WELL COMPLETION OR RECOMPLETION REPORT AND LOG* WELLI I DRY[~ Other b TYPE OF COMPLETION NEW I--~ WORK DEEP- PLUG DIFF WELLI ~1 OVERLY] EN B F-1 RESER BACK F1 Other 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360, Anchoraqe, AK 99510 4 LOCATION OF WELL (Report location clearly and in accordance with any State requirements)* At surface 893' FSL, 631' FEL, Sec 16, TllN, RIOE, UM At top prod ~nterval reported below AttotlalldZ~hI FNL, 1373' FEL, Sec 15, T]IN, R10E, UM p 969' FNL, 996' FEL, Sec 15, TllN, RIOE, UM 5 APl NUMERICAL CODE 50-029-20495 6 LEASE DESIGNATION AND SERIAL NO ADL 25651 7 IF INDIAN. ALLOTTEE OR TRIBE NAME 8 UNIT, FARM OR LEASE NAME Kuparuk 25651 9 WELL NO E-7 10 FIELD AND POOL, OR WILDCAT Kuparuk Prudhoe Baby Fie]d/River 0il I SEC ,T, R, M, (BOTTOM HOLE Pool OBJECTIVE) Sec 15, TllN, RIOE, UM 12 PERMIT NO 80 -80 13 DATE SPUDDED 9/23/80 18 TOTAL DEPTH MD & TVD j19 PLUG BACK MD & TVDJ20 IF MULTIPLE COMPL J 9310' MD 6'711' Tv[J) 9D~6~3H' MD 6636' TVI~ HqWU~NY'slng, e' 121 ROTARY TOOLSall 22 PRODUCING INTERVAL(S), OF THIS COMPLETION BOTTOM. NAME (MD & TVD)* Top Kuparuk 8670' MD 6237' ?~P' Top Lower Sand 9094' MD 6559' TVD Top Upper Sand 8680' MD 6245' TVD Base Lower Sand 9174' MD 6615' TVD Ba_~_ ,Unner Sand RR6R' MD 6393' TVD ga_~e Kunaruk 9213' MD 6643' TVD 24 TYPE ~ECTRIC AND OTHER LOGS RUN ' DIL/GR/BHCS, FDC/NGT/CAL, GR/CBL/CCL 25 CASING SIZE 16" 26 CASING RECORD (Report all strings set In well) IGRADE J DEPTH SET {MD) H-40 J 80' K-55 13249' K-55 I 9289' LINER RECORD WEIGHT, LB/FT 65 45.5 SIZE TOP (MD) BOTTOM (MD) SACKS CEMENT* 26 PRODUCTION 28 PERFORATIONS OPEN TO PRODUCTION (Interval, size and number) 30 INTERVALS DRILLED BY CABLE TOOLS 23 WAS DIRECTIONAL SURVEY MADE yes n/a DATE FIRST PRODUCTION n/a HOLE SIZE J CEMENTING RECORD J AMOUNT PULLED 24"1 200 sx permafrost to surflace 13 3/4" - 1500 sx fondu & 350 sx Arlcticset to surf. 8-3/4" 315 sx Class G cmt | m 27 TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) SCREEN (MD) 3~ 8598 8533 29 ACID, SHOT. FRACTURE. CEMENT SQUEEZE, ETC DEPTH INTERVAL (MD) n/a AMOUNT AND KIND OF MATERIAL USED IPRODUCTION METHOD (Flowing. gas lift, pumping--size and type of pump) DATE OF TEST HOURS TESTED CHOKE SIZE FLOW TUBING ICAS NG PRESSURE CALCULATED PRESS I 24-HOUR RATE 31 DISPOSITION OF GAS (Sold, used for fuel, vented, etc ) FOR OIL-BBL GAS--MCF WATER-BBL I GAS--OI L RATIO TEST PERIOD I OIL-BBL GAS--MCF WATER-BBL I OIL GRAVITY-APl (CORR) I I I I TEST WITNESSED BY 32 LIST OF ATTACHMENTS Drilling history ~nd Gryosc0pic surve~y. 33 I hereby certify that~e foregoing i~d attj[c~ed information is cornplete and correct as determined from all available records *(See instructions and Spaces for Additional Data on Reverse Side) DATE ~- ~'~"' '.IN UCTIONS ~ ' - 'his form is design~ed for sub, m[tt. ing~ com,~pleteland correct well completion report and Icg on all types of in Alaska. .Indicate~ which elevation IS use~t a~ rqferen~ (where not otherwise shown) for depth measurements given in ~s on thru form and m any~ttac~ments. [,nd.~22:~ If this well ~s c~,'leted fo~ sepa[~roduc~ion from more than one interval zone (multiple eom- i~state i~ item 20, and in item 22 show t~e ~r~ucmg interval, or intervals, top(s), bottom(s) and name(s) ) f~'r 6~ly t~e interval report(~ ~n i~e:~0. Su(m~ 4~p~rate' re-Pg~f (page~ on this form, ~dequately identified, ich additional ~nte~al to be separately produced, showing the additional data pertinent to such interval. : "Sacks Cement": Attached supplemental recoyds for ~his well should show the details of any multiple stage ing;and~ the location of the cementing.,. ~oo¢, 28: Submit a' separate completion repQ~ ~n thi~;f~m~ {or e~ch inter~.~l to be separately produced. (See instruction ' . ' t [ ~',~%~ _ = O .. MEAS. DEPTH TRUE VERT. DEPTI ~.~;~, ' .:::,~ ,1 .dj ' !,_.. ~;~;.:~ ~ .--" ,' ' ,,~, T Up ~and 8680' .. 6245' ~~:-~;:*~ , ~ ~ :¢~ ¢~i-;.::i ' _ :-' .- T:L-Sand' 9094' 6559' ~-~ , -, ....... ~ t I ~ ~ , ~--~'- ,~.~ -, B L Sand 9174' ~ZA~QH BRIEF DESCRIPTIONS OF LITHOLOGY, PQROSITY, ER~CTURES, APPARENT, DIPS DRILLING HISTORY KUPARUK E-7 API //50-029-20495 Permit No. 80-80 Spudded Well at 0605 hrs 9/23/80. Drld 13-3/4" hole to 3362'. Ran 78 its 10-3/4" 45.5# K-55 csg and landed at 3249'. Cmtd csg w/1500 sx Fondu and 350 sx Arcticset II to surface. NU and test BOPE. Clean out csg and drill 10' new 8-3/4" hole to 3272'. Test formation to 10.5 ppg EMW. Displace hole w/ oil mud. Drld 8-3/4" directional hole to 9230'. Log w/DIL/ GR/BHCS 9222'-3247' and FDC/NGI/CAL 9222'-3247'. Shoot s~dewall cores. Drld 8-3/4" hole 9230'-9310'. Ran 230 jts 7 26# K-55 csg and landed at 9289' Cmtd w/315 sx of Class G cmt. Installed packoff and teste~ w/3000 psi. Arctic Pak 7" x 10-3/4" annulus. Clean out 7" csg to 9203' PBTD. Ran GR/CBL/CCL log, ran Gyro/CCL. Ran 3½" tbg and completion assy and land w/tail @ 8598' and pkr at 8533'. Displace well to diesel, set pkr, and install BPV. ND BOPE, NU tree and test w/3000 psi. Rig lines to begin long term tubing test. Rig released 1430 hrs 10/13/80. SC I ENTIm IC' np2,i[,'r.,I Mc_. COMTPOT.g 700 W 41qT ?TPRRT q[t~ 101 ~NC-OP~CF hL?~},';~ cyr, n.ccoPIc DIPECTIO~,t~L .eUPVFY FOP · * ;~PCO Oil, :~"ID GD.~ * ******************** FOpw~y D~T~:-~ cUPWPv F~]c ~ FFF: ~q~L TE P CYPO' nnPwPR~?mE .P. EA?Tt~C.: :100-00P '~PT~On OF C'~T,c'TTL~TIc)M: PADTrlF n~' CItVV~TUPE VPPTTCnL SFCTIOM CALCTILATEQ T"T A PP,aPr)~;~L r)TPECTIOH OF: M 56-].5 F ***nFP'IP "PAFUPED I~1 FEET*** COq"F'TTg: lqT PTP] %':ITH P'I~ C~'IEP;~ .°M~l16 C, YPO ]07 2~]r~ r, lT,,T VITIt C;~Er'A F,~?~107 GYr'~ 236 90 r)FCPEE AMGL~ U~.1Im F,~,]~i]R,TIF I~t t,'A~- .~T ~00 FT. pIt:l AS ;~ TPUE V~LUE ~UPVF¥ ********************************* *TTTT,C 9UPwEY IF CtnP~-ECW Tm Tttm * *E[IppoDmFn Dy B~TrI~T PTFLD O~TA.* * ********************** * * CO'~pBMY DPDP~oPt~T~T T~r * ********************************* COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FH LINDSEY & ASSOC 24 OCT 80 KUPARUK E-7 KB ELEV 105.5 FT. JOB NO BSWIAL RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE ~1EAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 0 0 0 100 0 0 200 0 15 BO0 0 30 400 0 30 500 2 30 6OO 3 45 700 6 0 800 q 45 900 12 45 1000 16 45 0.00 -105,50 N O.OOE 100,00 -5.49 N52.10E 199,99 94,49 S72,88E 299.99 194,49 S29.20W 399,99 294,49 N22,23E 499,95 394,45 S86,78E 599,80 699.43 798.47 896.54 993,22 0.00 S 0.00 S 0.03 N 0.49 S 0.24 S 1,06 N 494,30 N58,75E \ 2.36 N 593.93 NSO.28E 7.29 N 692,97 N56.23E 15.48 N 791.04 N52,78E 26.81 N 887,72 N4q.77E 42.73 N 1130 ]e 45 1088,18 982.68 NSO.15E 123(I 22 45 1181.37 1075.87 NSO,OSE 1300 26 0 1272.45 1166.95 NS1.78E 1400 30 0 1360.72 1255.22 N52.35E 1500 33 15 1445.86 1340.36 NSO.68E 1600 34 0 1529,13 1423.63 N48.92E 1700 37 0 1610.53 1505.03 N49.67E 1800 42 15 1687.53 1582.03 N51.50E 1900 45 30 1759.60 1654.10 NSI.OOE 2000 46 15 1829.22 1723.72 NSOo92E 2100 46 15 1898.38 1792.88 NS1.48E ,2200 45 45 1967.84 1862,34 NS1.38E 2300 45 30 2037.78 1932.28 N49.85E ~400 45 15 2108,02 2002.52 N50.42E 62.87 N 86.12 N 112.14 N 140.99 N 173.62 N 209.36 N 247.22 N 287.70 N 331.08 N 376.29 N 421.55 N 466.40 N 511.76 N 557.38 N 0,00 W 0,00 W 0.20 E 0,41 E 0.10 W 1,97 E 7.18 E 14.09 E 25,06 E 40,94 E 60.80 E 84o7T E 112.57 E 144.60 E 181.62 E 222,66 E 264.96 E 308.97 E 358.22 E 412.27 E 468,02 E 524.32 E 580,56 E 635.80 E 690,43 E CLOSURES DISTANCE ANGLE D M S DOG LEG SEVERITY DEG/iOOFT 0,00 S 0 0 0 W 0,00 S 0 0 0 w 0.20 N 79 36 36 E 0.64 S 40 23 38 E 0.26 S 22 35 12 W 2.24 N 61 34 54 E 7,56 N 71 45 10 E 15,87 N 62 37 58 E 29,46 N 58 17 25 E 48.94 N 56 46 58 E ' 74,32 N 54 53 57 E 105.55 N 53 26 8 E O.O00 O.OCO 0,250 0.250 0.998 2.005 1,259 2.252 3,754 3.005 4,008 3.000 141.74 N 52 34 59'E I 3.000 182.99 N 52 12 25 E 229.93 N 52 10 41 E 282.35 N 52 3 17 E 337,69 N 51 41 7 E 395.71 N 51 20 4 E 459.45 N 51 13 50 E 528.75 N 51 13 59 E 600.53 N 51 I2 i E 6?2,77 N 51 12 1 E 744,70 N 51 13 21 E 816.18 N 51 10 9 E 887,34 N 51 5 11 E 3.267 4.003 3.289 0,930 3.012 5.315 3.260 0,751 0,405 0.503 0.818 0,381 SECTION DISTAFNCE 0.00 0.00 0.19 0.06 -0.22 2.22 7.24 15.73 29.42 48.9~ 74.~ 105.50 141.59 i82.74 229.61 281.93 337.06 394.81 458,36 527,49 599,08 671.14 742.92 814.17 885.06 ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO ~WIAL 24 OCT 80 RECORD QF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE ~IEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC OEO, TOTAL COORDINATES 25')0 46 0 2177.96 2072.46 NSO.97E 2600 47 30 2246.47 2140.97 NSO,48E 2700 49 45 2312.57 2207.07 N48,75E 2800 50 30 2376.68 2271.18 N49.10E 2900 50 0 2440.62 2335.12 N48.47E 3000 40 45 2510.79 2405,29 N48.78E 3100 48 30 2581.91 2476.41 N47.47E 3200 49 30 2647.52 2542.02 N47.20E 3300 50 30 2711.79 2606.29 N48.20E 602.65 N 745.74 E 648.76 N 802.12 E 697.38 N 859.27 E 747.80 N 917,13 E 798.46 N 974.96 E 845,45 N 1028,31 E 892.30 N 1080.58 E 943.45 N 1136.07 E 995.00 N 1192.73 E 3400 53 30 2773,35 2667,85 N47,10E 1048,08 N 1250,96 E 3500 55 45 2831,24 2725.74 N45,90E 1104,20 N 1310,10 E 3600 56 30 2886,98 2781,48 N44,00E 1162,96 N 1368,75 E 3700 56 45 2941,99 2836,49 N44,10E 1222.98 N 1426,82 E 3800 54 30 2998,45 2892,95 N47,07E 1280,73 N 1485,76 E 3900 50 45 3059,14 2953,64 N55.48E 1330,39 N 1547,69 E 4000 51 0 3122,24 3016,74 N58.42E 1372.70 N 1612,71 E 4100 51 0 3185,17 3079.67 N57.75E 1413,78 N 1678,68 E 4200 51 0 3248,11 3142,61 N57,85E 1455.19 N 1744,44 E 4300 52 45 3309,84 3204,34 N59.08E 1496.34 N 1811,48 E 4400 53 45 3369,67 3264,17 N59,47E 1537.27 N 1880,36 E 4500 54 45 3428,10 3322.60 N60.60E 1577,81 N 1950.67 E 4600 56 30 3484,56 3379,06 N62,87E 1616,89 N 2023,35 E 4700 56 45 3539,57 3434,07 N62.82E 1655.00 N 2097,66 E 4800 51 30 3598,15 3492,65 N60,57E 1693,41 N 2168,97 E 4900 50 30 3661,08 3555,58 N56,35E 1734,05 N 2235,19 E 5000 49 0 3725.69 3620.19 N56.95E 1776.01 N 2298,94 E 5100 47 45 3792,1'1 3686,61 N56.35E 1817.10 N 2361,38 E 5200 47 0 3859,83 3754,33 N55,57E 1858,29 N 2422,39 E · 5.300 47 0 3928,0.3 3822,53 N55,67E 1899,59 N 2482,71 E CLOSURES DISTANCE ANGLE D M S 958.81 N 51 3 26 E 1031.65 N 51 2 1 E 1106.66 N 50 56 15 E 1183.36 N 50 48 25 E 1260.20 N 50 41 1 E 1331.25 N 50 34 25 E 1401.38 N 50 27 4 E 1476,74 N 50 17 31 E 1553,27 N 50 9 51 E 1631,99 N 50 2 34 E 1713,37 N 49 52 28 E 1796,10 N 49 38 49 E 1879,23 N 49 23 55 E 1961,57 N 49 14 18 E 2040,91 N 49 19 3 E 2117,81 N 49 35 46 E 2194,71 N 49 53 45 E 2271,71 N 50 9 55 E 2349,57 N 50 26 32 E 2428,78 N 50 43 57 E 2508,90 N 51 1 55 E 2590,04 N 51 22 16 E 2671,93 N 51 43 38 E 2751,74 N 52 1 9 E 2828,96 N 52 11 44 E 2905,05 N 52 18 45 E 2979,60 N 52 25 17 E 3053,04 N 52 30 23 E 3126,07 N 52 34 46 E DOG LEG SEVERITY DEG/100FT 0,802 1,523 2.465 0,778 0,622 9,251 7,785 1,012 1.164 3.083 2.395 1.519 0,260 2,990 6,285 1,793 0.521 0,078 1,916 1,032 1,252 2.357 0.252 5,428 2.704 1.538 2.293 0,858 0,073 · SECTION DISTANCE 956.32 1028.94 1103.61 1179.90 1256.30 1326.93 1396.59 1471.35 1547,30 1625.41 1706.01 1787,71 1869.64 1951.01 2030.2-~,N 2107.~ 2185,35 2262.99 2341.52 2421,44 2502.30 2584.29 2667,06 2747.53 2825.10 2901.40 2976.12 3049.69 3122.83 AR~O KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BSWIAL 24 OCT .80 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, TOTAL COORDINATES 5400 47 45 3995,75 3890.25 N55,ISE 1941.36 N 2543,28 E 5500 47 45 4062.99 3957.49 N54.88E i983.80 N 2603.93 E 5600 48 0 4130.06 4024.56 N54.55E 2026.64 N 2664.47 E 5700 4~ 0 4196.98 4091.48 N55.02E 2069.49 N 2725.19 E 5800 48 30 4263.57 4158.07 N54.95E 2112.30 N 2786.29 E 5900 48 45 4329.66 4224.16 N54.97E 2155.39 N 2847.73 E 6000 49 0 4395.43 4289.93 N55,22E 2198,49 N 2909.50 E 6100 49 45 4460.54 4355.04 N54.90E 2241.96 N 2971.72 E 620u 50 0 4524.99 4419.49 N55.83E 2285.42 N 3034,64 E 6GQO 50 0 4589.27 4483.77 N56.i7E 2328.25 N 3098.I4 E 6400 50 0 4653.55 4548.05 NS?,27E 2370.29 N 3162.i8 E 6500 50 0 4717.83 4612.33 NS?.62E 2411.5i N 3226.75 E 6600 50 I5 4?81,94 4676.44 N58.2?E 2452.24 N 3291.80 E 6700 50 30 4845.?I 4740.21 N59,13E 2492.25 N 3357.61 E 6800 50 i5 4909.49 4803.99 N59.63E 2531.49 N 3423.89 E 6900 51 0 4972,93 4867.43 N58.63E 2571.I5 N 3490.24 E 7000 5I i5 5035,69 4930.I9 N57.68E 2612.22 N 3556.37 E 7100 5] 15 5098.28 4992.78 N57.68E 2653.92 N 3622.28 E 7200 51 0 5161.05 5055,55 N56.55E 2696.19 N 3687.65 E 7300 49 0 5225.32 5119.82 N56.27E 2738.57 N 3751.46 E 7400 47 45 5291,74 5186.24 N54,75E 2780.89 N 3813,07 E 7500 46 15 5359,94 5254,44 N56.25E 2822.32 N 3873.34 E 7600 44 45 5430,03 5324,53 N56.90E 2861,60 N 3932.87 E 7700 44 0 5501.51 5396.01 N56.80E 2899.85 N 3991,42 E 7800 43 30 5573,74 5468.24 N56,98E 2937,62 N 4049.34 E 7900 43 0 5646.58 5541.08 N58.08E 2974.40 N 4107.15 E 8000 42 0 5720,31 5614.81 N59.83E 3009~4 N 4165.03 E 8100 41 30 5794.91 5689.41 N59.22E 3043.01 N 4222.42 E 8200 41 0 5870,10 5764.60 N59.77E 3076.48 N 4279,22 E CLOSURES DISTANCE ANGLE D M S 3199.56 N 52 38 40 E 3273.52 N 52 41 53 E 3347.64 N 52 44 33 E 3421.91 N 52 47 13 E 3496,46 N 52 50 2 E 3571.45 N 52 52 43 E 3646.72 N 52 55 27 E 3722.57 N 52 58 4 E 3798.97 N 53 0 58 E 3875.47 N 53 4 30 E 3951.92 N 53 8 44 E 4028.31 N 53 13 38 E 4104,80 N 53 18 55 E 4181,49 N 53 24 52 E 4258.11 N 53 31 20 E 4335,04 N 53 37 19 E 4412.65 N 53 42 7 E 4490.46 N 53 46 15 E 4568.18 N 53 49 40 E 4644.70 N 53 52 14 E 4719,42 N 53 53 47 E 4792.52 N 53 55 15 E 4863.77 N 53 57 35 E 49..33.62 N 54 0 3 E 5002.68 N 54 2 26 E 5071.07 N 54 5 16 E 5138.39 N 54 9 6 E 5204.69 N 54 13 13 E 5270.34 N 54 17 10 E DOG LEG SEVER I TY DEG/iOOFT 0,802 0.200 0,309 0,349 0,502 0,250 0,28~ 0,773 0,600 0.260 0.843 0.268 0.458 0.570 0.387 0,963 0.630 0.000 0,727 2.006 1.502 1,692 1.534 0,752 0.507 0.715 1.270 0,567 0,553 SECTION DISTANCE 3196.41 3270.43 3344.59 3418.91 3493.51 3968.55 3643.88 3719,78 3?96.24 3872.84 3949.41 4025.96 4102.61 4179.49 4256.31..,.~ 4333.4~ 4411.17 4489.08 4566.89 4643.47 4718.22 4791.35 4862.65 4932.56 5001.68 5070,14 5137.55 5203.94 5269,69 APCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BSWIAL RECORD OF SUR{/EY ALL CALCULATIONS PERFORMED BY~ I B M ELECTRONIC COMPUTER 24 OCT 80 TRUE N,'EAS. DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG. TOTAL COORDINATES 8300 39 45 5946.28 5840.78 N60.68E 3108.65 N 4335.45 E 8400 39 0 6023,58 5918,08 NGO,22E 3139~94 N 4390,64 E 8500 38 0 6101,84 5996,34 N63.70E 3169,20 N 4445,57 E 8600 36 45 6181.31 6075,81 N65.12E 3195.41 N 4500,32 E 8700 37 30 6261,04 6155,54 NGI.O2E 3222.74 N 4554.12 E 8800 38 0 6340.11 6234,61 N62.28E 3251.81N 4607.99 E 8900 41 15 6417.12 6311.62 N62.80E 3281.22 N 4664.58 E 9000 43 15 6491,14 6385.64 N62,40E 3312.16 N 4724.27 E 9100 45 0 6562,92 6457.42 NGI,15E 3345.08 N 4785.61E 9150 45 0 6598,27 6492.77 NGO,70E 3362,27 N 4816,51E THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TD 9310 45 0 6711.41 6605.91 NGO,70E 3417.63 N 4915.17 E BOTTOM HOLE CLOSURE 5986.58 FEET AT N 55 11 17 E CLOSURES DISTANCE ANGLE D M 5 5334,78 N 54 21 29 E 5397.86 N 54 25 47 E 5459.57 N 54 30 55 E 5519.38 N 54 37 25 E 5579.07 N 54 42 52 E 5639.85 N 54 47 23 E 5703.04 N 54 52 34 E 5769.67 N 54 57 57 E 5838.81N 55 2 48 E 5873.98 N 55 4 55 E 5986.58 N 55 11 17 E DOG LEG SEVERITY DEG/iOOFT 1-304 0.772 1.655 1,349 1.694 0.691 3,258 2.009 1.858 0,636 0.000 SECTION DISTANCE 5334.2z 5397.39 5459.20 5519.I1 5578.88 5639,72 5702.96 5769.63 5838.79 5873.97 5986.58 .o ARCO OIL 8~ GAS ---, -- DRILL SITE KUPARUK E- RADIUS OF CURVATURE "- _ . · GYRO,~C OPIC---- ' SCALE_ I"= I000' : NOV 551980 · 'TIJN~ RIOE~ U,.M. . - oo - % ........ TVD -- 6711 e°°o TMD = 9510' ALL -DEP:I'HS SHOWN ARE TVD' _, t 400 eoo SURFACE LOCATION IS ........... 89:5' NSL, 631' WEL, SEC TIIN, R~OE, U.M. VERTICAL SECTION ARCO OIL I~ GAS DRILL SITE KUPARUKE-~ RADIUS OF CURVATURE GYROSCOPIC ........ SCALE I"= I000' NOV 5, 1980 ARCO KUPARUK E-7 24 OCT 80 INTERPOLATED VALUES FOR EVEN TRUE MEASURED VERTICAL DEPTH DEPTH 1000 993. 2000 1829. 3000 2510. 4000 3122, 5000 3725, 6000 4395, 7000 5035, 8000 5720, 9000 6491, GYROSCOPIC SURVEY JOB NO BSWIAL 1000 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES 887, 43.00 N 60,58 E 1723. 376.74 N 467.66 E 2405, 846.03 N 1027,80 E 3016. 1373,21 N 1612,37 E 3620. 1776.73 N 2298e46 E 4289, 2199.13 N 2909,05 E 4930. 2612.98 N 3555.90 E 5614, 3009,70 N 4164.75 E 6385. 3312.78 N 4723.94 E ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BSWIAL MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF SUB ~'SEA DEPTH, 24 OCT 8O TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES · e 206 306 406 506 606 706 807 909 1013 1118 1226 1337 1452 1571 1694 1824 1966 2110 2254 2~96 2540 268q 2845 2993 313~ 3290 3455 3833 3812 3973 4132 4293 4461 4638 4811 206, 100 0 0 306, 200 0 0 406, 300 0 0 506, 400 0 0 606, 500 0 0 706, 600 0 0 806. 700 . 1 1 906, 800 3 2 1006, 900 7 4 1106, 1000 12 5 1206. 1100 20 8 1306. 1200 31 11 1406. 1300 46 15 1506. 1400 65 19 1606. 1500 88 23 1706, 1600 118 30 1806, 1700 160 42 1906, 1800 204 44 2006, 1900 248 44 2106, 2000 290 42 2206. 2100 334 44 2306. 2200 383 49 2406. 2300 439 56 2506, 2400 487 48 2606. 2500 529 42 2706, 2600 584 55 2806. 2700 649 65 2906. 2800 727 78 3006. 2900 806 79 3106. 3000 867 61 3'206, 3100 926 59 3306. 3200 987 61 3406. 3300 1055 68 5506, 3400 1132 77 3606. 3500 1205 73 0.02 N 0.22 E 0.53 S 0.39 E 0.19 S 0.07 W 1.05 N 2.21 E 2.57 N 7.50 E 7,70 N 14,58 E 16.16 N 26,06 E 28,05 N 42,53 E 45,18 N 63,62 E 66.84 N 89,49 E 92,68 N 120,43 E 122.57 N 157.58 E 157.60 N 202.49 E 199.19 N 252,38 E 245,36 N 305,60 E 297,94 N 370,86 E 360.93 N 448.71 E 426,10 N 529,93 E 490,95 N 610,30 E 556,15 N 687,75 E 621.24 N 767,89 E 692.40 N 852,51 E 770.65 N 943,20 E 842,94 N 1024,37 E 910,23 N 1099,80 E 990,04 N 1186,83 E 107B,79 N 1283,26 E 1182.77 N 1387.88 E 1287.36 N 1492.98 E 1361,96 N 1594,67 E 1427,33 N 1699,53 E 1493,94 N 1806,27 E 1562,48 N 1922,83 E 1631.77 N 2051,35 E 1697,74 N 2176.40 E ARCO KUPARUK E-7 MEASURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB FEET OF NO BSWIAL SUB SEA DEPTH, 2~ OCT .80 TRUE MEASURED VERTICAL DEPTH DEPTH SUB MD-TVD VERT I CAL SEA DIFFERENCE CORRECTION TOTAL COORDINATES 4969 3706, 3600 1263 5120 3806, 3700 1314 5267 3906. 3800 1361 5414 4006. 3900 1408 5563 4106. 4000 1457 5712 4206, 4100 1506 586~ 4306, 4200 1557 6015 4406. 4300 1609 6169 4506, 4400 1663 6325 4606, 4500 1719 6481 4706, 4600 1775 6637 4806. 4700 1831 6793 4906. 4800 1887 6952 5006, 4900 1946 7111 5106, 5000 2005 7269 5206, 5100 2063 7420 5306, 5200 2114 7565 5406, 5300 2159 7705 5506, 5400 2199 7844 5606, 5500 2238 7980 5706. 5600 2274 8114 5806, 5700 2308 8247 5906. 5800 2341 8377 6006. 5900 2371 8505 6106. 6000 2399 8630 6206. 6100 2424 8756 6306, 6200 2450 8884 6406, 6300 2478 9020 6506. 6400 2514 9160 O00Ol 6200 Z~4 9301 6706. 6600 2595 58 51 47 47 49 49 51 52 54 56 56 56 56 59 59 58 51 45 40 39 36 34 33 30 28 25 26 28 36 40 41 1763.63 1825.34 1886.37 1947,31 2011,24 2074.62 2140,07 2205.00 2272.69 2338.93 2404,01 2467,20 2529.15 2592,66 2658,60 2725,88 2789.53 2848.47 2901.79 2954,21 3002.79 3047.79 3092,06 3133.02 3170.49 3203.19 3239,18 3276,83 3318.64 3365,80 3415,65 N 2279,04 N 2373.55 N 2462.46 N 2551.77 N 2641,71 N 2732,49 N 2824.51 N 2918.78 N 3014.57 N 3114,04 N 3214.10 N 3315,90 N 3419.02 N 3524,33 N 3629,47 N 3731.67 N 3825.05 N 3912,12 N 3994.30 N 4074,35 N 4153.29 N 4230.36 N 4305.39 N 4377.67 N 4448,12 N 4516.55 N 4584.11 N 4655,05 N 4736,40 N 4822.63 N 4908,98 E E E E E E E E E E E E E E E E E E E E E E E E E E E E E E AR~O KUPARUK E-? · GYROSCOPIC SURVEY JOB NO BSwIAL INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE "~' CODE MEASURED VERTICAL TOTAL COORD I NATES N A,~IE DEPTH DEPTH CLOSURE DISTANCE ANGLE D M S 24 OCT .80 SUB SEA T KUPARUK 8670 6237,20 3214,15 N 4538,06 E T UP SAND 8680 6245,15 3216,99 N 4543,41 E R UP SAND 8868 6392,87 3271,95 N 4645.86 E T LOW S4ND 9094 6558.67 3343.33 N 4781.74 E B LOW SA~ID 9174 6615.24 3370,75 N 4831.21 E B ~UPARUK 9213 6642,82 3384,54 N 4855,09 E PLUG BACK 9203 6635.75 3381.00 N 4848.96 E TD 9310 6711,41 3417.63 N 4915.17 E 5561,00 N 54 41 28 E 6131.70 5567,01 N 54 41 57 E 6139.65 5682.40 N 54 50 38 E 6287.37 5834.63 N 55 2 21 E 6453.17 5890,89 N 55 5 46 E 6509.74 5918.36 N 55 7 9 E 6537.32 5911,32 N 55 6 48 E 6530,25 5986,58 N 55 11 17 E 6605.91 NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL# FROM' Jerrs J. Pawelek/Leo Lash WELL NAME' ~/M ~£~ ~- ~"- Transmitted herewith are the following for the subject well' DATE SCALE XEROX BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log ,/ BL SEPIA LINE FILM cCEIVEt RECEIPT ACKNOWLEDGED FOR' DATE' NOV 2 8 1~',~0 Nm.Mm Oil & Gas Cons. Commission Anchorage PLEASE RETURN RECEIPT TO' ARCo Oil and Gas Company Attn- Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 SC IEHTIm IC:~DPI~ Lit,lC CO~.tTPOT,g 700 i'~ ~,lqT STPFFT qHITE 101 .~NCTTOP~CF aL~?}:~ CYnr~cCOPlC DIpECm!r~];~[0 ~UPVFY FOP ******************** * ~nCO OIL ~'ID G~F * ******************** T,OC ~TIOU: ,,'UP A pr1T' CYPO rrr, rrw,~r.r, l~EaPTtlC,: :lO0-OOF '~pT~On OF ("~,r,r'llr.,ATTrlI,]: PADTU? r~ ~PrTTCnT. fiFCTIO~I C~T, CIIT, STETM T~I A Pr.~rnS.~[, nlrrcTIoN OP: ~l 56-]5 r ***~FP~I' ':FAFUPED I~l PERT*** · CO'~,"P'IT?: lqT pIP! %'ITU p,~e C~,Irp~ ~'N,~]16 GYPr~ ]07 2Nr~ nU'l I'IT' CP'IEnA ?~,107 Gyro 23~ 9q r~FcrE~ A~ICLr U~IIm St,!~].]P,TIP IN r,'A~- .~T an00 FT. PI"1 Aq ~ TprIE V~T,UE ~[lrVPy ********************************* *TUTS FUPWEY I? Car~.rc~ Ta T-~' * ********************************* COMPLETION REPORT ARCO OIL & GAS GYROSCOPIC SURVEY RADIUS OF CURVATURE METHOD OF COMPUTATION COMPUTED FOR SDC BY FM LINDSEY 6 ASSOC 24 OCT 80 KUPARUK E-7 -K~-"E~V 105,5 FT. JOB NO BSWIAL RECORD OF SURVEY ALL CALCULAfIONS PERFORMED BY I B M ELECTRONIC COMPUTER TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT SEA DIREC DEG, 0 0 0 100 0 0 100.00 200 0 15 199,99 300 0 30 299,99 400 0 30 399.99 500 2 30 499.95 600 3 45 599.80 700 6 0 699,43 800 9 45 798,47 900 12 45 8q6,54 1000 16 45 993.22 0.00 -105,50 N O,OOE -5.49 N52.10E 94.49 S72.88E 194,49 S29.20W 294.49 N22,23E 394.45 S86.78E 494,30 N58.75E 593.93 N50.28E 692.97 N56.23E 791,04 N52,78E 887,72 N49.77E llO0 lC 45 1088,18 982,68 NSO.15E 1200 22 45 1181.37 1075.87 NSO,OSE 13nD 26 0 i272.45 1166.95 NSI,78E 1400 30 0 I360.72 1255.22 N52.35E 1500 33 15 i445.86 i340.36 NSO,68E I600 34 0 1529,I3 I423.63 N48.92E 1700 37 0 i610,53 1505,03 N49.67E 1800 42 I5 1687.53 1582,03 NS1,50E I900 45 30 I759.60 1654.I0 NSI,OOE 2000 46 15 1329,22 1723,72 ,N50.92E 2!00 46 i5 I898.~8 1792.88 NS1.48E 2200 45 45 1967,84 1862,34 NS1,38E 2300 45 30 2037,78 1932,28 N49,85E 2400 45 15 2108.0.2 2002.52 N50,42E TOTAL COORDINATES 0,00 S 0,00 W 0,00 S O,CO W 0,03 N 0,20 E 0,49 S 0,41 E 0.24 S 0,10 W 1.06 N 1,97 E 2.36 N 7.18 E 7.29 N 14,09 E 15.48 N 25,06 E 26,81 N 40,94 E 42.73 N 60,80 E 62.87 N 84.77 E 86.12 N 112.57 E 112.14 N 144,60 E 140.99 N 181.62 E 173.62 N 222.66 E 209.36 N 264.96 E 247.22 N 308.97 E 287.70 N 358.22 E 331.08 N 412.27 E 376.29 N 468.02 E 421.55 N 524.32 E 466.40 N 580.56 E 511.76 N 635,80 E 557.38 N 690,43 E ~ DOG LEG C L 0 S U R E S SEVERITY DISTANCE ANGLE DEG/IOCFT D M S 0.00 S 0 0 0 W 0.00 S 0 0 0 W 0.20 N 79 36 36 E 0.64 S 40 23 38 E 0,26 S 22 35 12 W 2.24 N 61 34 54 E 7.56 N 71 45 lO E 15.87 N 62 37 58 29.46 N 58 17 25 E 48,94 N 56 46 58 E 74.32 N 54 53 57 E 105.55 N 53 26 8 E 141.74 N 52 34 59 E 182.99 N 52 12 25 E 229.93 N 52 10 41 E 282.35 N 52 3 17 E 337.69 N 5I 41 7 E 395.71 N 51 20 4 E 459.45 N 51 13 50 E 528.75 N 51 13 59 E 600.53 N 51 12 1 E 672.77 N 51 12 1 E 744.70 N 51 13 21 E 816.18 IN 51 iO 9 E 887,34 N 51 5 11 E 0.000 O.OCO 0.250 0.250 0.998 2.005 1.259 2.252 3.754 3.005 4.008 3.000 3.000 3.267 4.003 3.289 0,930 9.012 3,260 0.751 0,405 0.503 0.818 '0,381 S~CTION DISTANCE 0.00 0.00 0.19 0.06 -0.22 2.22 7.24 15.73 29,4~.~ 48.~ 74,31 105.50 141.59 182.74 229,61 281,93 337.06 394.81 ~58.36 527.49 D99,0~ 671.14 742,92 d14.1~ 8~5.0~ ARCO KUPARUK E-7 GYROSCOPIC SURVEY dOB NO BSWIAL 24 OCT 80 RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER MEAS, DRIFT DEPTH ANGLE D M 2500 46 0 2600 47 30 2700 49 45 2800 50 30 2900 50 0 3000 40 45 3100 48 30 3200 49 30 3300 50 30 3400 53 30 3500 55 45 3600 56 30 3700 56 45 3800 54 30 3900 50 45 4000 51 0 4100 51 0 4200 51 0 4300 52 45 4400 53 45 4500 54 45 4600 56 30 4700 56 45 4800 51 30 4900 50 30 5000 49 0 5100 47 45 5200 47 0 5300 47 0 TRUE VERTICAL SUB DEPTH SEA DRIFT DIREC DEG. 2177.96 2072.46 NSO.97E 2246.47 2140,97 N50.48E 2312.57 2207.07 N48.75E 2376.68 2271,18 N49.10E 2440.62 2335.12 N48.47E 2510.79 2405.29 N48.78E 2581.91 2476.41 N47.47E 2647.52 2542.02 N47.20E 2711.79 2606.29 N48.20E 2773.35 2667.85 N47.10E 2831.24 2725.74 N45.90E 2886.98 2781.48 N44.00E 2941.99 2836.49 N44.10E 2998,45 2892.95 N47.07E 3059,14 2953,64 N55,48E 3122.24 3016.74 N58,42E 3185.17 3079.67 N57.75E 3248,11 3142,61 N57,85E 3309.84 3204.34 N59.08E 3369.67 3264.17 N59,47E 3428.10 3322.60 NGO.60E 3484.56 3379,06 N62.87E 3539.57 3434.07 N62.82E 3598,15 3492,65 N60.57E 3661.08 3555.58 N56.35E 3725,69 3620,19 N56,95E 3792,11 3686.61 N56,35E 3859,83 3754.33 N55,57E 3928,03 3822,53 N55.67E TOTAL COORDINATES 602.65 N 745,74 E 648,76 N 802,12 E 697,38 N 859.27 E 747.80 N 917.13 E 798,46 N 974,96 E 845,45 N 1028,31 E 892,30 N 1080.58 E 943.45 N 1136.07 E 995.00 N 1192.73 E 1048,08 N 1250.96 E 1104,20 N 1310.10 E 1162.96 N 1368.75 E 1222.98 N 1426.82 E 1280.73 N 1485.76 E 1330.39 N 1547.69 E 1372.70 N 1612.71 E 1413.78 N 1678.68 E 1455.19 N 1744.44 E 1496.34 N 1811.48 E 1537.27 N 1880.36 E 1577.81 N 1950.67 E 1616.89 N 2023.35 E 1655.00 N 2097.66 E 1693,41 N 2168,97 E 1734-05 N 2235.19 E 1776.01 N 2298.94 5 1817.10 N 2361.38 E 1858.29 N 2422.35 E 1899.59 N 2482.71 E CLOSURES DISTANCE ANGLE D M S ,958.81 N 51 3 26 E 10'31.65 N 51 2 1 E 1106,66 N 50 56 15 E 1183.36 N 50 48 25 E 1260.20 N 50 41 1 E 1331.25 N 50 34 25 E 1401.38 N 50 27 4 E 1476.74 N 50 17 31 E 1553.27 N 50 9 51 E 16'31.99 N 50 2 34 E 1713.37 N 49 52 28 E 1796.10 N 49 38 49 E 1879,23 N 49 23 55 E 1961,57 N 49 14 18 E 2040.91 N 49 19 3 E 2117.81 N 49 35 46 E 2194.71 N 49 53 45 E 2271.71 N 50 9 55 E 2349.57 N 50 26 32 E 2428.78 N 50 43 57 E 2508,90 N 51 1 55 E 2590,04 N 51 22 16 E 2671.93 N 51 43 38 E 2'/51.74 N 52 1 9 E 2828,96 N 52 11 44 E 2905.05 N 52 18 45 E 2979.60 N 52 25 17 E 3053.04 N 52 30 23 E 3126,07 N 52 34 46 E DOG LEG SEVERITY DEG/IOOFT 0,802 1,523 2,465 0,778 0,622 9.251 7,785 1,012 1,164 3.083 2,395 1.519 0.260 2.990 6,285 1.793 0.521 0.078 1.916 1,032 1.252 2.357 0.252 5.428 2.704 1.~38 1.293 0.858 0.073 SECTION DISTAN~ 956.32 1028,94 1103.61 1179,90 1256,30 1~26.93 1~96.59 1471.35 1547,30 1625.41 1706.01 1787.71 1869.64 1951.0.~ 2030.2 2107.74 2185.35 2262,99 2341.52 2421.44 2b02,30 2584.29 2667,06 2747,53 2825.10 2901,40 2976.12 3049,69 3122,~3 ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BS,~IAL 24 OCT 8O RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER MEAS, DRIFT DEPTH ANGLE D M 5400 47 45 5500 47 45 5600 4R 0 5700 48 0 5800 48 3O 5900 48 45 60O0 49 0 6100 49 45 6200 50 0 6~qO 50 0 6400 50 0 6500 50 0 6600 50 15 6700 50 30 68OO 5O 15 6900 51 0 7OOO 51 15 7100 5] 15 7200 51 0 7300 49 0 7400 47 45 7500 46 15 7600 44 45 770O 44 0 7800 43 30 7900 43 0 8000 42 0 8100 41 30 8200 41 0 TRUE VERTICAL SUB DRIFT TOTAL COORDINATES C L 0 · DEPTH SEA DIREC DISTANCE DEG, S U R E S ANGLE D M 3995.75 3890.25 N55.15E 1941.36 N 2543.28 E 3199.56 N 52 4062,99 3957.49 N54,88E 1983,80 N 2603.93 E 3273.52 N 52 4130,06 4024,56 N54,55E 2026,64 N 2664,47 E 3J'47.64 N 52 4196.98 4091.48 N55.02E 2069.49 N 2725.19 E 3421.91N 52 4263,57 4158,07 N54,95E 2112,30 N 2786,29 E 3496.46 N 52 ~329,66 4224,16 N54,97E 2155,39 N 2847.73 E 3571,45 N 52 4395,43 4289,93 N55.22E 2198,49 N 2909,50 E 3646,72 N 52 4460.54 4355,04 N54,90E 2241,96 N 2971,72 E 3722.57 N 52 4524,99 4419,49 N55,83E 2285.42 N 3034,64 E 3798,97 N 53 4589,27 4483,77 N56.17E 2328.25 N 3098,14 E 3875,47 N 53 4653.55 4548.05 N57.27E 2370.29 N 3162,18 E 3951,92 N 53 4717.83 4612,33 N57,62E 2411.51 N 3226,75 E 4028.31N 53 4781,94 4676,44 N58,27E 2452,24 N 3291,80 E 4104,80 N 53 4845,71 4740,21 N59,13E 2492,25 N 3357,61 E 4181,49 N 53 4909,49 4803.99 N59.63E 2531,49 N 3423,89 E 4258,11N 53 4972e93 4867.43 N58,63E 2571.15 N 3490,24 E 4335,04 N 53 5035.69 4930.19 N57,68E 2612.22 N 3556,37 E 4412.65 N 53 5098.28 4992,78 N57.68E 2653.92 N 3622,28 E 4490.46 N 53 5161,05 5055.55 N56,55E 2696,19 N 3687,65 E 4568,18 N 53 5225,32 5119,82 N56.27E 2738.57 N 3751,46 E 4644.70 N 53 5291,74 5186.24 N54,75E 2780,89 N 3813.07 E 4719.42 N 53 5359,94 5254,44 N56,25E 2822,32 N 3873.34 E 4792,52 N 53 5430.03 5324,53 N56,90E 2861.60 N 3932,87 E 4863.77 N 53 5501,51 5396,01 N56,80E 2899,85 N 3991.42 E 4933,62 N 54 5573.74 5468.24 N56.98E 2937.62 N 4049,34 E 5~02.68 N 54 5646.58 5541,08 N58,08E 2974,40 N 4107,15 E 5071,07 N 54 5720,31 5614.81 N59,83E 3009,24 N 4165,03 E 5138,39 N 54 5794,91 5689.41 N59.22E 3043,01 N 4222,42 E 5204.69 N 54 5870,10 5764.60 N59,77E 3076.48 N 4279.22 E 5270,34 N 54 DOG LEG SEVER I TY DEG/iOOFT 38 40 E 0,802 41 53 E 0.200 44 33 E 0.309 47 13 E 0.349 50 2 E 0,502 52 43 E 0.250 55 27 E 0.28d 58 4 E 0.773 0 58 E 0.600 4 30 E 0.260 8 44 E 0.843 13 38 E 0.268 18 55 E 0.458 24 52 E 0.570 31 20 E 0,387 37 19 E 0,963 42 7 E 0,630 46 15 E 0.000 49 40 E 0,727 52 14 E 2,006 53 47 E 1.502 55 15 E 1.692 57 35 E 1.534 0 3 E 0,752 2 26 E O. 507 5 16 E 0.715 9 6 E 1,270 13 13 E 0.567 17 10 E 0,553 SECTION D I S T AN,~, 3196,41 3Z70e43 3344.59 3418.91 3493,51 3568,55 3643,8d 3719.78 3796.24 3872,84 3949.41 4025.96 4102.61 4179,49 4256,~ 4~33.4. 4~11.17 4~89,08 4566.89 4643.47 4718.22 4791.35 4862,65 4972.56 5001.68 5070.14 5137,55 5203.94 5269,69 ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BSWIAL RECORD OF SURVEY ALL CALCULATIONS PERFORMED BY I B M ELECTRONIC COMPUTER OCT. 80 TRUE MEAS, DRIFT VERTICAL DEPTH ANGLE DEPTH D M SUB DRIFT 'SEA DIRE[ DEG, TOTAL COORDINATES 8300 39 45 5946.28 5840.78 N60.68E 3108.65 N 4335.45 E 8400 39 0 6023.58 5918.08 N60.22E 3139,94 N 4390.64 E 8500 38 0 6101.84 5996.34 N63.70E 3169,20 N 4445.57 E 8600 36 45 6181,31 6075.81 N65.12E 3195.41N 4500.32 E 8700 37 30 6261.04 6155,54 N61.O2E 3222,74 N 4554,12 E 8800 38 0 6340.11 6234,61 N62.28E 3251.81N 4607.99 E 8900 41 15 6417,12 6311,62 N62.80E 3281.22 N 4664,58 E 9000 43 15 6491.14 6385,64 N62.40E 3312,16 N 4724.27 E 9100 45 0 6562,92 6457.42 N61,15E 3345,08 N 4785.61E 9150 45 0 6598,27 6492.77 N60.70E 3362,27 N 4816.51E THE FOLLOWING INFORMATION IS EXTRAPOLATED TO TO 931~ 45 0 6711.41 6605.91 N60.70E 3417,63 N 4915.17 E BOTTOM MOtE CLOSURE 5986.58 FEET AT N 55 11 17 E C L O S U R E S DISTANCE ANGLE D M 5334.78 N 54 21 29 E 5397.86 N 54 25 47 E 54'59.57 N 54 30 55 E 5519.38 N 54 37 25 E 5579.07 N 54 42 52 E 5639.85 N 54 47 23 E 5703,04 N 54 52 34 E 5769.67 N 54 57 57 E 5838.81 N 55 2 q8 E 5873.98 N 55 4 55 E 5986,58 N 55 11 17 E DOG LEG SEVERITY DEG/10OFT 1,304 0,772 1,655 1,349 1,694 0,691 3,258 2,009 1.858 0.636 0.000 SECTION DISTANCE 5334,22 5397.39 5459.20 5519.11 5~78,88 5639.72 5?02.96 5769,63 5838,79 5873,97 b986,58 ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BSWIAL INTERPOLATED TRUE VERTICAL DEPTHS, COORDINATES AND CLOSURES FOR GIVEN DEPTHS TRUE CODE MEASURED VERTICAL NAME DEPTH DEPTH TOTAL COORDINATES CLOSURE DISTANCE ANGLE D M S 24 OCT 80 SUB SEA T KUPARUK 8670 ~237.20 T UP SAND 8680 6245.15 B UP SAND 8868 6392,87 T LOW SAND 9094 6558.67 B LOW SA~ID 9174 6615.24 B KUPARUK 9213 6642.82 PLUG BACK 9203 6635.75 TD 9310 6711.41 3214.15 N 3216.99 N 3271.95 N 3343.33 N 3370.75 N 3384.54 N 3381.00 N 3417.63 N 4538.06 E 4543.41E 4645.86 E 4781.74 E 4831,21 E 4855.09 E 4848.96 E 4915.17 E 5561.00 N 54 41 28 E 6131.70 5567.01 N 54 41 57 E 6139.65 5682.40 N 54 50 38 E 6287.37 5834.63 N 55 2 21 E 6453.17 5890~89 N 55 5 46 E 6509.74 5918.~6 N 55 7 9 E 6537.32 5911.32 N 55 6 48 E 6530.25 5986.58 N 55 11 17 E 6605,91 ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB NO BSWIAL 24 OCT. 80 INTERPOLATED HEASURED DEPTH 1000 2000 3000 4000 5000 6000 700O 8000 9000 VALUES FOR EVEN TRUE VERTICAL DEPTH 993, 1829, 2510, 3122, 3725, 4395, 50~5, 5720, 6491, 1000 FEET OF MEASURED DEPTH, SUB SEA TOTAL COORDINATES 887. 43,00 N 60 1723, 376.74 N 467 2405, 846,03 N 1027 3016, 1373,21 N 1612 3620, 1776,73 N 2298 4289, 2199,13 N 2909 4930, 2612,98 N 3555 5614. 3009.70 N 4164 6385, 3312,78 N 4723 · 58 E · 66 E ,80 E ,37 E · 46 E · 05 E · 90 E · 75 E ,94 E ARCO KUPARUK E-7 · MEASURED DEPTH AND OTHER DATA GYROSCOPIC SURVEY FOR EVERY EVEN 100 JOB NO FEET OF SUB BSWIAL SEA DEPTH. 24 OCT, 80 TRUE MEASURED VERTICAL SUB DEPTH DEPTH SEA MD-TVD DIFFERENCE VERTICAL CORRECTION TOTAL COORDINATES 206 206, 100 0 306 306, 200 0 406 406, 300 0 506 506, 400 0 606 606, 500 0 706 706, 600 0 807 806, 700 1 909 906. 800 3 1013 1006. 900 7 1118 1106. 1000 12 1226 1206, 1100 20 1337 1306. 1200 31 1452 \ 1406. 1300 46 1571 1506. 1400 65 1694 1606. 1500 88 1824 1706. 1600 118 1966 1806. 1700 160 2110 1906. 1800 204 2254 2006. 1900 248 2396 2106. 2000 290 2540 2206. 2100 334 26~9 2306, 2200 383 2845 2406. 2300 439 2993 2506. 2400 487 3135 2606. 2500 529 3290 2706. 2600 584 3455 2806, 2700 649 3633 2906. 2800 727 3812 3006. 2900 806 3973 3106. 3000 867 4132 3206, 3100 926 4293 3306, 3200 987 4461 3406. 3300 1055 4638 3506. 3400 1132 4811 3606. 3500 1205 0 0 0 0 0 0 1 2 4 5 8 11 15 19 23 30 42 44 44 42 44 49 56 48 42 55 65 78 79 61 59 61 68 77 73 0.02 N 0.53 S 0.19 S 1.05 N 2,57 N 7,~70 N 16,16 N 28.05 N 45.18 N 66.84 N 92.68 N 122.57 N 157.60 N 199.'19 N 245.36 N 297.94 N 360,93 N 426.10 N 490.95 N 556.15 N 621,24 N 692.40 N 770.65 N 842.94 N 910.23 N 990.04 N 1078~79 N 1182.77 N 1287.36 N 1361,96 N 1427,33 N 1493.94 N 1562,48 N 1631.77 N 1697.74 N 0,22 E 0,39 E 0,07 W 2,21 E 7.50 E 14.58 E 26,06 E 42,53 E 63,62 E 89.49 E 120,43 E 157.58 E 202.49 E 252,38 E 305.60 E 370.86 E 448.71 E 929,93 E 610,30 E 687.75 E 767.89 E 852.51 E 943,20 E 1024,37 E 1099,80 E 1186.83 E 1283.26 E 1387.88 E 1492.98 E 1594.67 E 1699.53 E 1806.27 E 1922,83 E 2051.35 E 2176.40 E ARCO KUPARUK E-7 GYROSCOPIC SURVEY JOB MEASURED DEPTH AND OTHER DATA FOR EVERY EVEN 100 FEET OF NO BSwlAL SUB SEA DEPTH, 24 OCT 8O TRUE MEASURED VERTICAL SUB MD-TVD VERTICAL DEPTH DEPTH SEA DIFFERENCE CORRECTION TOTAL COORDINATES 4969 3706. 3600 1263 58 5120 3806, 3700 1314 51 5267 3906. 3800 1361 47 5414 4006, 3900 1408 47 5563 4106. 4000 1457 49 5712 4206, 4100 1506 49 5863 4306. 4200 1557 51 6015 4406. 4300 1609 52 6169 4506, 4400 1663 54 6325 4606, 4500 1719 56 6481 4706. 4600 1775 56 6637 4806, 4700 1831 56 6?93 \ 4906. 4800 1887 56 6952 5006, 4900 1946 59 ?lII 5106, 5000 2005 59 7269 5206, 5100 2063 58 7420 5306. 5200 2114 51 7565 5406, 5300 2159 45 7705 5506, 5400 2199 40 7844 5606, 5500 2238 39 7980 5706. 5600 2274 36 8114 5806, 5700 2308 34 8247 5906. 5800 2341 33 8377 6006, 5900 2371 30 8505 6106. 6000 2399 28 8630 6206. 6100 2424 25 8756 6306, 6200 2450 26 8884 6406, 6300 2478 28 9020 6506. 6400 2514 36 9160 6606, 6500 2554 40 9301 6706, 6600 2595 41 1763 1825 1886 1947 2011 2074 2140 2205 2272 2338 2404 2467 2529 2592 2658 2?25 2789 2848 2901 2954 3002 3047 3092 ~133 3170 3203 3239 3276 3318 3365 3415 .63 N ,34 N · 37 N · 31 N · 24 N · '62 N · 07 N .00 N · 69 N · 93 N · 01 N · 20 N · .15 N ,~6 N ,60 N ,88 N · 53 N .47 N · 79 N · 21 N · 79 N · 79 N .06 N · 02 N ,49 N ,19 N · .18 N · 83 Iq ,64 N .80 N ,65 N 2279,04 E 2373,55 E 2462.46 E 2551.77 E 2641.71 E 2732.49 E 2824,51 E 2918,78 E 3014,57 E 3114,04 E 3214.10 E 3315.90 E 3419,02 E 3524.33 E 3629,47 E 3731.67 E 3825.05 E 3912,12 h 3994,30 E 4074,35 E 4153.29 E 4230,36 E 4305,39 E 4377.67 E 4448,12 E 4516.55 E 4584.11 E 4655,05 E 4736,40 E 4822,63 E 4908,98 E ARCO OIL & GAS DRILL SITE KUPARUK E- 7 RADIUS OF CURVATURE - GYROSCOPIC SCALE I"= I000' NOV 5~ 1980 TiJN, RIOE, U,M. , eo oo TVD -" 6711 ' TMD = 9510' ALL DEPTHS SHOWN ARE TVD ~[5 4OO 800 SURFACE LOCATION IS 895' NSL~651'WEL, TIIN, R'JO E, U.M. I 1600 SEC~ VERTICAL SECTION ARCO OIL & GAS DRILL SITE KUPARUKE-7 RADIUS OF CURVATURE GYROSCOPIC SCALE I"= I000' NOV 5~ 1980 ~800 ~,200 ALL DEPTHS SHOWN A RE TVD $6OO --- 4000 4400 4800 5EO0 6000 6400-~ TVD = 6711 ' TMD = 9510" C . spe -sun J. A. Fouch~ Pres,dent September 30, 1980 Mr. Bob Hines Arco Oil & Gas P. O. Box 360 Anchorage, AK 99510 Re: Our Magnetic Multishot Survey Job No. MS-16671 Well E-7 ~/ Kuparuk Field North Slope, Alaska Operator: Tom McGuire Date of Survey: September 26, 1980 Dear Mr. Hines: Please find enclosed the "Original" and one copy of our Magnetic Multishot Directional Survey on the above well. Also included are the field data sheet and film. Thank you for giving us this opportunity to be of service. Yours very truly, KB/kc SPERRY-SUN, INC. Ken Broussard District Manager Enclosures RECEIVED OCT 't ARCO OIL AND GAS rKUPARUK NORTH SLOPE MAGNETIC F;UL1]SHOT _ _ TRUE MEASURED VE RTI C A-i_' DEPTH DEPTH SUB ~ SEA TVD PAGE 1 DATE OF SURVEY SEPTEMBER 26, 1980 VERTICAL SECYTO~N DIRECTION ~7-~-~'=~'~-70-0~E RECORD OF S COURSE COURSE I NCL INA T'I'-(~'N- ..... DiRE CT I-- DEG MIN DEG MI SUN~ INC URVEY DOG-LEG ON 'S-EV N DEG/IO0 TOTAL RECTANGULAR NORTH/SOUTH COORDINATES EAST/WEST MS-1667-I SECTION 164.00 i-.-255.oo 348.00 440.00 1 o o .~o o .... 58 28 o '-A's's'U-Md ~k ~ f'C×F TO 16~.00 132.80 0 ~5 N 11 254.99 223.79 0 30 N 21 3A7.98 316.78 1 0 N 46 439.93 408.73 2 30 N 59 100 FEET 0 E 1.17 0 E .30 0 E .63 0 E 1.68 0,00 N · 41 N 1.37 N 3.90 N o.oo ~' o2bd ...... · 08 E .29 · 54 E 1.04 1.07 E 2-'. i-7 ..... 3.36 E 4.96 533.0 624.0 Ill, 0 809.0 900.0 1.62 2.77 3.23 3.86 3.13 6.52 N 7.9~ E 10.22 10,86 N 15.03 E 18,53 1~80 N 25,96 E 31.47 27.76 N 40,88 E 49.41 41.24 N 59.00 E 71.97 1082.00 1174.00 1265.00 1356.00 1065.68 1034.48 21 45 N 5/+ 1150.~3 1119.23 2~ 0 N 52 1233. ~-2 ..... 1202 · 12 ..... 24--4'~ ..............N--'5'3 1,314.38 1283.18 29 15 N 5/+ 0 E ~+.13 .... 57.9~ N 0 E 2.50 77.0/+ N 0 E 2.59 98.58 N 0 E .9/+ lfi.~3 N 0 E 4.97 1/+5.98 N 80,87 E 99.q6 106.64 E 131.47 135.17 E 167.16 16~.97 E 20~,63 198.19 E 245.89 8. oo 9.00 !__16_.g~ o_,_p O_ __ 1721.00 1812.00 1471.32 1~40.12 32 30 N 56 1547.33 1516.13 3,+ 15 N 50 1(2o.83 ....1589.'63 38--- b ........... 1690.26 1659.06 ~2 30 N 53 0 E 1.90 0 E 2,01 0 E 4,10 o E 4;56 0 E 4.95 173.11 N 2~5.5q E 200,56 N 274,76 E 339.88 230,70 N 31/+.66 E 389.80 264.03 N 356.67 E 299.41 N 403.61 E 501.9~ 1904.00 1996.00 2089.00 2182.00 2276.00 1~20.72 1789.52 46 20 N 51 0 E 1885.13 1853.93 46 0 N 51 0 E 19~.88 19'1~8.68 45 ~5 N 6-2 0 E 2015.62 1984.42 45 30 N 51 0 E 2.99 1.95 .36 .82 .81 378.38 N 420.60 N /+62.16 N 503.98 N 506.~8 E 631.34 558.62 E 698.15 610.86 E 764.67 663.A4 E 831.63 2369.00 ...... ~OBO';80 2~62,00 2146.00 2555.00 e210.60 2648.00 2273,72 2114.80 45 30 N 53 0 E 2179.40 46 30 N 51 0 E 2242.,.,Z 4~ 0 N 52 0 E 1.5'3 5/+6.61 N 3.07 588.3~ N 765.78 E 963.58 1.88 629,53 N 818./+8 E 1030.29 1.80 672~'03 N 871.92 E 1098.34 9.RZ 71g._97 fki OOT_rnl I:' 1140_ 1 r, I'ARCO OIL /~ND GAS i.~r7 ......... KUPARUK NORTH SLOPE ?~GNETIC NULTISHOT TRUE MEASURED '- VERTICAL-- DEPTH DEPTH PAGE 2 VERTICAL SECTION DIRECTION N-56-i5-OO-E _M$s166~I .... S~ERRY-SUN~ INC RECORD OF SURVEY SUB COURSE COURSE DO~.?~EG SEA ...... I'NCLI NATi~ .... ~'-IREC TI ON SEV RECTANGULAR COORDINATES V E ~¥'~ TVD BEG MIN BEG MIN DEG/IO0 NORTH/SOUTH EAST/WEST SECTION 2835.00 239~.69 n930,00 2455,92 L~.c?2*+,oQ __ 2517.43 3117.00 2579.20 3148.00 259~.79 ~.363.49' - '50-15 -' N *+c,~ 0 E .1..65 76~-'2-3 N 982.29 E 12-~-'~.~'2~ "' 242A,72 ~9 30 N 51 0 E 1,79 808.92 N 1037,93 E 1312,~1 2486.23 ........ A8 4~ .......... N._~_ 0 E ~1,80 854.59 N 25~8.00 ~8 0 N 52 0 E 2.5q 898.80 N 11A5.98 E lq52,20 2568.59 q8 ~5 N 51 0 E 3,42 913,23 N 116q,12 E 1~75,29 3190.00 2627,56 3262.00 2675,26 2596o3~ 68 30 N 53 0 E 3,'62 932,63 N 1188,95 E' 1506,72 26*+4.06 48 30 N 53 0 E 0.00 965.08 N 1232,02 E 1560,55 ** T~ ~-~-I~CULAT-IO"~ ARE BASED ON THE MINIMUM RADIUS OF CURVATURE METHOD ** HORIZON_'TAL DISPLACEMENT_ = ..... 1565.01 .FEE.T_AT_NOR_T.H..5!__Q.EG START OF SURVEY WAS ~1.20 FEET ABOVE,SEA L EVEL M I N ° ..~ A .S. _T_ _(_.T_ P, _U E.L_ iARCO OIL AND GAS KUPARUK NORTH SLOFE MAGNETIC MULTISHOT MEASURED DEPTH 100. ?,.., 2100. 3100. ___3_2.62. DATE OF SURVEY SEPTEMBER PAGE 26, 1980 .... TRUE- VERTICAL DEPTH 100. 1082. 1893. 256R. 2675. SPERRY-SUNe INC INTERPOLATED RECORD OF SURVEY SUB SEA TVD TRUE ELEVATION 69. -69. 1051. -'i051. 1862. -1862. 2537. -2537. 2644. -26q4. MS-1667~ TOTAL RECTANGULAR COORDIN NORTH/SOUTH EAST/ O. N 81, N 11 426, N 56 891. N 113 965. N 123 ATES WEST O. E 2. E 5. E 6. E INTERPOLATED COORDINATES FOR EVERY FROM 100.00 FEET TO 1000.00 FEET OF MEASURED DEPTH 3262.00 FEET A PETROLANE COMPANY REPORT of SUB-SURFACE DIRECTIONAL SURVEY Arco 0il & Gas COMPANY Pad E, Well No: 7 WELL NAME K~]p~ruk Field: North Slope, Alaska LOCATION JOB NUMBER TYPE OF SURVEY DATE A980D0022 Directional Single Shot 9/26/80 SURVEY BY D. LeJeune OFFICE Alaska Eastman Whipstock A PET,~CANE ~ P. O. Box 4-1970/Anchorage, Alaska 99509/(907) 349-4617 7'WX 910-881-5066/Cable: EAS TCO October 22, 1980 Arco Oil and Gas P. 0. Box 1479 Anchorage, Alaska 99510 Well Number: Pad E, Well No: 7 Location: Kuparuk Field, North Slope, Alaska Type of Survey: Directional Single Shot Date: September 26, 1980 Method of Computation: Radius of Curvature Surveyor: Donald LeJeune Job Number: A980D0022 ? .~ ATTN: Bob Hines Dear Mr, Hines, I am enclosing the original and one copy of the Directional Single Shot Survey run on the above men- tioned well. We wish to take this opportunity to thank you for calling on our services and trust that we may continue to serve you in the future. Sincerely, VJim Turnage District Operations Manager Alaska District cc: file eno o JT/cfw D~rect~onal Drdlers/Sub-Surface Surveyors/Instrument & Tool Rentals/Sales/Worldwide ARCO OIL. AND GAS -- F'AI'I E', WE'L.L NO~+ 7 ~'IHS/DSS JOB NO~ A~780I)0022 )xUF'A~(I)~ FI~-LD, NORTH ~LOF'E, ALASKA Mdf~, O--~i'o.J b[~, S;UKVEY BY OPERRY SUN, DATE RU~4I 26-SEF'-80 DSS, ~;~47-'?160 HD, DKILLER: D LEJUENE VERl [CAL SFCT[ON CALCULATED IN F'L. ANE oF PRoF'osAI2 DIRECTION~ N RECORD OF SURVE'Y RADIUS OF CURVATURE HEI'H[)D /F,'CO OIL. AND GAS 'AD E, WFL. L NO: 7 MMS/DSS ,tJF'ARt]I~, FIELD, NORTH ,_LO~E, ALASKA ,.JOB NO: A980[;0022 COHFUTATION TIME [;ATE : 44: 11 22-0CT-80 PAGE NQ, I .... TRUE tEASURCD DRIF-1 DRIFI COURSE VERTICAL VC<RTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E OOGL. EG I~E:F']H ANGLE DIRECIlON LENGT~I DEPTH SECFIOiq TVO C 0 0 R D I N A T E S DISI'ANCE DIRECTCON S~VERII FEE1 I~ ~l D t'l FEE]' F.'E:£ l' FEET FEET FEET FEET 1] ~'i DG/IOOF ~ O. 0 0 0 0 O. 0.00 0.00 -105.00 0.00 0.00 0.00 0 0 0,00 100, 0 0 0 0 100o 100,00 0.00 -5.00 0.00 0.00 0.00 0 0 0,00 14'; 0 4~- N 11 0 E 64. 164.00 0.~9 ' ~, 59 O0 0.41 N 0.08 E 0.42 N 11 0 E 1.17 255 0 530 N ~1 0 E 91. '~=" 99 . . - ..~,4. 1.05 149.99 1.36 N 0 S5 E 1.41 N 14 S1 E 0.30 348. ] 0 N 46 0 E c9~. S47.98 9.16 '~ ~ ~ ~ , - ~4~.98 °.37 N 1.02 E 2.58 N ,.3 16 E 0.63 439.94 4.96 334.94 4.08 N 3.24 E 5.21 N S8 30 E 1.68 ,..,,53''~...79 10.-':'°..~. 427.79 6+71 N 7.81 E. 10.SO ,N 49 19 E 1.6 623.40 18.54 518.40 11.00 N 14.94 E 18.56 N 53 S9 E 2.77 715.48 31.48 610.48 17.95 N "~'~.8o E Sl.48 N 55 14 E. AO'~' ~ 42 N 55 41 E 3.86 ~.70 49.42 700.70 o/.86 N 40.82 E 49~ · . 900. 15 45 · .... 0 E 991. ]9 SO N 553 0 E 1082. 21 45 N 54 0 E 1174. 24 0 N 52 0 E 1265. ?4 45 N 53 0 E 9]. 893,84 71.98 788.84 41.29 N 58.98 E' 91. 980.56 99.47 ~ '875,56 ~' 58.06 N 80.83 E ' '~' 72 131.49 960.72 77.13 N '106.60 E 91. 10~.. 92. 1150.48 167.19 1045,48 98.65 N 135.16 E 91. ,1253.36~, 204.66' 1128.36 ~ 121.51N 164.95 E 72.00 N 55 0 E 99.53 N 54 ]9 E 131.58 N 54 7 E 167.33 N 53 53 E 204.88 N 53 S7 E 3.13 4.13 2.50 2.59 0.94 1356, 29 15 N 54 '0 E ]448, 31 0 N 54 0 E 1539. 32 30 N 56 0 E 1~30. 34 15 N 50 0 E ~..31. 38 0 N 53 0 E 91. 1314.43 92. 1394.00 91. 1471.38 91. 1547.37 91. 1620.86 245.92 1209.43 292.05 1289.00 339.9°~ 1366.38 389.88 1442.37 443.~~ lb15.86 146.08 N 198.15 173. ~:2% N 23,.,.51 ?-00.68 N 274.73 230.79' N 314.69 264.18 N '356,6/ 246.18 N 53 36 E 292.35 N 53 40 E 340.°°.. N 53 5i E 390.~, N~o~" 4~;~ E 443.85 N 53 28 E 4.97 1.90 2.01 4.10 4.56 1812. 42 30 N 53 0 E 1904. 45 15 N 53 0 E 1996. 46 20 N 51 0 E 2089. 46 0 N 51 0 E 2182. 45 45 N 5d 0 E 91. 1690.29 502.02 1585.29 92. 1756.61~ 565.67 1651.61 92. 1820.75 631.43 1715.75 93. 1885.16 698.24 1780.16 93. 1949.91 764.76 1844.91 299.56 N 403.61 E 337.93 N 454.53 E 378.53 N 506.49 E 420.74 N ~=~.63'"~ E 462.30 N 610.o~? E 502.63 N 53 25 E 5o6.39 N 53 22 E A32.31 N 53 14 E 699.35 N 53 1E 766.08 N 52 53 E 4.95 '2.9~ 1.95 0.36 0.82 2276. 45 30 N 51 0 E - 2369.- 45 30 N 49 0 E ~46.. 45 30 N 553 0 E '2555. 46 30 N 51 0 E -~648~-- 48 0 N 52 0 E 94. 2015.65 831.72 1910.65 93. '~080.85 897.~~ - ~, 1975.83 953. 2146.02 963.70 2041.02 93. 2210.62 1030.41 2105.62 93. 2273.75 1098.46 ~ 2168.75 504.13 N 546.76 N 588.50 N 629.68 N 67~..19 N 663.45 E 853.26 N 52 46 E 714.27 E 899.51 N 52 34 E 765.80 E 965.01 N 52 28 E 818.52 E 1032.70 N 52 26 E 871.96 E 1100.98 N 52 22 E 0.81 1.53 3.0/ 1.88 1.80 ;RCO O~L. AND GAS ' ' COM~UTATION PAGE NO,, 2 AD E, WLL[ NLI] / MHS/BSS JL)B NO~ A~oOE~O~ l'I~E DATE ,UF'ARUK ;'i~'LI~, NORI'~I SLOPE', ALASKA ~2144~11 fRUE dEASURErl I~RIF'] DRIFT COIJRSE VERTICAl. VERTICAL SUBSEA R E C T A N G U L A R C L. 0 S U R E DOGLEG DEF'I~I ANGi E DIRECTION LENGlll BEI-']~i SECTION TVD .C 0 0 R D I N A ] E S DISI'ANCE DIRECTION SRVERIT I:EE.T I~ ~'~ D M FEE] F~ET FFET FEET FEET F'EE~ D M DG/100F 2742. 50 15 N 51 0 E 283b. 50 15 N ,;9 0 E 29`30. ,19 30 N bl 0 E 3024. ,;8 45 N 49 0 E $117.' '18 0 N 52 0 E ~B%~q8. '18 45 N 51 0 E 3190. '18 SO N 5.3 0 E 3262. 48 $0 N 5;5 0 E. 94, '~335,26~ 1169,29 ~.....o~n.., 26 93, 2394,73 1240,36 2289,7~ 95. 2455.95 1512.57 2350.95 94. 2517.46 1383.22 2412.46 93. ~.o79,24 1452.38 ~474.24 31. =~,,.'~:°9 8~ 1475.47 ~o494.83 42. 2627.59 1~' 25v0 59 ~06,90 · 72. ~6~.30 1560.73~70.30 ,) 716.44 N 9,~7.58 E 1172.04 N 52 19 E 760 39 N 98~ 24 ,_, -.-.3b E I 3.49 N 52 11 E' 809,08 N 1038,00 E 1316,07 N 52 4 E 854,77 N 1092,44 E 1387,10 N 51 58 E 898,98 N 1146,08 E. 1456,59 N 51 5.3 E ,, 913.41 N 1164,21 E 1479.76 N 51 53 E 952.81 N 1189.05 E' 1511.28 N ,51 53 E 965.26 N 1232.11 E. 1565.]9 N 51 55 E 2,53 1.65 1.79 1,80 2,54 3.42 3,o2 0,00 ~')62- MI: I° ~, .:, FiE IN I-'OINT FROM SF'ERF(Y-SUN t~?~S FOR E/W 3347. =JO 45 N 50 `30 E 3658, ~ o6 30 N ,15 30 E 3690. 57 0 N 44 30 E 5821. 52 0 N 48 0 E 39].5. 49 45 N 54 30 E 4127. ,,0 30 N ,,8 ,30 E 4438, 53 ,15 N 60 30 E' 85 2730.36 16'~5 28 '~9 E = · 2625036 1005.35 N 1~82 96 E 16=..94 N 5[ 55 311, 2.14~ ,73 18 72,91 2809,73 . 1172,77 N 1468,91E 1879,65 N ~18 24 E 32, ~93~,27_ . . 1899,16' ~_0°~°~ 27 1191,70 N 1487,83 E 1906,25 N 131. S008.32 .... 2004,14~ ,2903.32 1265.41N 1564,83 E 2012.45 N o4., 3067.63 2076.74 ~,~=.~o 65 1~11.03 N 1621,67- E 2085.SS N 51,.~ E =;=' 4 N ~°ln-. 3203.55 =~'~x~.40 3098.~0 1 00.8f'* ,7U7.31 E 2247,51 N bl 311. .3394.46 2484.45 3289.46 1~=' 24 ,.~ ~o,38 N 1968,79 E 90,5/ N ':';~ 1-1E 3,47 2.26 3.04 .1,39 5.87 ].49' 1.16 ~z 62 4z~6, .,o 0 N 30 E .~..?6, 56 15 N 58 0 E 4773. 55 15 N 56 30 E 4808. 51 0 N~ 30 E 4934.- 49 45 N 55 30 E ._'~18, 3519,88 2661,98 3414,88 1610,45 N ..'.~1~.~...~,47 E 2666,68 N.:..~-'"~ 51 E 40. 3542.17 2695,10 3437,17 -. 162o.92 N 2154,30 E 2699.61 N 52 56 E 77. 3586.61 2757.97 3481.61 1660.94 N 2207.17 E 2/62,30 N 53 2 E 35. 3608.09 2785~59 3503.09 1676.38 N 2230~08 E 2789.89 N 53 4 E 126, 368R~.,45 ~88.,o 'q 63 3583,45 17~1,35 N 2310,06 E 2886,86 N 53 9 E 1,28 9,$6 -1,"1_ 6.81 0.99 5173. 47 0 N 54 30 E 5426. 47 0 N 53 0 E 5644. ,17 15 N 53 .30 E 5893, 48 0 N 53 30 E ~' 6205~' 49 0 N 54 30 E 239, 3847,19 3061,22 3742,19 1853,81 N 2456,39 E 3065,40 N 5.3 15 E 253. 4019.74 3246.07 3914.74 1943.22 N 2605.o0-E 3,:-:50.42 N 53 17 [' '~18, 4168.07 3.405.61 4063.07 ..038.81 N 2753.60 E 3410.18 NbS 17 [ ~ .. 74'-.,-'~ 15 N 53 18 E 249. 4335.89 3589.35 4230.89 ~'148."'3 N 2881..47 E ~,-,. 312. 4542.62 3822.84 4.137,62 2285,58 N 3070.51 E 3827,78 N 03 20 E 1.1.9 0.43 0,20 0.30 0.40 '6518, 49 .30 N 56 0 E 6830,- 49 '15 N 59 0 E 7110, 50 45 t5 60 0 E =: 177 313. 4746.93 4059.91 4641,93 2420.73 N 3265.34 E 4064.77 N ~3 E 312. '%949.05 4297,52 4844.05 2U4U.42 N 5465.78 fi. 4501.87 N b3 40 E 280. 5128.09 4512.'i4 5023.09 ~z~:~ 68 N 3651, ~.,. 26 E ,1";16.08 N 5.3 57 E 0.40 O. 74 4 ,a ;tl'(CO [ilL ANI~ t'~AS ' " A COHF~U..fAi. ION PAGE .'AIt E, WE'[.L NO; 7 H~IS/'DSS JOI:'~ NLI~ A980I';0022 ¥Itlb. £1AI'E xUF'ARUK FJ'E'LI'~, NORT~I SLOF'E, ALASKA 12,'4.4;11 22-0CT-80 ...... TRUE 'tEASURED r;RIi-.-I DRIFT COLIRSE VERTICAL VERTICAL SUBSEA R E C T A N G U L A R C L 0 S U R E DOt, LEG DEPTH At~G[.E D£RECTION LENGI~i I)LF"I~I Sf':CTIO~4 TVI) C 0 0 R I) .[ N A T E" S [~ISi'AiICE DIRECTION SE~VE. Rll FEEl' D t,I [; r,I FEET FEEl' FEET FEET FEEl' F'EET D t,i IJG/tOOF 7370, 47 0 N 60 0 E 77_1.0, 43 30 N 61 0 E 8241, 39 50 N ,~,5 0 E 8755o $7 15 N ~,& 0 E '?_1.60. 4'1 0 N ~ '~ o~ 0 E. 260, 5299°06 4707,84 5194,06 ,..~7''"~"...,~,59 N 3820,85 E 4710,"~~",:.,., N 54 1,.."~ E 340, ...,_...,,.,':':":,~°, 39 .... 4948,60 5433,39 i'."874+47 N 4050°'?7 E 4950,89 J'-,l 54 30 F' 531, ,.., ,,.. ~". ° :'"¢ ", 0 O0 5'"'~7,87.., 5031000 3034014 r4 4;344,34 E 5'~90,00~ , N ,~,~'" 4 [" 494o ~323 ,26 5.:,00,53 6218,26 S16_1. ~Sl f.I 4623 , ,.~:.~.,~ fi. ,.5600°86 N ,.,.,~," 38 [---' 425° 6645; o 64 5875,49 6540,64 ~276 · O0 N 4~)"5 o 04 [:.' 5~-373,51 N 56 6 IL I o 44 i,05 0,90 0,47 1,60 FINAL CI_.OSUI'(E -- DIRECFION,' DI STANCE N 56 DEGS 5 HINS 57 SECS E 5873,51 FE. EZT :PAD E RNB 14ELL NO ELD, ,i} I-:_~i PAD -~, 14EUL NO:* '7',' f- . t--!_L_~.. ~ ~UPRRUK FIELD. INORT Ii It:: [. EflSTIIRN i, IHIPSTOCK~ :INC. L~._;_L-_,.L~_.;. __,_L. !X_'._L_:'_..-4-'---!-4--L~ i- l~ I~ ' il, i', '~ ' t t I L ~ , I , t ' ' l-~'; ! I ~l , I,~, :, III d---~, ,~ t t t t--r i f-t-l-t ,'-q , 1- -_ :; -'~!~ 1~ iI~[~ -ti~-i -- !, .!.!l, ii.!.. !..t.l,.!!!~. !i-, ~, t,;! 1,, HS/DS$ SLOPE~: R TOR:_ DEPTH 9 . .227E i. 631T~ !4875.03 i6 5, Check Form for timely compliance w~th our regulations. Operator, Well N~ and Number Reports and Materials to be received by: , //- / ~- FO Date Required Date Received I Yes ~ .... ,, ', Remarks Completion Report Well History Samples Mud Log Core Chips Core Description Registered Survey Plat Inclination Survey Directional Survey Drill Stem Test Reports Production Test Reports Yes ! (~.,_ I -_ 06~ Logs Run Yes NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL FROM' Jerry J. Pawelek/Leo WELL NAME' ~, ~'//,~/~~/(- Transmitted herewith are the following for the subject well' DATE BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysi.s - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro Single Shot Mu 1 ti-s]~y~- Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log SCALE XEROX SEPIA BL LINE FILM RECEIPT ACKNOWLEDGED FOR- ~~k[ASE RETURN RECEIPI TO' ARCo Oil and Gas Company Attn' Mr. Leo Lash P.O. Box 360- Rm. #311-FAB Anchorage, AK 99510 DATE-D 7'. Transmitted herewith are the following for the subject well' NORTH SLOPE DISTRICT ENGINEERING ST~T TE~ FROM: Jerry J, Pawelek/Leo La " /~ WELL NAME' ~uP~,~ ~'~~t BL DATE SCALE XEROX SEPIA LINE FILM i~/~ BHC Sonic/Gamma Ray Log 0"/5"' ~ ~ Cement Bond Log/VDL /~/-~- Compensated Formation Density Log ~" ~/v/~- Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.)- Core No. Directional Survey - Gyro Single Shot Multi-shot Drill Stem Test - Test No. /Z)/~,,, Dual Induction Laterolog- Formation Density Log Formation Density Log/Gamma Ray Spectralog TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log , Carbon-Oxygen Log RECEIPT ACKNOWLEDGED FOR: ' OCT 2 2 DATE' ~ ;..',,,,, ! - - l"' , ARCo Oil and Gas Company Attn- Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 V~PLEAsE RETURN RECEIPT TO' f _ NORTH SLOPE DISTRICT ENGINEERING TRANSMITTAL #_ _,~'3 ~ TO- DATE' (~CT. FROM' Jerry J. Pawelek/Leo Lash WELL NAME- Transmitted herewith are the following for the subject well' DATE SCALE XEROX BL SEPIA LINE FILM BHC Sonic/Gamma Ray Log Cement Bond Log/VDL Compensated Formation Density Log Compensated Neutron-Formation Density Compensated Neutron Log Core Analysis - Interval Core No. Core Description (SWC) - Interval Core Description (Conv.) - Core No. Directional Survey - Gyro · , Single Shot ~ Multi-shot ! Drill Stem Test - Test No. Dual Induction Laterolog Formation Density Log Formation Density Log/Gamma Ray Spectral og TVD-DIL Differential Temperature Log Spinner Survey Fluid Density Casing Collar Log Perforating Record Neutron Lifetime Log Carbon-Oxygen Log DATE- P~~LEASE RETURN RECEIPT TO' RECEIPT ACKNOWLEDGED FOR' ARCo Oil and Gas Company Attn: Mr. Leo Lash P.O. Box 360 - Rm. #311-FAB Anchorage, AK 99510 RECEIVED OCT 5 i980 ARCO O,il,, a, nd,Gafi ,mpany October 7, 1980 Mr. Hoyle Hamilton State of Alaska Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject~Permit No. 79-96) Permit No. 80-80) DS-11-14 -~(Permit No. 80-73) DS 17-4 (Permit No. 80-85) Dear Sir' Enclosed please find our Monthly Reports of Drilling Operations for the subject wells. Very truly yours, P. A. VanDusen District Drilling Engineer PAV'sp Enclosures Form No 10-404 REV 3-1-70 SUBMIT IN DUPLICATE STATE OF ALASKA OIL AND GAS CONSERVATION COMMITTEE MONTHLY REPORT OF DRILLING AND WORKOVER OPERATIONS I OIL ~--~ GAS F-1 WELL WELL OTHER 2 NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P.O. Box 360, Anchorage, Alaska 99510 4 LOCATION OF WELL 893' FSL, 631' FEL, Sec 16, TllN, RIOE, UM 5. APl NUMERICAL CODE 50-029-20495 6 LEASE DESIGNATION AND SERIAL NO ADL 25651 7 IF INDIAN'ALOTTEE OR TRIBE NAME UNIT FARM OR LEASE NAME Kuparuk 25651 9 WELL NO. [-7 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay Field/ 11 SEC. T R. M. (BOTTOM HOLE OBJECTIVE) Kuparuk -River Oi 1 Pool Sec 15, TllN, RIOE, UM 12. PERMIT NO. 80-80 13. REPORT TOTAL DEPTH AT END OF MONTH, CHANGES IN HOLE SIZE, CASING AND CEMENTING JOBS INCLUDING DEPTH SET AND VOLUMES USED, PERFORATIONS, TESTS AND RESULTS FISHING JOBS JUNK IN HOLE AND SIDE-TRACKED HOLE AND ANY OTHER SIGNIFICANT CHANGES IN HOLE CONDITIONS. Report of Operations for September, 1980. Spudded well @ 0605 hrs, 9/23/80. Drilled and surveyed 13-3/4" directional hole to 3262'. Ran lO-3/4#csg and landed at 3249'. Cmtd csg w/1500 sx Fondu cmt followed by 350 sx Arcticset II cmt. ND diverter, NU BOP stack and test same. Drld out csg and drld 10' new 8-3/4" hole. Tested fm to 10.5 ppg EMW. Displace hole w/oil base mud system. Drld 8-3/4" hole to 4726'. As of 9/30/80, drilling 8-3/4" hole below 4726'. SIGNED -' --! ~n~ ~ TITLE. District Dril 1 itl ~CL~_~DATE~~ NOT£--Report on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the oil and {las conservation committee by the 1§th of the succeeding month,unless otherwise directed. ALASKA OIL AND GAS CONSERVATION COMMISSION Hoyle H. Hamilton~ Chairman/Commiss~~ Petroleum Inspector September 30, 1980 BOPE test on Arco~s Kuparuk %E-7, Sec. 16, TllN, R10E, UM. KupartLk River Undefined. S..aturda¥, s,ep.t~_r.' 27,!9.80 - I departed my home at 5:30 am for a 6=00 am showup and 7:00 am departure via Wien flight #71 for Deadhorse arriving at 9=40 am. Weather: +21°F, blowing snow, wind 25 mph from the east. BOPE tests on Kuparuk E-7 began at 9530 pm and were completed at midnight. Inspection report is attached. Sunday. SePt~er.,,,28w,,1.9,80 - BOPE tests began on Kuparuk D-6 at 9~00 p,m . . . Monday. September 29~ 1..980- and were completed at 5=15 pm, the $~ect Of' a' sep~'~ate ~el~r~. I departed Deadhorse via Wien flight %10 at 7=20 pm and arrived in Anchorage via Fairbanks at 10=00 pm and at my home at 10:30 pm. The check valve was repaired and tested while I was on location. In summary, I witnessed successful BOPE test on Arco~s Kuparuk E-7. BL:mm ~ ~ O&G #4 4/80 ALASKA OIL & GAS CONSERVATION COMMISSION B.O.P.E. Inspection Report Operator _.~~_~9 Representative ~/~F_ ~.~.,~: Well ~'/~-~ zF ~3 i~ ~-~ Pe~it ~ ~-~ Location: Sec /~ TII~R/~--M O~ /~asing Set ~ ~2~ f~- Drilling Contractor ~~~ Rig , ~ Representative ~~. ~,~ Location, General Well Sign ... General Housekeeping Reserve pit Rig BOPE Stack Annular Preventer Pipe Rams . _ Blind Rams Choke Line Valves H.C.R. Valve Kill Line Valves Check Valve Test Results: Failures Test Pressure l ,,, . ,, ~~,o ACCUMULATOR SYSTEM Full Charge Pressure. .. ~5.(~ psig Pressure After Closure /~.~- psig 200 psig Above Precharge Attained: Full Charge Pressure Attained: Controls: Master Remote ~)/<_ Blinds switch cover~--T~ Kelly and Floor Safe Upper Kelly Test Lower Kelly Test Ball Type 6P/~ Test Inside BOP.._ /9/~ Test Choke Manifold No. Valves No. flanges Adjustable Chokes ty Valves Pressure Pres cur e Pressure Pres sure Test Pressure,,, ,! Hydrauically operated choke Test Tlme~hrs. , Repair or Replacement of failed equipment to be made within _~ days and Inspector/Commission office notified. Remarks: . __ rain ~ O se~ rain ~' se( Distribution orig. - AO&GCC cc - Operator cc - Supervisor Inspector~_~~~~'~ ARCO 0~1 and Ga~ mpany /' ',J, L ,. ':'05', ,,.J;*,,. ,, , TO!el:", ,,0 .'], September 24, 1980 Xr. Hoyle Hamilton State of Alaska Division of Oil & Gas 3001 Porcupine Drive Anchorage, Alaska 99501 Subject- As-Built Survey Plats Dear Sir' ": .... In an effort to insure that your files are complete, we h ached copies of our well location as-built survey plats for all wells permitted thus far in 1980, excluding those included in our original drilling permit applications. Very truly yours, P. A. VanDusen District Drilling Engineer PAV/JBK/jh Attachments / '~ V r. ro~3~ ,~ F-- -m < < > (TI N, 2 I :RTIFY THAT I AM WELL #8 WELL #7 WELL //6 WELL #'5 WELL WELL WELL #2 WELL #1 15 Y 5,960,6000230 X = 549,8890825 LAT = 70°18~11o283" LONG = 149°351450185'' Y = 5,960,480.368 X = 549,8890486 LAT = 70918t10o104'' LONG = 149°35~45o219'' Y = 5,960,360.207 X = 549,889.255 LAT = 70°18'08o923'' LONG = 149°35~450249'' Y = 5,960,240.410 X = 549,889°039 LAT = 70018'07.744'' LONG = 149°35145o278'' Y = 5,960,120o155 X = 549,889o818 LAT = 70°18~06o561'' LONG = 149°35~450279'' Y = 5,960,000o596 X = 549,889°506 LAT = 70o18'05.386'' LONG = 149°35'45.311'' X = 5,959,880°504 Y = 549,889.996 LAT = 70°18~04o204I' LONG = 149,35145o320'' X = 5,959,760.244 Y = 549,889.514 LAT = 70°f8'03o022'' LONG = 149°35t45o358'' I HEREBY C EROPERLY REGISTERED AHD LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS AN AS- BUILT SURVEY MADE BY ME, AND THAT ALL DIMENSIONS AND OTHER DETAILS ARE CORRECT, AS OF: I II I II I I I ........... -~----- I III II I AtlanticRichfieldCompany O DATE: IDRAWING No: NORTH AMERICAN PRODUCING DIVISION ALASKA DISTRICT:=- KUPARUK '"~";~"' -- ', II '~" II I '1 I I I I III Ill lit ~ I [ u -~---'~=----' "! :~IIIII~iII~_L ... ~" I II ARCO Oil and Gas( ~pany Alaska Dist,l~,. Post Ofhce Box 360 Anchorage Alaska 99510 Telephone 907 277 5637 August 20, 1980 Mr. Hoyl e Hamilton Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject' Kuparuk Well E-7 Dear Sir' The maximum anticipated bottom hole and surface pressures for the subject well were not included with the application for a Permit to Drill. Based on data gathered from other wells drill- ed into the Kuparuk, the maximum bottom hole pressure to be en- countered is 3210 psi. If a gas bubble at bottom hole pressure and temperature were to rise without expanding but cooling to 80OF, it would exert 2800 psi on the BOP equipment. A 5000 psi 13-5/8" RSRRA BOP stack will be installed and tested to 3000 psi. A new surface hole diverter system with 10" diverter lines will be used. The ball valves on the diverter lines will open auto- matically when the annular preventer is closed, as per A.P.I. Recommended Practices. P. A. VanDusen District Drilling Engineer PAV:ruo August 20, 3.980 Pr. P. &. VanDusen District Drilling Engineer ARCO Oil and Gas Company p. o. Box 360 Anchorage, Alaska 995~0 Rex ~pa~ 2S6S:L 1~-7 Atlantic Richfield Company Permit Ho. 80-80 Sur. Loc,~ 893*HSL, 6310~L, Bott~ole ~.~ Dear M]r. VanDu~ne Enclosed Lo the approved application £or permit to dr~ll the above referenced ~ell. Well samples, ~ore chips and a mud log are not required. A d£reetional surve~ :Ls required. If available, a tape contain- ing the digitized log in£ormation shall he submitted on all logs for cop~ except experimental logs, velocit~y surveys and dipmeter surveys. Nany rivers in Alaska and their drainage systems have been elasai£ied as ~mportant for the spawning or m~gration of anadrouous £~tsh. ~ra~ons ~n ~se ar~8 are subject to AS ~6,50.870 and ~e regulat~o~ p~ulgat~ ~ereunde~ (T~le 5, Alash ~m~n~st~at~ve Co~). Pr~or to c~nc~ng ~~~nt of F~sh and ~. Pollution of any waters of the State is prohibited by AS 46, Chapter 3, Article 7 and the regulations promulgated thereunder (Title 18, Alaska Administrative Code, Chapter 70) and by the Federal leater Pollution Control Act, as amended. Prior to Mr. P. A. VanDusen Xupa=uk 25651 -2- August 20, 1980 commencing operations you may be contacted by a representative of the Department of Environmental Conservation. Pursuant to AS 38.40, Local Hire Under State Leases, the Alaska Department of Labor is Being notified of the issuance of this permit to drill. To aid us in scheduling field work, we would appreciate your notifying this office within 48 hours after the well is spudded. We would also like to be notified so that a repre- sentative of the commission may be present to witness testing of blowout preventer equipment before surface casing shoe is drilled. In the event of suspension or abandonment, please give this office adequate advance notif~cat.ion so that we may have a Very truly yours, ltoyle It. R~t. lton Chair~m of ny ORDL~ 07 T;:2 CE Alaska 0il & ~as Conservation Com~ission ~nclosure cc: Department of Fish & 6~uae, Habitat Section w/o encl. Department of Environmental Conservation w/o/encl. Department of Labor~ Supervisor, Labor Law Compliance Division w/o encl. ARCO Oil and Gas O,~ pany Alaska D~stnct Post Office Box 360 Anchorage, Alaska 99510 Telephone 907 277 5637 July 15, 1980 Mr. Hoyl e Hamilton State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Subject: Kuparuk Wells E-7 & E-8 Dear Sir: Enclosed please find the Applications for Permits to Drill the above-mentioned wells, along with the required as-built surveys, directional maps, BOP diagrams, and filing fees. Very truly yours, P. A. Van Dusen District Drilling Engineer PVD/jh Enclosures ARCO Od and Gas Company is a Divas,on of AtlanhcR~chheldCompany Form 10-401 REV. 1-1-71 SUBMIT IN TR~ ATE (Other mstructlons on reverse rode) STATE OF ALASKA,,i~' i: ~- L. .... ~- 1''~/~: ~; OIL AND GAS CONSERVATION COMMITTEE PERMIT TO DRILL OR DEEPE~'L ~ 7 ]0L~I la. TYPE OF WORK DRILL ['~ b TYPE OF WELL WELL WELL OTHER 2. NAME OF OPERATOR Atlantic Richfield Company 3 ADDRESS OF OPERATOR P. O. Box 360, Anchorage, 4. LOCATION OF WELL 8~t~¥fa~sL, 631' WEL, At proposed prod zone @ 6150' ss 1320' DEEPEmlt~:.; I'Ti O, ~" ~ "" ,r'~', r. lt SINGLE ~LTIP~ Alaska 99502 Sec. 1__6, T11.N, RIO__E, UM API %50-029-20495 6 LEASE DESIGNATION AND SERIAL NO ADL 25651 7 IF INDIAN, ALLOTTEE OR TRIBE NAME 8 UNIT FARM OR LEASE NAME Kuparuk 25651 9 WELL NO. [-7 10 FIELD AND POOL, OR WILDCAT Prudhoe Bay-Kuparuk River Oil 11 SEC., T., R., M, (BOTTOM P o o 1 SNL, 1320'WEL,Sec. 15, T11N, RIO.E, UM 13. DISTANCE IN MILES AND DI~ON FROM NEAREST TOWN OR POST OFFICE* 12 30.0 Miles NW of Deadhorse HOLE OBJECTIVE) Sec.15, TllN, RIOE, UM 14. BONDINFOP.MATION Oil and Gas Bond nE Statewi des~ety and/o, No. 8011 - 38 - 40 15. DISTANCE FROM PROPOSED * LOCATION TO NEAREST PROPERTY OR LEASE LINE, FT. 4387 (Also to nearest dng, umt, ff any) 18. DISTANCE FROM PROPOSED LOCATION TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT 120' 21. ELEVATIONS (Show whether DF, RT, CR, etc ) 71.5'GL, RKB 105.5' Federal Insurance Co.) ~mount $100,000 16 No OF ,ACRES IN LEASE 17 NO°ACRES ASSIGNED TO THIS WELL 2560 320 20 ROTARY OR CABLE TOOLS Ro ta ry 22 APPROX DATE WORK WILL START 8/15/80 19 PROPOSED DEPTH 6669' TVD 23. PROPOSED CASING AND CEMENTING PROGRAM r , SIZE OF HOLE SIZE OF CASING WEIGHT PER FOOT GRADE SETTING DEPTH Quantity of cement 3,.~ 24" 16" 65 H-40 80+ MD Cmt t'o surf-approx. 200 ft 13-3/4" 10-3/4" 45.5 K-55BTC 3276' + MD Cmt to surf-approx.3500 ~t~ 9-7/8" 7" 26 K-55BT( 9259' ~- MD Cmt wit~ approx. 2300 ft~ primary ' - 233 ft° secondary Arct. ic Pack from 2300' MD to surf. Atlantic Richfield Company proposes to drill a Prudhoe Bay Kuparuk River Oil Pool development well to approximately + 9259'MD, + 6669'TVD. Selected intervals will be logged and tested. A 20" x 2000 psi annula-r diverter-will be installed on the 16" conductor while drilling the surface hole. A 13-5/8" 5000 psi RSRRA BOPE stack will be installed on the surface pipe. It will be tested upon installation and weekly thereafter. Test pressure will be 3000 psig. The well will be completed with 3~"2 9.2# J-55 buttress tubing. Non-freezing fluids will be left on uncemented annuli thru the permafrost interval. Selected intervals will be per- forated within the Kuparuk formation and reported on subsequent report. A downhole safety valve will be installed and tested upon conclusion of job. IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM If proposal Is to deepen give data on present productive zone and proposed new producUve zone. If proposal is to drill or deepen duect~onally, g~ve pertinent data on subsurface locations and measured and true vertical depths. G~ve blowout preventer program. ~. / (Tim space for State office use) CONDITIONS OF APPROVAL, IF ANY SAMPLES AND CORE CHIPS REQUIRED MUD LOG [] ws C~-.o [] YES DIRECTIONAL SURVEY REQUIRED 'l~.~s [] NO OTHER REQUIREMENTS A.P.I. NUMERICAL CODE ~-o - ~- ~o PERMIT NO. ~ o- ~ ..3 APPROVAL DATE ' APPOVED BY ~~~ TITLE v ~- - ~, , ~ *See Instruction On BY ORDER O~ i~E CO,~&~IS$;ON ' Reverse Side August 20, 1980 DATE 08/20/80 FEET 9259 3926. iT ~4979. 56 15 ]~S E ' , I i WELL #8 Y 5,960,600.230 X = 549,889.825 LAT ~ 70°18~11.283'' LONG = 149°35~45.185'' i > WELL #7 Y = 5,960,480.368 ~ X = 549,889.486 ~ ~2_e' < LAT = 70.°18I10.104'' '~ WELL #6 Y = 5,9609360.207 O_ ~ ~ X = 549,889.255 ~ - LAT = 70°18~O8.923'' ~'~ ~ LONG = 149°35~45.249''' ~ WELL ~5 Y = 5,960,240.410 ~~ X = 549,889.O39 ~ .~ LAT = 70°18tO70744'' ~~- _-- LONG = 149°35~45.278'' ~ E~ WELL ~4 Y = 5,960,120.155 ~ ~' X = 549,889~818 ~ ~ > LAT = 70°18~060561'' ~4~ ~ LONG = 149°35~45~279'' m ~3~' WELL ~3 Y = 5,960,000 596 J ~ ~ ~ ~ X = 549,889. 506 ,~ ~ LAT = 70°18'05.386" ~ ~ ~, LONG 149°35~45 311" ~ WELL ~2 X = 5,959,880.504 '~ ~ Y = 549,889.996 ~; ~' LAT = 70°18~O4.204'' ~ ~l~'- -- LONG = 149,35'45.320" > = WELL ~1 X = 5,959,760.244 ~ Y = 549,889.514 ~ LAT = 70°~8~O3.O22'' ~ LONG = 149°35~45.358'' , t I HEREBY CERTIFY THAT I AM - PROPERLY REGISTERED AND LICENSED I ~ ~"" THIS PLAT REPRESENTS AN AS- JUL ~ 7 BUILT SURVEY MADE BY ME, AND ' .~ . 6/_~. THAT ALL DIMENSIONS AND OTHER A]~80i~ & G,~ ~ , DETAILS ARE CORRECT, AS 0F: .... ... II AllanlicRichfJeldOompany ~ DATE: DRAWING NORTH AMERICAN PRODUCING DIVISION ~ll.l~0 ALASKA DISTRICT -- =KUPARUK IT I II v I['"t.~. . r' r RTIFY THAT I AM -SURFACE DIVERTER SYSTEM 1. 20" Bradenhead 2. 20" 2000 psi Drilling Spool 3. 20" 2000 psi Annular Preventer 4. 6" Ball Valves 5. Rig Drilling Riser 6. 6" Lines to Sump -15- ANNULRR PREVENTOR BLIND RRMS PIPE RRMS DRILLIN(3 SPOOL PIPE RRMS 13-5/8" BOP STACK DIAGRAM Accumulator Capacity Test le Check and fill accumulator reservoir to proper level with hydraulic fluid. Assure that accumulator pressure is 3000 psi with 1500 psi downstream of the regulator. e Observe time,then close all units simultaneously and record the time and pressure remaining after all units are closed with charging pump off. Record on IADC report. (The acceptable lower limit is 45 seconds closing time and 1100 psi remaining pressure.) - 13-5/8" BOP STACK TEST le Fill BOP stack and manifold with non-freezing fluid. e Check that all hold down screws are fully retracted. Predetermine depth plug will seat & mark running joint. Run test plug on drill pipe and seat in wellhead. Run in lock down screws i n head. e Close annular preventer and chokes and bypass valves on manifold. e Test all components to 250 psi and hold for 10 minutes. Be Increase pressure to 3000 psi and hold for 10 minutes. Bleed pressure to 0 psi. Close top set of pipe rams and open annular preventer. e Increase pressure to 5000 psi and hold for 10 minutes. Bleed pressure to 0 psi. m Close bottom set of pipe rams and valves directly upstream of chokes, then open top set of pipe rams and chokes. Increase pressure to 5000 psi and hold for 10 minutes. e Test remaining untested manifold valves (if any) with 5000 psi upstream of valve and zero pressure: downstream. 10. Back off running joint and pull out of hole. Close blind rams and test to 5000 psi for 10 miq, 11. Bleed pressure off all equipment open bottom preventer. Make sure manifold & lines are full of non-freezing fluid and all valves are set in drilling position. 12. Test standpipe valves to 5000 psi. 13. Test Kelly cocks and inside BOP to 5000 psi with Koomey pump. 14. Check operation of De Gasser. 15. Record test information on Blowout preventer test form. Sign and send to Drilling Supervisor. 16. Perform complete BOPE test once a week and functional operate BOPE daily. CHECK LIST FOR NEW WELL PERMITS Item (1) Fee Approve Date Yes No Remarks ~,._~~~fi~ .~_,?.~2 . 1. Is the permit fee attached .......................................... ~r~. 2 Is well to be located in a defined pool . . .. 3 Is a registered survey plat attached ........... ' 4. Is well located proper distance frcm property line .................. ~ . 5. Is well located proper distance frcm other wells .................... / 6. Is sufficient undedicated acreage available in this pool ............ ( 7. Is well to be deviated .............................................. C~.;~ 8. Is operator the only affected party ................................. ~ 9. Can permit be approved before ton-day wait ................... ~ 11. Is a conservation order needed ...... ~. ......... " .........~ ..... . -~.... _ , · 12. Is administrative apuroval needed ................................... 13. Is conductor string provided ........................................ ~ (4) Cas~. ~ ~/,.ff~ 14. Is enough cement used to circulate on conductor and surface ......... 15. Will c~nent tie in surface and intermediate or production strings 16. Will cement cover all known productive horizons ..................... 17. Will surface casing protect fresh water zones ....................... ~_ 18. Will all casing give adequate safety in collapse, tension and kurst.. ~~ (5)BOPE ~ 19. Does BOPE have sufficient pressure rating - Test to Approval 5~c~ed: ~O psig .. ~ Additional Requirements: Geology: rev: 03/05/80 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. LIS ~APE LVP OlO,ho2 YEMAFiCaTION bIMTtNG PAGE SERVICE ~]A,Vg :SERVIC DAT~ :83/.05/ 4 ORI Ir: : TAPE ~ANE CONTINUATIO~ ; PREVIOUS TAPE COMMENTS :TAPE ** Flbg hEADER ** FILE hAb~E :SERViC.001 R~ICE NA~ : ER IOr~ # DAT~ MAXiM~ Lh~GT~ : 1024 ITYPE RE¥IOUS FILE ** INFORPATIOr! RFCORDS ** MNEM RANG: TOW~: SECT: COUN~ STAT: CALIFOE~iA CTR~: U.5.A. MNEM C~NTE~6 PRES: NEDIT4F ** RECORD ~YP~, 047 ** RECGP, 5 TYPE 047 ** RECLRD TYP~ 047 OOn 000 005 065 000 OOu 008 065 000 000 007 065 000 000 006 0~5 000 000 010 065 000 OOO 00b O~b ONIT ~IP~ CATE SIZE COOL 000 000 0O7 O65 LVP OlO,M02 VERIFICATION bISTING PAGE 2 , ~ACIFIC COAST CO~PUII~G CE~TER * , COFPAhY IELD COUNTY STATE : ATI. A~;TIC RICHFIELD : KOPARb~ g'7 : ?RUDHGE BAY : ~. ~bOPE : A~SwA ,<>,<>,<>,<>,<>,<>,<>,<>*<>*<>*<>*<>*<>*<>* O B # 70162 IL Rb~i~ ~10. : 6NE OGGED ~ATE : 07 OCT-BO ASi~G [)~ILbE~ : 10'75 ~ 3248 BIT SIZE : ~.75 FLUID TYPE : 6IL ~ASE DENS, : lu,5 ViSe. : 42 LUID LO S : %.8 Mb RM ~ ~EA8. TgMP, : N/A ~NF @ ~EAS, TE~. : N/A LVP OlO,H02 VgklFICATION Lt$3'I~G PAGE R~ tXBBT ~ATR : TENP. ; ** DAIA FORMAT ENTRY ~LSCK~ ~ECO~D ** 1 4 ~PR COD~ 66 65 65 DATUN SPECIFICAfION ~NE~ SERVICE SERVICE ID ORug~ # DEPT iLD DiL GR D1L NPHI CNL RHOB CNL GR C~L [A ~I C~L RHO C~L NRAT C~L NCNL CNL FC~5 POTA SGR 002 THOR Oo~ DATA 00~ RT ~C APl API APl FT 0 0 OMMM 7 0 0 oH:i? 7 J 2 46 GAPI 7 31 32 PU 42 68 2 G/C3 42 35 GAPI 42 31 32 I~ 42 28 3 G/C3 42 44 0 42 4 2 CPS 42 34 92 PPM 0 0 0 PO 0 0 u GAPI C 0 PP~ 0 0 0 0 GAPI 60 31 32 US/F 60 52 32 1 bO .lin 0 API FILE SIZE PROCESS M~D ;~. 4 0 0 4 0 0 0 4 0 0 0 4 0 0 4 0 u 0 4 0 0 0 4 n 0 0 4 o 0 0 4 o 0 0 4 0 0 0 4 0 0 0 4 0 o 0 4 0 u 0 4 O 0 0 4 o 0 0 4 0 0 0 4 0 0 0 4 0 n 0 4 n REPR CODE 68 68 68 65 68 DATA DEPt DRHO URAN DATA DEPT NPHI DRHO URA~ DA~A 3.3906 2.3047 3 1387 o: ~8,5000 9785 4121 0703 39n6 ';500 IuD GR CR ~C{~L DT 3 5U59 542 OOu 90,1~7b 4.0t:,Ou 44.6875 CALI 23]0 000 90.5u25 6@,5000 8.7500 154 7500 3:3242 73.7500 8.5625 63].0000 .3242 DEPT DATA DEPT NPHi DRHO URAN DATA DEPT NPHI URAN DATA DEPT NPHI DRHO URAN DATA DEPT NPH1 DEMO URAD DATA DEPT NPHI RAh DATA DRHO URA{~ DATA 010,HD2 VERIFiCAT%UN 9100 0 IbM 0 0i22 NRAT 2."2500 POTA 66.2b00 GR ~0~0 0 0 IbP z9:~9~2 RHOB . POTA b7.3~38 GR B8u0.OO00 IbM 25.,D977 RHOB 0.OI7D N~AT 2.20Q0 POTA q9o5o25 GR ~700.0u00 ~i.5527 RHOP -0.0083 0.8936 POTA ~0,5]13 ~boO.uuO0 Ib~ 45.1660 RHOd O.OlOj NHAT 2.i25u POTA 101.%250 G~ ~500.0o00 ILs -999.3(,00 RHOH ~999 3UO0 ~'RA~ 999:3000 POTA -9~9.3u90 GR 11 -99 84,657 DEPT ~400.0000 Ibh NPHI 999.lU00 RHO,~ -99 DRHO -999.3u00 NRAT -99 UKAN -999.3000 PDTA -9993 DATA -9~9.3d00 GR 20 4 8 5,75~ 9.875 5,964 2.400 1 0.87~ OD2 3,494 0.976 ~.687 1,5~7 2.334 3,~2 3.076 5.562 1.993 9.300 ~00 6.187 2.6~2 9.30n O0 . 9,~75 O' 9.30u 0.o15 5.00{) ILD G~ NCNb SGR GR OT DT CR SGR GR bC~b SGR IbP GR DI IbP GR NCnb $GR DT ~C~L D~ 4, ~4@4 2252 000O 84.'2500 95. DO00 ,8437 7 .3750 . 91.7500 gl. 2162,0000 91.0'625 97.~750 5 9922 67~5000 O00 O 6 0 90,0000 42 375C 70:~250 2013.0000 70.:[256 80.5~25 1 56 1685 0000 116:~S0C 117.7500 1 9902 -99g:3006 -999 00 ° 000 IO8.0000 2 ~762 -999: -999 ° 111.1675 2 ~3~ -999: 0oo -9~9 O i11,5625 GR CALl FC~b GR CALI TMGR R ThOR GR CALl FCNL GR CALI THCR G~ CALl FCNb GR CALl FCNL TdCR GR CALI FCNL THOR CALI 84 b875 651 5000 10~2578 785,7500 .8672 84O 0000 89 8750 645 5000 11.'2578 ~0.8750 9.0547 5OO0 93~'6719 . 66,6875 9.7)44 542.0000 12.1953 115.5625 9.3125 421,2500 13.7734 Ilb.1875 -999.3000 -999.3000 -999.3000 209.8750 -999.3000 -999,300u -9q9.3000 215.0000 -99g.300u -999,3000 -999.3000 DEPT NPHI URAN DATA DEPT NPHi DR.HO DRA~ DATA DEP~ NPHi OReO URA~ DATA DEPT MPHI DRhO D~TA DEPT NPHI URA~ DaTA DEPT NPHI DRhO URAN DATA NPHi D~HU URAN DATa DEPT DRHU DAIA DEPT ~PHI DATA 8200 ooou lb~ -999]3;')C0 RHOR -999 ~uO0 -9~9.3000 GR -999 33000 NI~A'£ -999; ()00 POTA -9~9,3000 GR ~o00 ~uO0 IbM 999:000 RHO{3 -999.3000 ~RAT -999.30n0 POTA -9~9,3000 GR -999.. -999 RA'f -999,3000 Gi~ .. RHO~ -999.300U NRAT -999,3000 POTA -999,3o00 GR ./79~.0o0o Ib~~ .3000 Rl{f~t~ -999 3bO0 NRAT -999:3000 POTA -999.3000 GM 7buO OuO0 4IbM ~ggq .' 3000 HOB 999,3000 NRA~ 29~9.3000 POTA -999.3000 GR "15uO.O000 IL~ -999.3o00 RHOB -9~9.3000 ~,RAT -999,3000 POTA -999,~o00 GM ?400.0000 IbP: -999. 3000 Rt~Ok~ 99 . 30 0 POTa -999.3o0O G~ 2 7930 -999:3000 -999.3000 -99930.0156 SGR 144.7500 DT 3.]9~8 lbD -999, DO0 GP -999~3900 NCNb -9993n.0156 SGR 79,3125 Df . 0 GR -999,3000 -99930.0156 SGR 100,8125 2.2617 -999.3ono -999,3000 -99930.0156 119,3750 DT 2,8091 -999.30n0 -999.3000 -99930.0i56 137 u25U 3 {)9 1LD -999.3000 -99930.0!56 135.3750 bT lt,lbh2 -999.30ri0 -999 o~OOO -99930:156 SGF 52.9687 bT 3,0078 ILD -999. 3000 GR ;~ 3000 ,,~ C ~, b -9 :0156 ~GR 2.8340 -999.30n6 -999.3000 -99930,01~F, SGP 184,5000 O"i 2 76 -999. ~000 -999.3000 117.0000 3 7207 -999: 3000 -999.3'00?, -99°. . 3000 96,0000 '99~ ' 1":895 .3000 -999 ]000 110.7bO0 2,18~95 -999.3'000 99:3000 113,7500 .9992']754 . 000 -9999.3.000 - 99. 300C, 104,3750 3.175~ -999.3000 :~99.3ooo 999.3000 i10.7500 -999 3060 -999:3000 66.0000 -999: oo -999.3000 -999.30C0 90.7500 2 8242 -999:3000 -999. 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DRHO ~99~.3000 N~AT URAN -99 ,3o00 POTA DATA -999.3uU0 GR DEPT ~boo.ouo0 IbM NPHI -999.3u00 DR~O -9M9.3900 NRA~ URAh -999.30no PGTA DATA -999,3000 GR OgPT 700 ()~00 DAT~ -999.3000 GR DEPT ~O0,O~O0 NPMI 99g,3nOO RHOB DRMO -999,3000 NRAT URAN ~q99.3000 DATa -9~9,30oo G~ DEPT ~5 DR~O -999 3000 N~AT URA~ -999:3u00 POq'a DATA -999.~o00 4,5820 ILD -999.3000 -999,3000 NCNb -99930,0156 139.~500 DT 2 oo -99930. ~6 SGR 204.00o0 .091B -99 ,3000 GR '9993 .0156 ~42,62§0 DT 2 ~37 -999~ 0~0 -99930, 15~ 2 4102 -999:3000 GR -999 3000 -99930:0156 SG~ 69,9375 2.0801 -999.3000 -999,3000 NCNb -99930,0)56 9b.bO¢)O 2,~262 -999, 000 -999 ~0110 -99930: 15~, SGR 87,1875 2,4609 ILD -999,3000 GR -999,3000 -99930,01%6 ~8.1875 -q99,300C -999 30rio -99930:51~6 8~,062b OT 2 GR oo 109.0000 2,0-.723 G R -999,3000 CAbI -999 30 FCNL llb,O000 2,2~610 GR -999,300 CALl -999 ~000 FCNb -999: 3000 T~CR 112,5625 2.4180 G~ -999.3000 CALl -999,3000 FCNL -999,30m0 T}]OR lO$,0VO0 2 0996 GR -999:3000 CALI -999 3000 FCNb -999: 3000 105.7500 2 318a GR -999: 300C CALl -999 ~000 FCND -999: 3000 T~I3R 105,7b00 2.5020 GK -999,3000 CALI -999 3000 ~CNb -999; 3000 THCR 107.~875 2 29~6 GR -999:3o¢o C¢ci -999,$000 fCNb -999,3000 THOR 104,7500 PAG~ 139.2500 -999,3000 -999.3000 -999.3000 204.0000 -999.3000 -999.~000 -999.3000 142.0250 -999.3000 -999 3000 -999:3000 143.5000 -999.3000 -99~,3000 -99 .3000 69.9375 -999.3000 -9~9,3000 -999.3000 96.5000 -999.3n00 -999.3000 -999.3000 87.1b75 -999,3000 -999.3000 -999.3000 88.1875 -999.3000 -999,3000 -999.3000 84.0625 -999,3000 -999,3000 -999.3000 LVP olu,Ho2 Yk~F~CATIOI, 5i~TI~G PAGE ! NPHI -99 ORdO -99 URA~' -99 DATA -99 NPHI -q9 DRHO -99 URAN DATA DEPT NPM1 -99 DRMO -99 URAN -99 DATA -99 DEP~ NPHI -99 DRHO -99 URAN -99 DAIA -99 DEP~ NPHI -99 DRHO URA~ -gq DATA -99 D£P~ 59u NPHI -gq DRHO -99 URAf, -99 DATA -99 DEPT NPHI -99 ORhO -99 URAN -99 DATA DEPT b7u NPHI -99 DATA -99 NPHI -99 D~HO -9~ URAr~ DATA 9,30~0 9.3000 NRAT q.~dO0 PGTA OoOOOu IbM 9.3~00 NRAT ~.3{~0 POTA ~.3o0o POIA 9.3u00 9.30~ 9,3~0U 9.3000 P[]TA 9.]~00 GR 0,0u00 IbM 9.3u00 NRAT 9.3u00 PUTA 9.~uO0 GR o. OoOU Ib~~ 9.]000 9.300U 9.3Uo0 POTA 9.~00 u. OuO0 Ib~ 9.3000 RhOB 9.3uOu NAA~ 9.3000 POTA 9.3000 GR O.OUOU I~s 9.30n0 RHOB 9,300o NRAT 9.3~0o POTa 9.3u00 GR O.OuO~ Iuh 9.30~0 RHOF 9.3o(;V ~RAT 9.3n~0 POTA 9.3~,U0 G~ 2.5~25 I~0 -999,30~]0 GR -999,3000 NCNb -99930.o15~ SGR 96.~00 DT 2.7715 IUD -999,30~0 GR -99~.3000 NCNb -99930.0156 SGR 96,1875 DT 2,8398 IbD -999,3000 GR -999.30,;0 NCmb -~993n.0156 SGR 86,6875 3.1953 -999.3000 GR -999.3000 ~Chb -99930.0156 SGR 97,25~)0 DT 3,9473 -999.3000 -999,3000 NCNb -99930.0156 SGE 97.52%0 bT 5.8~77 lbo -999.3000 GR -999,3000 NCNb -99930.0156 101.~250 DT 3.8340 ILD -999,30o0 GR -999,3000 -q9930,OlS6 79.3750 OT 2,8828 I~D -999.3000 GR -999,3000 ~Cab -~9930,0156 SGR 94,8125 OT 4.0742 lbo -999.3000 GR -999.3000 NCNb -99~30.0156 MGR 94,5000 Dr 2 6094 -999:3600 -9~9,3000 -999,3000 104,000o 0 b -999 ~000 -999: 104.7500 -999,~00U -999. oeo 104,7500 3 227 -999 3000 lu6,0000 4,0078 -999,3000 -999.3000 -999.3000 101,0000 -999.3000 -999,3000 104,5625 . 000 -999,3000 -999.3000 104.1875 -999.~000 -999, 000 113,0000 -99 3000 114.7500 CALl THCR C,~LI CALI THOR C~L1 FC,~b THOR CALl FCNb CALI GR CALl FCNL THCR CALI FCbb CALI ~6,2500 -999.3000 -999 3000 -999:3000 9~ 5 000 -999 3000 -999:3000 86 687 -999 3000 -999:3000 91 2500 -9gg:3000 -999 300,0 -99923000 97,6250 -999,3000 -99~ ~000 -gg 23000 101 6250 -999:3000 -999 3000 -999:3000 79,3750 -999.3000 -999 3(,00 -999~3000 94 5 -999,J000 -999,3000 . 94. 999'3000 -999 3000 -g99:3000 bVIP OtO.H02 VkF£~iCATIOI~ DEBT NPnI DEMO URA~ DATA DEBT NPHI URAN DATA DEBT NPHI DRHO URAN DATA DEPT N PHI DRHO URAh DATA DEBT NPHI DEMO URA~ DATA DEBT NPHI D~O URAh DATA D~PT NPHI DEMO URAN DATA DEBT NPHi URA~ DATA OMPI ~PHI DRHO URA~. DATA -9~9 -999 -999 -999 5400 -999 -999 -999 -999 .OoOO ILF .30o0 RBO~ .3000 NEAT .3000 POTA .]uOo GR .0000 IbM .3000 PHOB .3000 NRAI .BOOO POTA .3000 GR b3UO.OUO0 IbM 35.],J74 RHOB -0.0034 NEAT 1.6~,3~ POTA ~.3750 GN ~200 0 1 bO 5100 40 0 1 .OUOO ILN .7207 NhO~ .0083 NRA~ .560b POTA .O~3M GR .OO0O IbM .0391 RHO~% .0107 NEAT .5~36 P~TA .2187 GR bO00.O(~O0 IbM 41.0156 RHOb 0.0063 N~AT 2.6541 POTA b8.9687 GR ~900.0000 Ib~ 39.6484 RHOB 0.0278 NEAT 1.4b09 POTA '1~.~25 GR 4800 33 0 2 b2 .uuOO lb~ .1055 RHOB .155~ NRAT .6973 POTA .4~8 GR 4700.0000 IbM 33.B~7 ~HOB 0.0146 NEAT 2.~523 POTA bb.875U GR -99 -99 -9993 9 -99 -99 -9993 7 77 5.1914 9.30~0 9.~000 0.01~6 4.50q0 3.2109 9.3000 9.3000 0.0156 3.4375 3.9i21 2.2070 3.1465 1.51~7 .4375 5 2 3 ! 62 5 2 3 2 75 8 2 3 2 7b 7 2 3 2 11 2 3 2 13 2 2 .6523 .21&8 ,0000 .01q5 .2773 .4043 .0996 .6250 ,59]B .29~0 .0020 .2500 .2519 .3301 .41~0 .B750 .3418 .4219 .1777 .14R4 .0625 ,70JI .32~] .1641 .0508 .5625 GR DT SGR ILD SGR DT GR NCNb SGR DT GR SG~ DT GR DT GR SGR bT -99 . 000 °° 116.0000 3.7949 78.1875 li5.1875 62.5 132.1250 8 5.437 119,0000 9.0781 74.6875 121.5e25 2578 8~-;5000 193~.0000 5000 101,5~25 12,52813 82. 625 17~.0000 .5625 104.3750 12 6719 vl: 7s o I.ooo .18750 119.7500 GR CALI FCNb CALl FCNL THO~, CALl GR CALl FCNL THnR GR CALl THOR GR CALI FCNL THOR GR CALl FCN5 THOR GR CALl CNb BAG~ 94,5000 -999.3000 -999 :]ooOo. oo -99 -999 0 77 4375 9.'8906 547 5728.05000 . 625 75 ~250 ,~41 2~00 6~5 34 76,72500 9. 457, 10. 4~4 0000 0."4219 - 80.0625 12.6250 498 500 LVP 010.802 V~.kIFICATIO(~ LISTING PAG~ 9 DEPT 4bbO.O';O0 NPHI 36.57~3 RHOD DNHO 0,015o URA~ J,4()82 POTA DATA 48.3/50 GH DEP3 qbOu.v{~Ou NPHI 37.3~5 ORHO 0.0u29 NRAT URA~ 2.6fi~5 DATA 41.~n75 GR DEPI 4400.u~,00 I~ NPHI 39.~555 R}iOb DRMO -0.0u24 ~RAT URA~ 2.6152 POTA DATA 57.8/50 GR DEPT a300.Ou,)O Ib~ NPHI -999.~b00 RHOB DRMU -999.2~00 NRA1 UPAN -999.25~0 POTA DATA -999.2500 GR DEPT 4200.0o0U IL~ hPHI -999.25~0 RhO5 DRHU -999.2b00 NRAT b~A~ -999.2500 POTA DATA -999.2~00 G~ DEP~ 41uO.OuOu IL~~ NPHI -99q,2~)0 RHCI{ O~hO -9~9.2bOu NHAY URA[~ -999.2bo0 POTA DATA -999.2500 GR DEPT 4000.uvOu IbM NPHI -999.2500 RHOB DRdO -999.2b(~0 N~AT URAr,~ -999.~500 POTA DATA -999,2b~'0 GR DEPT ~900.0~00 Ib~~ NPHI -999.2b00 RHOB ORHO -999.2~0 N~AT URAP -999.2500 POTA DATA -9M9.2%00 GN NPHI -999.2Dn0 RHO5 DRHO -gB9.2bOu NHAT URAN -999.2b00 PUTA DATA -~9.2b0~ GA 3. 1, 56. 16. 2. 1. 06, 1~. 2. 1. 74. 12. -999. -999. -999. 50. 2000, -999. -999. -999. 84. -999. -999. 9~ -999. -999. -999. 60. 15, -9q9, -9~9. -999. -999. -999. -999, 70, 3672 84]7 9375 3125 5137 ~625 6313 I660 3809 ~6n2 6250 9687 2500 2500 2187 0000 2500 25OO 25e0 8125 5703 25c0 2500 25n0 OOOO 9062 25OO 2500 25eo 3750 27~4 25e0 25O0 2500 0313 8359 2500 25OO 2500 3125 ~P 5GR GR ~CNL DT GR NCNL SGR SGF GR SGR D? GR SGR DT GR NCmb SGR GR IbD SGR 5 563 126.375o 17,0625 63,4375 21~4 375 98.7500 1 250 2098,000v 74.6250 124,7b00 12,0703 -999,2500 -9~9.2500 -999.2500 143.125u 4.300u -999.2500 i999,2500 -999.2500 1:]0,0000 991-28i -9 .2500 '999,2500 -999.2500 124.0000 10.1~28 -999.2500 -999,250u -999.2500 129,7500 t4.3281 -999.2500 -999 -999.2500 134,3750 10,4063 -999,2500 -999. 0 103,0uOO CALl THOR GR CALl TBqR GR CALl TBGR CAb! FCNh T~CR CALl GR CALI THOR CALI THOR CALl FCNh GR CALl FC~,~L THOR i0. 13 b~. 594 10.~b25 9. 37 s :sooo i953 ,~ 8 50 21 -999,2500 -999 2500 84,8t25 -999.2500 -999,2500 -999.2500 ~8 0000 -99922500 -999 2500 -999:2500 60 3750 -999:2500 :25oo 34 0313 -999."2500 -999,2500 70,3125 -999,2500 -999,2500 -999 LVP OIO.HO~ VkRIViCATIOh LISTING DEPI 1700.Ou')O DRHO -999.2500 NEAT ORAN -999.2bOu POTA DATA -gN9.2b,)O GR DEFT 3600.OuOo NPHI -999.2bOu DRHO -9~9.2b00 N~AT URAN -999.2b~0 POTA DATA -999,2b,)0 DEPT 350U,Ouuu NPHI -999.2500 DRHO -999.2500 URAN -999.~00 PGiA DATA -999.2b')0 DEPT ~400.0o~0 NPHI -999.~b~0 D~HO -9~9.2b00 N~AT ~A~ -999,25~0 PGTA DATA -999.2590 GR DEFT ]300.OuO0 IbM ~PHI -999.2b00 DEMO -999.2b00 NEAT URA~ -999.2D00 POTA DATA -9~9.2b~0 GR DEFT ~229.0u(]0 Ib,~ NPHI -999.2500 ~OB DR~O -999.2b00 NEAT DRA~ -999.2500 POTA DATA -999.2~0u GF 8.1250 IbD -999.2560 -999.2500 -999.25~*0 SGR 57.b313 ~T 11.05~7 ILO -999.2500 GR -999.2500 ~CNb -999.25(~0 53.7500 10.007~ -999.25O0 GR -999.25~0 hCNL -999.2500 52.8125 DT 13.2656 -999.2500 GR -999,25¢;0 NCNb -~99.25n0 50.4688 8.7656 -999.25n0 -999,2500 -999,2500 SGR 50,6563 DT 2000.00()0 lbD -999.2500 GR -999,25~0 NCNb -999,25o0 SGR 34.7813 Di ** FILE T~qlLEF ** FILE mANE :SE~VIC,O0! 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MONITOR ,WS KL10E40 NOV-80[ *START* FILE: DSKH:VERIF¥.00~<051>[10707.610751 CREATED: PRINTED: 12 FEB 81 20:09:27 OUEUE SWITCHES: /FILE:FORT /COPIES:! /SPACING:! /LIMIT:78 /FORMS:NORMAL 3804 DATE 12-fEB-8! 12-FEB-81 20:05:49 20:09:10 SCHLUMBERGER COMPUTING CENTER 10707,61075 REEL HkADER LENGTH: 132 BYTES REEL NAME: P.C.A.L. SERVICE NAME: EDIT REEL CONTINUATION NUMBER: 0! PREV1UUS REEL NAME: C(]MMENTS: LiS FORMAT CUSTOMER TAPE DATE: 80111/ 8 TAPE hEADER LENGTH: 112 BYTES TAPE NAME: 61075 SERVICE NAME: EDIT TAPE C{~NTINUATION NUMBER: PREVIOUS TAPE NAME: COMMENTS: DATE: ~O/lt/ 8 EOF FILE HEADER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LENGTH: PREVIOUS FILE NAME: 1024 BYTES WELL SITE INFORMATIUN RECORD LENGTH: COMPANY: WELL: FIELD: RANGE: TOWN: SECTION: COUNTY: STATE: 184 BYTES ATLANTIC RICHFIELD COMPANY KUPARUK E-7 KUPARUK 16 N. SLOPE ALASKA PA~A .~()RMAT SPECIFICATION LENGTH: 770 BY?ES ENTR~ BI~OCKS: ?YPE 0 SIZE REP CODE ENTRY 1 66 0 DATUM SPECIFICATION BLOCKS: ENTRY IC TOOL SVORD# [{NITS AP1 API API API FILE# SIZE EXP PROC SA~ PEP DEPT SHIFT ! DEPT 2 ILD DIL ] ILM DIL 4 GR DIL 5 CALI CNL 6 DRHO CNL 7 NPHI CNL 8 RHOB CNL 9 NRAT CNL 10 NCNL CNL 11 FCNL CNL 12 SGR l) THO~ 14 U~AN 15 POTA lb SGR 17 GRST 18 GR BHC 19 DT BHC FT 0 0 0 0 0 4 0 0 1 68 0 0 OHMM 7 12 46 0 0 4 0 0 1 68 0 0 OHMM 7 12 44 0 0 4 0 0 1 68 0 0 GAPI 7 31 32 0 0 4 0 0 1 68 0 0 IN 42 28 1 0 0 4 0 0 1 68 0 0 G/C] 42 44 0 0 0 4 0 0 1 68 0 0 PU 42 68 3 0 0 4 0 0 1 68 0 0 G/C3 42 35 1 0 0 4 0 0 1 68 0 0 C/C 42 42 1 0 0 4 0 0 1 68 0 0 CPS 42 ]4 92 0 0 4 0 0 1 68 0 0 CPS 42 34 93 0 0 4 0 0 1 68 0 0 GAP/ 0 0 0 0 0 4 0 0 1 68 0 0 PPM 0 0 0 0 0 4 0 0 I 68 0 0 PPM 0 0 0 0 0 4 0 0 1 68 0 0 NONE 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 0 0 0 0 0 4 0 0 1 68 0 0 GAPI 60 3! 32 0 0 4 0 0 1 68 0 0 US/F 60 52 32 0 0 4 0 0 1 68 0 0 DEPTH 9246,000 9200.000 9100.000 9000,000 8900,000 8800.000 8700.000 8600,000 8500,000 MNEMONIC IbP DRHO NCNb URAN GR ILD DRHO NCNL URAN GR ILD DRHO NCNb URAN GR ILD DRHO NCNL URAN GR ILD DRHO NCNL URAN GR ILD DRHO NCNb URAN GR ILD DRHO NCNL URAN GR DRHO NCNb URAN GR iLD DRHO NCNb URAN GR VALUE 3.585 -0.438 542.5O0 0.369 68.500 4.051 0.007 2330.000 0.369 73.750 4.148 0.012 2252.000 2.250 84.688 4.844 0.006 2578.000 2.135 75.750 4.172 0.009 2162.000 1.412 89.875 5.9q2 0.018 2580.000 2.209 60.875 42.375 -0.008 201].000 0.894 66.688 1.516 0.010 1685.000 2.125 115.563 1.990 -999.300 -999.300 -999.300 116.188 MN EMONIC ILM NPHI FCNL POTA DT ILM NPHI FCNL POTA DT IbM NPH! FCNL POTA DT IbM NPHI FCNL POTA DT ILM NPHI FCNL POTA DT NPHI FCNL POTA DT ILM NPHI FCNL POTA DT IbM NPHI FCNL POTA DT ILM NPHI fCNL POTA DT VALUE 3,391 40.186 154,750 0.004 90.188 3.979 35,645 637.000 0.004 90.563 4,316 32.617 651.500 0.019 95.000 4.809 29.492 840.O00 0.017 91.750 4.234 34.473 645.500 0,021 97.]75 5.965 25,098 9]7.500 0.015 90,000 51 063 542.000 0.010 80.563 1.567 45.166 421.250 O.031 117,750 1,993 '999,]00 '999.300 -9991]00 108.O00 MNEM(]NIC GR RHOB SGR GR RHOB SGR SGR GR RHOB 5GR GR RHOB SGR GR RHOB SGR GR RHOB SGR GR RHOB SGR SGR GR RHOB SGR SGR GR RHOB SGR SGR VALUE 68.500 2.3O5 21.703 21.703 73.750 2,412 44.688 44.688 84.688 2.387 84.250 84.25O 75.750 2.383 74.375 74.375 89.875 2.395 91.063 91.063 60.875 2.400 67.500 67.500 66.688 2.691 70.125 70.125 115.563 2.334 116.250 116.250 116.188 -999.300 -999.300 -999.300 MNEMONIC CALI NRAT THOR GRST CAbI NRAT THOR GRST CALI NRAT IHOR GRST CALl NRAT THOR GRST CALl NRAT IH[)R GRS~ CALl NRAT THOR GRST CALI NRAT THOR GRST CALl NRAT THOR GRST CAbI NRAT THOR GRST VALUE; 8.750 3.139 3.324 18.750 8.563 3.070 3.324 39.719 9.156 2.969 10.258 66.250 8.867 2.736 8.523 57.344 8.922 3.033 11.258 79.813 9.055 2.459 b.b72 49.563 9.734 3.494 12.195 60.531 9.313 3.662 13.773 101.125 -999.300 -999.]00 -999.300 -999.300 DLP'rH 8400,000 8]00.000 8200.000 8100.000 8000.000 7900.000 7800,000 7700.000 7600.000 MN EMDNIC ILD DRHO NCNb URAN GR ILD DRHO NCNb URAN ILD DRHO NCNb URAN GR iLD DRHO NCNb URAN GR ILD NCNb URAN GE DRHO NCNb URAN iLD DRHO NCNb URAN GE 1LD DRHU NCNb URAN GR ILD DRHO NCNb URAN GR VAL 2 -999 -999 -999 209 2 -999 -999 -999 215 2 -999 -999 -999 144 3 -999 -999 -999 79 2 -999 -999 -999 100 . -999 . -999. -999 . 119. . -999. -999. -999. 137. . -999. -999. -999. 135. lO. -999. -999. -999. 52. UE .576 .300 .300 .300 .875 .234 .300 .300 .300 .000 .764 .300 .300 .300 .750 .721 .300 .300 .300 .313 .189 .300 .300 .300 189 300 300 300 375 775 300 300 300 625 176 300 300 300 375 391 300 300 300 969 MNEMONIC IbM NPHI FCNL POTA DT NPHI FCNL POTA DT NPHI FCNL PUTA DT ILM NPHI FCNL POTA DT IbM NPHI FCNL POTA DT NPHI FCNL POTA DT ILM NPHI FCNL POTA DT ILM NPHI FCNL POTA DT IbM NPHI FCNL POTA DT VAL 2 -999 29og 999 111 2 -999 -999 -999 111 2 -999 .-999 999 117 -999 -999 -999 96 2 -999 -999 -999 110 2 '999, '999, '999, 113. 0 -999, :999, 999, 104. . -999. -999. -999. 110. 11. .999. 999, 66, UE ,662 .]00 .300 .300 .188 .303 .300 .300 .300 .563 .793 .300 ,{00 .300 .000 .799 .]00 .~00 .300 .000 .158 .300 .300 .300 ,750 262 ]00 ~00 3OO 75O 869 300 300 300 {75 2ll 300 300 300 750 156 300 300 300 000 MNEMON lC GR RHOB SGR GR RHOB SGR GR RHOB GR RHOB SGR GR RHO8 SGR SGE GR RHOB SGR GR RHOB SGR SGR GR RHOB GR RHOB SGR SGR VALUE 209.875 -999.300 -999.300 -999.300 215.000 -999.300 -999.300 -999.300 144.750 -999.300 -999.300 -999.300 79.313 -999.300 -999.300 -999.300 100.813 -999.300 -999. ]00 -999.300 119.375 -999.300 -999.300 -999.300 137.b25 -999.300 -999.]00 -999.300 135.375 999.300 2999.300 -999.300 52.969 -999.300 -999.]00 -999.300 MNEMONIC CALl NRAI THOR GRS£ CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THUR GRS£ CALl NRAT THO~ GRST CALl NRA~ THO~ GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALI NEAT THOR GRST VALUE -999.300 -999.]00 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.]00 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 DEPTH 7500,000 7400.000 7300.000 7200.000 7100.000 7000,000 6900,000 6800,000 6700,000 MNEMONIC IUD DRHO NCNb URAN GR IUD DRHO NCNL URAN GR ILD DRHO NCNL URAN GR DRHO NCNb URAN GR IUD DRHO NCNb URAN GR DRHO NCNb URAN GR IUD DRHO NCNb URAN GR iUD DRHO NCNL URAN GR IIJD DRHO NCNb URAN GR VALUE 3.188 -999.300 -999.300 -999.300 161.125 2.824 -999.300 -999.300 -999.300 184.500 4.391 -999.300 -999.300 -999.300 139.250 2.877 -999.300 -999.300 -999.300 204.000 2.072 -999.300 -999.300 -999.300 142.625 2.246 -999.300 -999.300 -999.300 143.500 2.418 -999.300 -999.300 -999.300 69.938 2.100 -999.300 -999.300 -999.300 96.500 2.318 -999.300 -999.300 -999.300 87.188 MN kMONIC NPH! FCNL POTA DT ibm NPHI FCNL POTA DT NPHI ~CNL POTA DT NPHI FCNL POTA DT ILM NPHI fCNL POTA DT ILM NPHI FCNL POTA DT IbM NPHI fCNb POTA DT IbM NPHI fCNL POTA DT NPH! FCNL POTA DT VALUE 3,008 -999.300 -999.300 -999,300 90.750 2.834 -999.300 -999.~00 -999.300 102.~75 4.582 -999.300 -9q9.300 -99q.300 86,563 2,836 -999,300 : oo. oo 99.]00 109.000 2,092 -999.300 -999.300 -999.]00 116.000 2,264 -999,300 -999.]00 -999.300 112.563 2.410 -999.300 -999,300 -999,300 103.nO0 2,080 -999,300 -999.300 -999.300 105,750 2.326 -999,300 -999,300 -999.~00 lO5.750 MNEMON lC GR RHOB GR RHOB GR SGR SGR GR RHOB SGR SGR GR RHOB SGR GR RHOB SGR GR RHOB SGR SGR GR RHOB SGR GR SGR SGR VALUE 161.125 -999.300 -999.300 -999.300 184.500 -999.300 -999.300 -999.300 139.250 -999.300 -999.300 -999.300 .204.000 999.]00 -999.300 -999.300 142.625 -999.300 -999.300 -999.300 143.500 -999.300 -999.300 -999.]00 69.938 -999.300 -999.300 -999.300 96.500 -999.300 -999.300 -999.300 87.188 -999.300 -999.300 -999.300 MNEMONIC CAbi NRAT THOR GRST CALl NRAT THOR GRST CALZ NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRS~ CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST VABUE -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.]00 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 DLPTH 6600,000 6500.000 6400.000 6300,000 6200.000 6100,000 6000,000 5900,000 5800.000 MN LMONIC DRHO NCNL URAN GR DRHO NCNL URAN G~ DRHO NCNL URAN GR ILD DRHO NCNL URAN GR DRHO NCNL URAN GR ILD DRHO NCNL URAN GR ILD DRHO NCNL URAN ILD DRHO NCNL URAN GR ILD DRHO NCNL URAN GR VALUE 2,502 -999,300 -999.300 -999.300 88.188 2,299 -999.300 -999.300 -999.300 84.0b{ 2.609 -999.300 -q99.300 -999.300 96.250 2.811 -999.300 -999.300 -999.300 96.188 2.867 -999.300 -999.300 -999.300 86.688 3.223 -999,300 -999.300 -999.300 97.250 4.008 -999.300 -999.300 -999.300 97.625 5.828 -999.300 -999.]00 -q99.300 101.025 3.914 -999,300 -999.300 -999.300 79.375 MNEMON lC IbM NPHI FCNL PUTA DT NPHI FCNL POTA DT 1LM NPHI fCNb POTA DT 1LM NPHI FCNL POTA DT NPHI FCNL POTA DT ILM NPHI FCNL POTA DT ILM NPHI fCNL POTA DT IbM NPHI fCNL POTA DT NPHI FCNL POTA DT VALUL 2,461 -999.300 -999.300 -999.300 107.188 2.289 -999.]00 -999,300 -999.300 104,750 2,563 -999.300 -999,~00 -999.300 104.000 2,771 -999.300 -999.]00 -999,300 104.750 2,R40 -999.300 -999.300 -999,300 104,750 3.195 -999.300 -999.300 -999.300 106.000 3.947 -999,300 -99q,t00 -999.300 101.000 5.848 -999.]00 -999.300 -999.300 104.563 3.834 -999,300 -999.300 -999.300 104.188 MNEMON1C GR RHOB GR RHGB SGR SGR GR SGR SGR GR RHOB SGR GR RHOB SGR SGR GR RHOB SGR GR RHOB SGR SGR GR RHOB SGR SGR GR RHOB SGR SGR VALUE 88.188 -999,300 -999.]00 -999.300 84.063 -999.300 -999.)00 -999.300 96.250 -999,300 -999.300 -999.300 96,188 -999.300 -999.300 -999,300 86.688 -999.300 -999.300 -999,300 97.250 -999.300 -999.300 -999,300 97.625 -999,300 -999.300 -999,300 101.625 -999,300 -999,300 -9q9.300 79.375 -999,300 -999.300 -999,300 MNEMONIC CALl NRAT THOR GRST CALl NRAT THOR GRS~ CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAI THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THUR GRST CALl NRAT ~HOR GRST VALUE -999,300 -999,300 -999,300 -999,300 -999.300 -999,300 -999.300 -999.300 -999,300 -999.300 -999,300 -999,]00 -999,300 -999,300 -999.300 -999,300 -999.300 -999.300 -999,300 -999,300 -999.300 -999.300 -999,300 -999,300 -999.300 -999.300 -999,300 -999.300 -999,300 -999.300 -999.300 -999,300 -999,300 -999,300 -999,300 -999,300 ) i DEPTFt 57O0,,0OO 5600,000 5500,000 5400,000 5300,000 5200.000 5100,000 5000,000 4qo0,o00 MNEMONIC iLD DRHO NCNL URAN GR iLD DRHO NCNL URAN GR ILD DRHO NCNL URAN GR ILD D~HO NCNb URAN GR 1LD DRHO NCNb URAN GR 1LD DRHO NCNb URAN GR ILD DRHO NCNL URAN ILO DRHO NCNL URAN GR ILO DRHO NCNb ORAN GR VALUE 2,953 -999.300 -999,300 -999.300 94.813 4.199 -999.300 -999.300 -999.300 94.500 5.398 -999.300 -999.300 -999.300 94.50O 3.154 -99q.300 -999.300 -999.300 73.438 3.795 -0.003 2102.000 1.684 77.438 5.664 0.008 2150.000 1.561 62.000 5,258 0,011 1663,000 1.594 75,625 9.078 0.006 1847.000 2.664 76.250 8,258 0,028 1931,000 1,461 83.875 MN EMONIC IbM NPHI FCNb POTA DT NPHI FCNL POTA DT ILM NPHI FCNL POTA DT IbM NPHI FCNL POTA DT IbM NPHI FCNb POTA DT ILM NPHI FCNL POTA DT IbM NPHI ~CNL POTA DT IbM NPHI fCNb POTA DT ILM NPHI FCNL POTA DT VALUE 2,88) -999.300 -999,300 -999.300 113.000 4.074 -999.]00 -999.~00 -999.300 114,750 5,191 -999,300 ~999,300 999.300 116,000 3.211 -999.]00 999.]00 Z999.t00 119.188 3 912 . 0,015 115,188 5,652 38,721 572,500 0,014 132,125 5.020 40,039 441,250 0.021 119.000 8.594 41,016 457.500 O.020 121.56] 7,254 39,648 474,000 0,023 101,563 RHOB 6GR SGR GR RHOB SGR GR RHOB SGR GR RHOB SGR GR RHOB 8GR GR RHOB SGR SGR GR RHOB SGR GR RHOB SGR GR RHOB SGR VALUE 94.813 -999.300 -999.300 -999.300 94.500 -999.300 -999.300 -999.300 94.500 -999.300 -999.300 -999.300 73.438 -999.300 -999.300 -999.300 77.438 2.207 78.188 78.188 02,000 2.21~ 62.594 62,594 75.625 2.277 75.438 75.438 76.250 2.293 74.688 74.688 83.875 2.330 88.500 88.500 MNEMONIC CALl NRAT THOR GRST CALI NR~T THOR GRST CALl NRAT THOR GRSI CAbI NRAT THOR GRSI CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALI NRAT THOR GRST CALl NRAT THOR GRST VALUE -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 -999.300 .-999.300 999.300 .-999.30o 999,300 -999.300 -999.300 -999.300 -999.300 9.891 3.146 11.211 66.315 9.555 3.320 8.063 50.094 9.656 3.404 6.523 56.219 9.7B1 3.469 7.488 58.969 10.078 3,416 10.422 76.813 DEPTH 4800.000 t700.000 4600.000 4500.000 4400.000 4300.000 4200.000 4100.000 4000.000 MNEMONIC ILD DkHO NCNb URAN GR iLD DRHO NCNb ORAN G~ DRHO NCNb URAN GR ILD DRHO NCNb URAN GR ILD DRHO NCNL ORAN GR ILD DRHO NCNb URAN ILD DRHO NCNL URAN GR DRHO NCNb URAN GR ILD DRHO NCNb ORAN VALUE 12.281 0.156 1780.000 2.697 80.063 12.672 0.015 2027.000 2.652 68.563 MNEMONIC VALUE MNEMONIC ibm 11,344 GR NPHI ]3.105 RHOB ~CNL 498,500 6GR POTA 0,021 SGR DT 104.375 IbM 13.703 GR NPHI 33.887 RH00 ~CNL 579.000 SGR POTA 0.021 SGR DT 119.750 21.]44 IbM 21 0.016 NPHI 36 2150.000 FCNL 570 1.408 POTA 0 56.844 DT 126 17.06] 0.003 2134.000 2.604 66.063 12.844 -0.002 2098.000 2.615 74.625 12.070 -999.250 -999.250 -999.250 50.219 4.301 -999.250 -999.250 -999.250 84.813 .406 .572 ,000 ,014 ,]75 GR RHOB 8GR IbM 16,938 GR NPHI 37.]54 RHOB FCNL 583.500 SGR POTA 0,015 SGR DT 98.750 ILM 13,031 GR NPHI 39.355 RHOB FCNL 549,500 SGR POTA 0,017 SGR DT 124,750 1LM 12 NPHI -99925 FCNL -999 POTA -999 DT 14] .969 .000 .250 .250 .i25 ILM 2000 NPHI -9~925 FCNL 999 POTA -999 DT 130 .000 ,000 .250 ,250 .000 .570 ,000 ,250 ,250 .000 11.82R -999.250 -999.250 -999.250 68.000 q06 000 25O 25O 750 IbM 11 NPHI -99925 ~CNL -999 POTA -999 DT 124 10,133 IbM 9. -999.250 NPHI -99925, -q99.250 FCNL -999. -999.250 POTA -999. 60.375 DT 129. GR RHOB MGR SGR GR RHOB SGR SGR GR RHOB SGR SGR GR RROB SGR SGR VALUE 80,063 2.422 82.563 82.563 68.56J 2.328 71.188 71.188 56.844 2.293 59.656 59.656 66.06] 2.285 63.438 63.438 74.625 2.166 74.625 74.625 50.219 -999.250 -999.250 -999.250 84.813 9,250 -999,250 68.000 -999.250 -999.250 -999.250 60.375 -999.250 -999.250 -999.250 MNEMONIC CALl NRAT THOR GRST CALl NRA~ THOR GRST CALl NRAT THOR GRS1 CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALI NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST VALUE 12.625 3.178 7,4560 62.469 11.305 3.164 7.895 55.875 10.531 3.283 7.422 48.375 10.359 3.313 5.496 41.688 9.844 3.381 8.195 57.875 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 DEPTH 3900,000 ]800,000 3700.0OO 3600,000 3500.000 3400,000 3300,000 3229,000 MNEMONIC DRHO NCNb URAN GR DRHO NCNb URAN GR iLD DRHO NCNL URAN GR DRHO NCNL URAN GR ILD DRHO NCNL URAN GR ILD DRHO NCNb UPAN GR ILD DRHU NCNb URAN GR DRHO NCNL URAN VAL 14 -999 -999 -999 34 10 -999 -999 -999 70 8 -999 -999 -999 57 10 -999 -999 -999 53 10 -999 -999 -999 52 12 -999 -999 -999 5O 8 -999 -999 -999 5O 9 -999 -999 -999 34 UE .25 .25 .25 .03 MNEMONIC VALUE 8 IbM 15,27) 0 NPHI -99925.000 0 ~CNL -999.250 0 POTA -999,250 1 DT 134.]75 .406 .250 .250 .250 .313 IbM 9,836 NPHI -99925.000 FCNL -999.250 POTA -999.250 DT 10),000 .422 IbM 8.125 ,250 NPHI -99925,000 .250 FCNL -999.250 .250 POTA -999,250 .531 DT 137,375 .930 .250 .250 .250 .750 .805 .250 .250 .250 .813 .609 .250 .250 .250 .469 .75O .250 .250 .250 .656 1bM 11,055 NPHI -99925,000 FCNL -999,250 POTA -999.250 DT 144.~75 IbM 10,008 NPHI -99925.000 FCNb -999,250 POTA -999,250 DT 141.)75 IbM 13.266 NPHI -99925.000 FCNL -99q,250 POTA -999.250 DT 144.125 ILM 8,766 NPHI -99925.000 FCNL -999,250 POTA -999.250 DT 129.000 .586 IbM 2000,000 .250 NPH1 -99925,000 .250 FCNL -999,250 .250 POTA -999,250 ,781 DT 57,375 MNEMONIC GR RHOB SGR SGR GR RHOB GR RH00 SGR RHOB SGR RHOB SGR SGR GR RHOB SGR GR RHOB GR RHOB VALUE 34.0]1 =999.250 -999,250 -q99,250 70.313 -999.250 -999.250 -999.250 57.531 -999.250 -999,250 -999.250 53.750 -999.250 -999.250 -999.250 52.813 -999.250 -999.250 -999.250 50.469 -999,250 -999,250 -999.250 50,656 -999.250 -999.250 -999.250 34,781 -999.250 -999.250 -999.250 MNEMONIC CALI NRAT THOr4 GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALl NRAT THOR GRST CALI NRAT THOR GRST CALI NRAT THOR GRST CALl NRAT THOR GRST -999.250 -999,250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999,250 -999.250 -999.250 -999,250 -999,250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 SUMMARY Of DATA RECORDS NUMBER OF RECORDS: 926 LENGTH OF RECORDS: 994 BYTES I,ENGTH Uf LAST RECORD: 706 BYTES FILE TRAILER LENGTH: 62 BYTES FILE NAME: EDIT .001 MAXIMUM PHYSICAL RECORD LfNGTH: NEXT FILE NAME: EOF TAPE TRAILER LENGTH: 132 BYTES TAPE NAME~ 61075 SERVICE NAME: EDIT TAPE CONTINUATIUN NUMBER: 01 NEXT TAPE NAME: COMMENTS: , * * · * * 1024 BYTES , * , * * DATE: 80/It/ 8